Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
191-043
• • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑✓ f Suspended❑ lb.Well Class: 20AAC 25.105 20MC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG❑ WDSPL❑ No. of Completions: Service 0 ' Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 7/30/2016 191-043/316-209 3.Address: 7. Date Spudded: 15.API Number: P.O. Box 100360 Anchorage,AK 99510-0360 4/2/1991 50-029-22151-00 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 357'FNL, 143'FEL,Sec.31,T11N, R10E, UM 4/9/1991 (e L-17 Top of Productive Interval: 9.Ref Elevations: KB: 129' . Field/Pool(s): 1228'FSL, 1167'FWL,Sec.31,T11N, R10E, UM GL 87' BF: 88' Kuparuk River Field/Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 950'FSL, 893'FWL,Sec 31,T11N, R10E, UM 8586'MD/6244'TVD ADL 25659 . 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 539922 y- 5948611 Zone- 4 8700'MD/6322'TVD ALK 2585 TPI: x- 536255 y- 5944898 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 535982 y- 5944619 Zone- 4 N/A 1558'MD/1470'TVD 5. Directional or Inclination Survey: Yes Q(attached) No ❑ 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 R z ' . sc�� E �« t /} N/A SEP 272096 ACC 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 16" 62.5 H-40 43 122 43 122 24" 235 SX ASI 9-5/8" 36 J-55 42 4607 42 3571 12-1/4" 650 SX PF Type E,450 SX Class G 7 26 J-55 32.3 8675 32.3 6306 8-1/2" 275 SX Class G 24.Open to production or injection? Yes ❑ No 0 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3-1/2" 8081' 8032'MD/5868'TVD All perforations plugged off. ' N*04=4.J Gy) .... .:r.z 26.ACID, FRACTURE,CEMENT SQUEEZE,ETC. 7/30'h to Was hydraulic fracturing used during completion? Yes❑ No 0 1-fi-, Per 20 AAC 25.283(i)(2)attach electronic and printed information LU DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 8462'-8525' 26 bbls 16.5 ppg Class G 8037'-8455' 45 bbls 16.5 ppg Class G 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period ,-0. Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate -+- Form 10-407 Revised 11/2015 1/77- /0/3/4- CONTINUEDpN PAGE 2 RBDMS LV SEP 2 8 IOW it ORIGINIAL only • • 28.CORE DATA Conventional Core(s): Yes Q No Q Sidewall Cores: Yes LI No a 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 El No Q Permafrost-Top surface surface If yes,list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1558' 1470' Attach separate pages to this form,if needed,and submit detailed test information,including reports, per 20 AAC 25.071. N/A 31. List of Attachments: Summary of daily operations,well schematics. Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report,production or well test results,per 20 AAC 25.070. 32. I hereby certify that the foregoing is true . d correct to the best of my knowledge. Contact: Mike Callah.n Email: mlke.callahan Cl conocophllllps.com Printed Name: Gary Eller ‘�"� Title: CTD Engineering Team Lead Signature: c_14� N, Phone: (907)-263-4172 Date: �,A �C' \\c INSTRUCTIONS General: This form and the re firedat chments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well coir ion 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 lb: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level.Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost.Provide MD and 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 11/2015 Submit ORIGINAL Only • • 1 L-17 DTTM JOBTYP SUMMARYOPS START 6/24/16 DRILLING RIH AND CORRECT DEPTH AT FLAG, HARD TAG AT 8537' RKB, LAY IN CEMENT FROM SUPPORT- 8525' RKB TO TBG TAIL AT 8082' RKB, CLOSE CHOKE AND PERFORM 5 HESITATION CAPITAL SQUEEZES BEFORE WELL WILL HOLD 2300 WHP, CONTINUE TO LAY IN CEMENT FROM TBG TAIL TO SAFETY AT 6500' RKB, UNABLE TO BUILD ADEQUATE SQUEEZE PRESSURE AFTER 2 MORE HESITATIONS, DROP BALL AND CONTAMINATE CEMENT TO 8460' RKB, CHASE OOH WHILE MAINTAINING 1:1 RETURNS, F/P TBG, JOB IN PROGRESS. 6/25/16 DRILLING RIH WITH BALL DROP NOZZLE, CORRECT DEPTH AT FLAG TO 8041.7 RKB, TAG TOC AT SUPPORT- 8462' RKB, LAY IN 45 BBLS OF 16.5#CLASS G CEMENT(25 BBLS WITH CemNet) FROM CAPITAL 8455' RKB TO 4500' RKB WHILE MAINTAINING 1:1 RETURNS, CONTAMINATE CEMENT TO 8050' RKB WITH PRO-VIS, WASH ALL GLM WHILE POOH, F/P TBG TO 4000' RKB, READY FOR SLICKLINE AFTER 72 HOURS CURE TIME, JOB COMPLETE. 6/28/16 DRILLING ASSIST SL AS DIRECTED (JOB COMPLETE) SUPPORT- CAPITAL 6/28/16 DRILLING PRESSURE TEST CEMENT TO 2000 PSI (PASS); TAG TOP OF CEMENT @ 8037' RKB. SUPPORT- LEFT 1500 ON TBG. READY FOR DHD. CAPITAL 6/29/16 DRILLING (Pre-CTD) : TREE VALVE TEST. SV, SSV, & MV NEGATIVE (ALL PASSED). SV, SSV& MV SUPPORT- POSITIVE (ALL PASSED) CAPITAL 7/27/16 DRILLING Complete RD from 1L-18. Rig move to 1L-17. Spot modules over well. Perform RU checklist. NU SIDETRACK BOP stack. Circulate surface lines. Begin Initial BOPE test 250/3,750. 7/28/16 DRILLING Complete initial BOPE test, Fail/Pass valves C3, C11 and Ni, serviced stack, B7 and B8 failed, SIDETRACK rebuilt in place, greased, retested good. Complete testing inner reel iron, stripper and TT line. Lubricate out BPV. MU/RIH with BHA#1 pilot hole milling assembly, a 0.9°AKO motor and HCC 2.80" D331 GEB slick gauge mill to 3,800 ft as of midnight. 7/29/16 DRILLING Continue RIH with BHA#1 from 3,800 ft. Plus 21.5 ft correction at HRZ. Tag top of cement at SIDETRACK 8,050 ft. Mill cement pilot hole from 8,050 ft to 8,223 ft. Casing contact at 8,086 ft. Dressed transition area. Dry drift good. POOH. LD BHA#1. Jet stack. MU/RIH with BHA#2 Halliburton 24 short arm caliper to 2,400 ft as of midnight. 7/30/16 DRILLING Continue RIH with BHA#2 from 2,400 ft. Plus 9 ft correction at K1. Caliper 3 passes from 8,215 ft SIDETRACK to 8,000 ft. POOH. LD BHA#2. MU BHA#3 Whipstock Assembly. RIH. Plus 10.5 ft correction at HRZ. Set TOWS at 8,193 ft, 5° LOHS as per town discussion. POOH. LD BHA#3. MU BHA#4, 0.6°AKO motor with string reamer and 2.80" DSM. RIH. Plus 10 ft correction at HRZ. Dry tag TOWS at 8,193.5 ft, Circulate hole over to 8.6 ppg milling fluid. Mill window exit from 8,192.8 ft to 8,197.6 ft as of midnight. 7/31/16 DRILLING Continue milling window exit from 8,197.6 ft to 8,198.6 ft(Bottom of window)and rathole to 8,214 SIDETRACK ft. Back ream window 30° UR. Dry drift clean. POOH. PUD BHA#4. MU/PD BHA#5, 2.2+°AKO motor and RR 1-1 HCC Bi-center bit. RIH. Plus 11 ft correction at HRZ. Drill build/turn section to called TD 8,410 ft, erratic drilling. POOH. Logged RA marker at 8,201 ft. TOW at 8,194 ft, BOW at 8,199 ft. as of midnight. r • Modified by MSC 8-30-, " 3-1/2"Camco DS Landing Nipple @ 491'MD(2.875"ID) 3-1/2"9.3#L-80 EUE 8rd Tubing to surface 16"62#H- h 40 shoe @ 3-1/2"Camco MMG gas lift mandrel @ 2313'&7890' MD 9-5/8"36#J- Baker 80-40 Seal Assy @ 7947' RKB(7940'ELM) 55 shoe @ Baker FHL packer @ 7954'RKB j7947'ELM)(2.93"ID) 3-1/2"Camco DS Landing Nipple @ 7999' RKB (7992'ELM) (2.812"ID) Baker 80-40 Seal Assy @ 8017' RKB (8010'ELM)(2.99"ID) Baker PBR @ 8018-8036' RKB (8011'-8029'ELM) 11 1991 Completion Baker HB Retrievable Packer @ 8032' RKB (8025'ELM)(3.5" ID) 3-1/2"Camco D-Nipple @ 8048' RKB (8041'ELM) (Drilled out to 2.80"IC) 3-1/2"Baker SOS @ 8082'RKB l'ffiffi----.1 �( KOP @ 8193'MD 1L-17A(southeast) TD @ 12500'MD 1L-17AL1 (northwest) Liner @ 12500'MD Hole TD @ 11631'MD Billet @ 8349'MD Liner TD @ 11600'MD Liner top @ 8050'MD C-sand perfs --- ----- -- - ----- 8170' 8242' MD . 1 L-17A PB2(southeast) TD @ 10622'MD A-sand perfs Cement Retainer @ 9505'MD 8342'-8370'MD Billet @ 9165'MD -----------8405' 8420' MD 1L-17A PB1 (southeast) 8446'-8460'MD TD @ 10705'MD Billet @ 9220'MD 7"26#J-55 shoe @ 8675'MD KUP I • 1 L-17 ConocoPhiflips - Well Attribut Max Angle TD Alaska.Inc, Wellbore APIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Conocoyhdlips 500292215100 KUPARUK RIVER UNIT INJ49.22 4,400.00 8,700.0 `- ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1L-17,9/27/20162.05:54 PM SSSV:NIPPLE Last WO: 12/23/2013 J 42.01 4/11/1991 Verhral Schemabc(actual) Annotation Depth(MB) End Date Annotation Last Mod By End Date Last Tag: 8,421.0 5/27/2015 TENT SQUEEZE lehallf 9/27/2016 HANGER,38.5 ( .17. I 1 Casing Strings 11 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Leng...Grade Top Thread CONDUCTOR 16 . 15.062 43.0 122.0 122.0 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 9 5/8 8.921 42.0 4,607.2 3,571.5 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len Q...Grade Top Thread ( PRODUCTION 7 6.276 32.3 8,675.3 6,305.6 26.00 J-55 BTC-MOD Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection TUBING WO 31/2 2.992 38.5 8,018.4 5,858.7 9.30 L-80 EUE-M �.a�CONDUCTOR;43.6122.0 ----,Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) II 38.5 38.5 0.17 HANGER FMC TUBING HANGER 2.992 NIPPLE;481.1 491.1 490.8 6.08 NIPPLE CAMCO DS LANDING NIPPLE w 2.875"Profile 2.875 I 7,946.8 5,810.7 47.89 LOCATOR BAKER LOCATOR 2.990 7,947.1 5,810.9 47.89 SEAL ASSY BAKER 80-40 SEAL ASSY,Stick up 7'off NoGo Seals 2.990 Engaged 14.67' GAS LIFT;2,313.4 7,954.1 5,815.6 47.89 PACKER BAKER FHL PACKER w/PBR(Center element on 2.930 packer 7980.73') 1 7,998.9 5,845.6 47.91 NIPPLE CAMCO DS LANDING NIPPLE w 2.812"Profile 2.812 8,016.6 5,857.4 47.84 LOCATOR BAKER LOCATOR 2.990 II 8,017.4 5,858.0 47.84 SEAL ASSY BAKER 80-40 SEAL ASSY.Fully Located 1'Spaced Off 2.990 NoGo Seals Engaged 10.86' Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..'Set Depth(ND)(...Wt(Ib/fl) Grade Top Connection TUBING-Original 31/2 2.992 8,018.4 8,082.3 5,901.7 9.30 J-55 EUE8rdABMOD SURFACE;42.04,607.2 [ Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top(noir) Item Des Com (in) y- 8,018.4 5,858.6 47.83 PBR BAKER 10'STROKE PBR 3.000 GAS LIFT;7,890.8 1 8,032.1 5,867.9 47.77 PACKER BAKER HB RETRIEVABLE PACKER 3.500 8,048.4 5,878.9 47.69 NIPPLE 'CAMCO D NIPPLE NO GO MILLED TO 2.80" 2.800 11. 8,081.6 5,901.2' 47.54 SOS 'BAKER SHEAR OUT SUB 2.992 LOCATOR;7,918.6 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) I. Top(ND) Top Incl SEAL ASSY;7,947.1 'l1111.. Top(ftKB) )ftKB) I°) Des Corn Run Date ID lin) 8,193.0 5,976.6 47.28 WHIPSTOCK Baker 3.5"XL Mono-Bore WS with Cement Slips 7/3012016 PACKER;7,954.1 - MONOBORE NIPPLE;7,988'9ram Perforations&Slots 4 Shot Dens LOCATOR;8,016.6Er Top(TVD) Btm(TVD) (hots/ Top(f1KB) Btm(0KB) (ftKB) (ftKB) Zone Date ft) Type Com SEAL ASSY;8,017.4 8,052.0 8,054.0 5,881.3 5,882.6 A-4,1L-17 4/30/2016 3.0 APERF 2,120 Deg,Phase Big PER;8,018.4liiHole Charges PACKER;8,032.1 II If 8,170.0 8,242.0 5,961.0 6,009.9 C-4,1L-17 8/18/1991 6.0 APERF 2 1/8"Flow Jet Perf;0 deg.ph 2I10 °e 0. 8,342.0 8,370.0 6,078.1 6,097.3 A-5,1L-17 6/21/1991 4.0 IPERF 4.5"Csg Guns;180 deg. ZIl "'i CCWriented 25 deg. NIPPLE;8,0484 k A A 8,405.0 8,420.0 6,121.1 6,131.3 A-4,1L-17 3/27/2012 6.0 IPERF HES 2.5"Perf Gun,60 ( Deg,DP Charges 4 I\ 4i 8,446.0 8,460.0 6,149.1 6,158.6 A-4,1L-17 6/21/1991 4.0 IPERF 4.5"Csg Guns;180 deg. y ; ph;Oriented 25 deg. CCW APERF;8,052.08,054.0 N 8 Cement Squeezes y Top(ND) Btm(ND) y Top(ft(B) Btm(ftKB) (ftKB) (MB) Des Start Date Com SOS;8,081.0 4 l-a® 8,462.0 8,525.0 6,160.0 6,203.0 Cement 6/24/2016 45 bbls of 16.58 class G cement SLOTS;8,051.0-11,599.0--. 0 g Sq UeeZe ALU LATERAL LINER ASSY; y 8,037.0 8,455.0 5,871.2 6,155.2 Cement 6/25/2016 8.oso.6-11, O.n N kr WSqueeze WHIPSTOCK-MONOBORE;` 8,193.0 Mandrel Inserts APERF;8,170.0-8,242.0- . A st atii Cement Squeeze;8,037.0 ftKB- o Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (MB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com A 1 2,313.4 1,997.3 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/25/2016 2 7,890.8 5,773.1 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/29/2013 7:30 IPERF;8,342.0-8,3700 Notes:General&Safety End Date Annotation PERF,8,405.0-8.4200- 10/4/2010 NOTE:View Schematic w/Alaska Schematic9.0 LI IPERF;8 446.0-8,460.0 T r Cement Squeeze,8,462.0 kKB PRODUCTION;32.3-8,675.3 KUP Op •1L-17A con©coP"hllhlps a Well Attribut Max Angle D TD Alaska in, Wellbore API/UWI Field Name Wellbore Status ncl C) MD(MB) Act Btm(ftKB) (gaps 500292215101 KUPARUK RIVER UNIT PROD 98.94 10,690.26 12,500.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1L-17A,9/27/2016206;35 PM SSSV:NIPPLE Last WO: 42.01 4/11/1991 Vertical sGwmaoc jaotual) Annotation Depth)ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:CEMENT SQUEEZE lehallf 9/27/2016 HANGER;38.5 -•� Casing Strings Casing Description OD(in) ID)in) Top)ftKB) Set Depth(ftKB) Set Depth(ND)...W7Len(I...Grade Top Threatl AA SSY LATERAL LINER I 2 3/8I 1.9921 8,349.01 12,500.01 5,988.1 I 4.601 L-80 I ST-L f1 ''Liner Details Nominal ID Top(RKB) Top(ND))RKB) Top Incl)°) Item Des Com (in) 8,349.0 6,012.1 96.15 BILLET Aluminum OH Anchored Billet 1.000 9,600.8 6,003.8 89.44 DEPLOY Shorty Deployment Sleeve I 1.920 A..° CONDUCTOR;43.0.122.0 l Perforations&Slots Shot Dens Top(ND) Btm(ND) (shoal Top(ftKB) Btm)RKB) (00KB) (ftKB) Zone Date ft) Type Com NIPPLE;491.1 8,386.0 9,696.0 6,007.7 6,006.6 C-4,1L-17 8/18/2016 SLOTS ALL PERFS IN WELLBORE:Alternating solide/slotted pipe 4 -/.125"x2.5"@4 II circumferential adjacent rows GAS LIFT;2,313.4 } ¢ 10,776.0 12,499.0 6,028.8 5,988.1 C-4,1L-17 8/18/2016 SLOTS ALL PERFS IN WELLBORE:Alternating solide/slotted pipe -/.125"x2.5"@4 circumferential adjacent rows Notes:General&Safety SURFACE;42.0-4,807.2 End DaleAnnotation [( I NOTE GAS LIFT;7,890.8 tar r b � LOCATOR;7,946.8 SEAL ASSY;7,947.1 11._ PACKER;7,954.1 P. NIPPLE;7,988.9 f 11 LOCATOR;8,018.8 IN SEAL ASSY;8,017.4 PER;8,018.4 • PACKER;8,032.1 ADE Via. 1 NIPPLE;8,048.4 VI g. 'Jr, r . V APERF;8,052.048054.0— N t I- I gti'41I_. p SOS;8,081.6 Cemerd Squeeze;8,037.0 RKB i, APERF;8,170.0-8,242.0 0. ', WHIPSTOCK-MONOBORE;\ 8,193.01 - PRODUCTION;8,0 32.3A,5953 SLOTS;s,os1.011 666.0^��•••. AL1 LATERAL LINER ASSY; t"..— 8,050.6-11.800.0 1 at— 1� S-OT$.838609 696.01 T"' : SLOTS;10,778.012,499.0 1 1 A LATERAL LINER ASSY; 8,349 0-12,500.0 KUPD 1 L-17AL1 ConocoPh Blips Well Attribut Max AngleWD TD Alaska,no Wellbore APW WI Field Name Wellbore Status ncl(°) MD(9KB) Act Blm(RKB) wig, 500292215160 KUPARUK RIVER UNIT PROD 103.82 8,380.09 11,631.0 ... Comment H2S(ppm) Date Annotation End Date KB-Ord(R) 'Rig Release Date 1L-17AL1,9/27/2016 2:07:02 PM SSSV:NIPPLE Last WO: 42.01 4/11/1991 Vertical schemahc.(ootua0... Annotation Depth(RKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:CEMENT SQUEEZE lehallf 9/27/2016 Casing Strings HANGER,38.5 '® a CasingDescriptionasstelniOD(in) ID(in) Top ftK8 Set Depth(kKB) Set Depth(ND)...WELen I...Grade Top Thread ASSY II AL1 LATERAL LINER 23/8 1.992 8,050.6 11,600.0 6,015.61 4(601 L-80 ST-L Liner Details Nominal ID Top(RKB) Top(TVD) m MKS) Top Incl(°) [tern Des Com (m 1.920 ) I` Il8,050.6 5.880.3 47.69 DEPLOY Shorty deployment sleeve Perforations&Slots Shot Dens Top(ND) Btm(TVD) (shots/ Top(MB) Btm(ftK8) (RKB) (ftK8) Zone Date k) Type Com I 8,051.0 11,599.0 5,880.6 6,015.6 C-4,1L-17 8/1812016 SLOTS ALL PERFS IN -es-/s.CONDUCTOR;43.0-122.0 WELLBORE:Alternating Bolide/slotted pipe -/.125'x2.5'@4 circumferential adjacent t, rows NIPPLE;491.1 i'>t��. rit Notes:General&Safety End Date 1 Annotation NOTE: GAS LIFT 2,313.4 al • SURFACE,42.0-4807.2 1 I GAS LIFT,7,890.8 FIF I I I LOCATOR;7,948.8 SEAL ASSY;7,947.1 t'= PACKER;7,984.1 tI•t NIPPLE;7,995.9 car LOCATOR;8,016.6 1.7111 SEAL ASSY;8,017.4 - PBR;8,018.4 I= t• PACKER;8,032.1 it li FM M i i01 nt 4 l. i° NIPPLE,8,048.4 115 1"xi d i l' a ' k r ' ti APERF;8,082.0-8,054.0—..11'. 0 1 SOS;8,081.8 ^..4".---.-';f1; Cement Squeeze;8,037.0 ftK8 i APERF;8,170.0-8,242.0\._ n WHIPSTOCK-MONOBORE; FFFN717 8,675.3 la PRODUCTION;32.3-8,875.3 ?>— 121 r SLOTS;8,051.0-11,599.0---. 111.1- --am ALI LATERAL LINER ASSY, 8,050.6-11,600.0 • • 0 Operations Summary (with Timelog Depths) Si 4 1 L-17 Corcc)Phillips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(ftKB) 7/27/2016 7/27/2016 3.50 MIRU MOVE MOB P Complete ND BOP stack,secure 0.0 0.0 12:00 15:30 stack.Complete RD checklist.While waiting on trucks. 7/27/2016 7/27/2016 0.50 MIRU MOVE MOB P PJSM with NES trucking crew. 0.0 0.0 15:30 16:00 7/27/2016 7/27/2016 3.75 MIRU MOVE MOB P Pull pit module to side,pull sub off 1L- 0.0 0.0 16:00 19:45 18.Prep 1L-17 cellar,spot sub module over 1L-17,set mats,set down.Spot pit module,set mats,set down. 7/27/2016 7/27/2016 1.25 MIRU MOVE RURD P Complete post rig move checklist. 0.0 0.0 19:45 21:00 7/27/2016 7/27/2016 1.00 MIRU MOVE NUND P Nipple up BOPE,change out riser, 0.0 0.0 21:00 22:00 check torque on flange bolts(30 min) all good. 7/27/2016 7/27/2016 1.00 MIRU MOVE RURD P PJSM-Perform pre spud check list, 0.0 0.0 22:00 23:00 circulate surface lines,body test BOPE 4,000 psi. Rig Accept at 23:00 on 07/27/2016 7/27/2016 7/28/2016 1.00 MIRU WHDBOP BOPE P Perform initial BOPE test 250/3,750 0.0 0.0 23:00 00:00 psi.Annular 2,500 psi.Waived witness by AOGCC Jonnie Hill at 20:57 on 07/27/2016 over the phone. 7/28/2016 7/28/2016 11.00 MIRU WHDBOP BOPE P Continue initial BOP test 250/3,750 0.0 0.0 00:00 11:00 psi.Annular 2,500 psi.Witnessed waived by AOGCC Jonnie Hill at 20:57 on 07/27/2016 over the phone. C11 &C3,fail,retest pass. B7 and B8 failed. 7/28/2016 7/28/2016 1.00 MIRU WHDBOP SVRG P Service rig greased stack,choke 0.0 0.0 11:00 12:00 valves,serviced B7&B8. 7/28/2016 7/28/2016 5.00 MIRU WHDBOP BOPE T Continue initial BOP test 250/3,750 0.0 0.0 12:00 17:00 psi.Annular 2,500 psi.Rebuild in place and grease B7&B8,retest , good.TV1 fail,greased,retest good, Koomy test. Note: Nabors 5 hours NPT 7/28/2016 7/28/2016 2.75 MIRU WHDBOP PRTS P PJSM-Load coil and test inner reel 0.0 0.0 17:00 19:45 iron,stripper.Test PDL and TT line good. 7/28/2016 7/28/2016 1.50 MIRU WHDBOP MPSP P PJSM-RU/PT BPV equipment, 0.0 0.0 19:45 21:15 lubricate BPV out, 1,380 psi WHP,off load BPV equipment. 7/28/2016 7/28/2016 0.75 SLOT WELLPR OWFF P PJSM-Install night cap,bleed well to 0.0 0.0 21:15 22:00 0 psi,monitor for flow,no flow for 30 minutes.PJSM-MU BHA over dead well. 7/28/2016 7/28/2016 1.25 PROD1 RPEQPT PULD P MU BHA#1,Pilot hole milling 0.0 62.5 22:00 23:15 assembly,0.9°AKO motor and a HCC 2.80"D331GEB slick gauge mill. inspect pack offs,MU to CoilTrak, surface test. 7/28/2016 7/29/2016 0.75 PROD1 RPEQPT TRIP P RIH while displacing out the wells 62.5 3,800.0 23:15 00:00 diesel freeze protect. 7/29/2016 7/29/2016 1.00 PROD1 RPEQPT DISP P Continue RIH while displacing out the 3,800.0 7,925.0 00:00 01:00 wells diesel freeze protect. 7/29/2016 7/29/2016 0.25 PROD1 RPEQPT DLOG P Tie in to HRZ for plus 21.5 ft 7,925.0 7,984.0 01:00 01:15 correction. PUW 41k. • Page 1/26 Report Printed: 8/29/2016 0 ! 0 Operations Summary (with Timelog Depths) 1L-17 ODiiitips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (MKS) end Depth(ftKB)' 7/29/2016 7/29/2016 0.75 PROD1 RPEQPT DISP P RIH,Tag top of cement at 8,050',PUH 7,984.0 8,050.0 01:15 02:00 displacing well bore to milling fluid, RBIH. 7/29/2016 7/29/2016 13.50 PROD1 RPEQPT MILL P 8,050 ft.Mill cement pilot hole per 8,050.0 8,223.0 02:00 15:30 recommended practice,cement across shakers,several stalls, contacted casing at 8,086 ft,continued milling 1.7 BPM,2600 psi,as per wellplan at ROP 15 to 20 FPH TD pilot hole 8223'ft, PUW 38K 7/29/2016 7/29/2016 3.50 PROD1 RPEQPT REAM P Back-ream transition area up at 1 8,223.0 8,040.0 15:30 19:00 FPM, 180°to 8,070 ft,ream down 5 fpm to 8,092 ft,repeat 3 times,log HRZ for a plus 1 ft correction,dry drift ith 0.5k bobble at 8,091 ft,confirm pilot hole TD 8,223 ft,PUH and back ream tranition area 1 fpm,dry drift transition are with same bobble to 8,139 ft, 7/29/2016 7/29/2016 1.40 PROD1 RPEQPT TRIP P Check for flow(10 min),well dead, 8,040.0 62.5 19:00 20:24 POOH for caliper. 7/29/2016 7/29/2016 0.45 PROD1 RPEQPT OWFF P On surface,check for flow,good while 62.5 62.5 20:24 20:51 performing PJSM-LD BHA over dead well. 7/29/2016 7/29/2016 0.65 PROD1 RPEQPT PULD P LD BHA#1 62.5 0.0 20:51 21:30 7/29/2016 7/29/2016 0.90 PROD1 RPEQPT CTOP P Install nozzle,jet stack,remove 0.0 0.0 21:30 22:24 nozzle.PJSM-MU caliper. 7/29/2016 7/29/2016 1.00 PROD1 RPEQPT PULD P MU BHA#2(Halliburton realtime 24 0.0 22.0 22:24 23:24 short arm caliper)to coil,test caliper. 7/29/2016 7/30/2016 0.60 PROD1 RPEQPT TRIP P RIH with Halliburton caliper. 22.0 2,400.0 23:24 00:00 7/30/2016 7/30/2016 0.95 PROD1 RPEQPT TRIP P RIH with Halliburton caliper. 2,400.0 7,925.0 00:00 00:57 7/30/2016 7/30/2016 0.30 PROD1 RPEQPT DLOG P Tie in at K1 for plus 9 ft correction. 7,925.0 8,215.0 00:57 01:15 continue RIH to depth,open calipers. 7/30/2016 7/30/2016 0.65 PROD1 RPEQPT DLOG P POOH logging 1st caliper pass to 8,215.0 8,000.0 01:15 01:54 8,000 ft at 50 fpm,RBIH to 8,215 ft, POOH logging 2nd caliper pass.RBIH to 8,215 ft,POOH logging 3rd caliper pass, 1st pass questionable.Close caliper.Rush data. 7/30/2016 7/30/2016 1.40 PROD1 RPEQPT TRIP P POOH for whipstock. 8,000.0 22.0 01:54 03:18 7/30/2016 7/30/2016 0.45 PROD1 RPEQPT OWFF P On surface,flow check good while 22.0 22.0 03:18 03:45 performing PJSM-LD BHA over open hole. 7/30/2016 7/30/2016 0.65 PROD1 RPEQPT PULD P LD BHA#2,Halliburton caliper 22.0 0.0 03:45 04:24 7/30/2016 7/30/2016 0.75 PROD1 RPEQPT PULD P PJSM-MU BHA#3 Baker XL Mono- 0.0 73.5 04:24 05:09 Bore Whipstock w/Cement Slip,MU to CoilTrak,surface test. 7/30/2016 7/30/2016 1.60 PROD1 RPEQPT WPST P RIH with BHA#3,correlate to HRZ, 73.5 8,203.5 05:09 06:45 +10.5 ft,corrected depth 7978'ft,set whiptock at 8193 ft(TOWS)oriented 5°LOHS,set 3.5K down,PUW 411 . 7/30/2016 7/30/2016 2.70 PROD1 RPEQPT TRIP P POOH with BHA#3(whipstock setting 8,203.5 73.5 06:45 09:27 assembly) 7/30/2016 7/30/2016 0.50 PROD1 RPEQPT OWFF P Flow check-good. 73.5 73.5 09:27 09:57 Page 2/26 Report Printed: 8/29/2016 Operations Summary (with Timelog Depths) 1L-17 CorioccRttiHips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time - Dur(hr) Phase Op Code Activity Code', Time P-T-X Operation MKS) End Depth(ftKB). 7/30/2016 7/30/2016 0.30 PROD1 RPEQPT PULD P LD BHA#3(whipstock setting 73.5 0.0 09:57 10:15 assembly) 7/30/2016 7/30/2016 1.00 PROD1 WHPST PULD P PJSM,MU BHA#4,(Baker 2.80 0.0 74.3 10:15 11:15 Window mill&diamond string reamer w/Xtreme motor at 0.6°AKO), change pack-offs, MU to CoilTrk, surface test. 7/30/2016 7/30/2016 2.50 PROD1 WHPST TRIP P RIH with BHA#4,circulate well over to 74.3 8,193.0 11:15 13:45 8.6 FloPro milling fluid, tie-in to HRZ, +10 ft,dry tag 8193.5 ft,PUW 36K 7/30/2016 7/31/2016 10.25 PROD1 WHPST WPST P Begin milling whipstock from 8192.8 ft 8,193.0 8,197.6 13:45 00:00 per recommended practice and Baker rep,at 1.7 bpm,3350 psi FS, 11.2K off-btm Wt, **Top of whipstock at 8193 ft. 7/31/2016 7/31/2016 1.40 PROD1 WHPST WPST P Continue milling window from 8197.6 8,197.6 8,198.6 00:00 01:24 ft per recommended practice and Baker rep. 1.7 bpm at 3,265 psi,CWT 8.6k,WOB 2.6k. 7/31/2016 7/31/2016 1.60 PROD1 WHPST WPST P 8,198.6 ft. WOB dropped-1k lbs, 8,198.6 8,202.0 01:24 03:00 continue milling window per RP.2 fph to allow string reamer to clean-up bottom of window. *Btm of Window @ 8,198.6 ft* 7/31/2016 7/31/2016 0.85 PROD1 WHPST WPST P 8,202 ft. Continue milling to 21 ft past 8,202.0 8,214.0 03:00 03:51 TOWS.Gradually increased ROP from 3,6, 10,20 fph 1.70 bpm at 3,365 psi.CWT 10k,WOB 2.6k. 7/31/2016 7/31/2016 1.15 PROD1 WHPST REAM P 8,214 ft. TD rathole, PUW 33k, back 8,214.0 8,214.0 03:51 05:00 ream the window area 30°UR per RP A.OD�1 /L - / @ 1 fpm.Dry drift window @ 20 fpm- clean pass through window. 7/31/2016 7/31/2016 1.35 PROD1 WHPST TRIP P POOH w/BHA#4(window milling 8,214.0 - "'74.3 05:00 06:21 assembly),open EDC,contimue POOH 7/31/2016 7/31/2016 1.15 PROD1 WHPST PULD P PJSM-PUD BHA#4 74.3 0.0 06:21 07:30 7/31/2016 7/31/2016 1.25 PROD1 DRILL PULD P LD milling assembly/MU build section 0.0 72.2 07:30 08:45 BHA,install into PDL 7/31/2016 7/31/2016 1.00 PROD1 DRILL PULD P PJSM,pressure deploy build section 72.2 72.2 08:45 09:45 BHA 7/31/2016 7/31/2016 1.40 PROD1 DRILL TRIP P RIH with build section assembly,2.2+° 72.2 7,967.0 09:45 11:09 bend motor,HCC bi-center bit,open EDC. 7/31/2016 7/31/2016 0.20 PROD1 DRILL DLOG P Log tie-in to HRZ,+11 ft correction 7,967.0 7,967.0 11:09 11:21 7/31/2016 7/31/2016 0.25 PROD1 DRILL TRIP P RIH,close EDC,get PUW 31K, 10.3 7,967.0 8,214.0 11:21 11:36 SOW,establish 1.7 bpm rate 7/31/2016 7/31/2016 1.95 PROD1 DRILL DRLG P Drilling, 1 stall,WOB and weight 8,214.0 8,261.0 11:36 13:33 transfer erratic,PU 3 times off bottom, resume drilling,pull back through window area to 8171 ft,RBIH and resume drilling,drilling still erratic. Page 3/26 Report Printed: 8/29/2016 • • Operations Summary (with Timelog Depths) s 1L-17 Phiiiips .. F'.fiseke Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log, Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB); End Depth{ftKBI', 7/31/2016 7/31/2016 0.50 PROD1 DRILL DLOG P Log tie-in to HRZ,+2 ft correction,RA 8,261.0 8,261.0 13:33 14:03 marker at 8201 ft. *Correct TOW to 8194 ft&BOW at 8199 ft,based on RA tie-in of+1 ft. 7/31/2016 8/1/2016 9.95 PROD1 DRILL DRLG P 8,261 ft. OBD 1.7 bpm at 3,861 psi 8,261.0 8,410.0 14:03 00:00 FS,BHP 3,991 psi,CWT 10k,WOB 1.6k,Several BHA wipers,restarts, eratic drilling,acts as if balled up bit, pump 10 bbl pill Lo-vis with 1.5% Drillzone,little help,several BHA wipers,reduce pump rate to 1.5 bpm, squat 3k+WOB,9k CWT,to get some motor work,stick/slip,minimum DLS 38°,max 53°,average DLS 47°to end of build called at 8,410 ft.Pump 5x5 sweep 8/1/2016 8/1/2016 2.00 PROD1 DRILL TRIP P POOH for lateral drilling assembly 8,410.0 72.2 00:00 02:00 chasing sweeps to surface. 8/1/2016 8/1/2016 1.50 PROD1 DRILL PULD P PJSM-PUD BHA#5,Bit condition 3-1 72.2 0.0 02:00 03:30 -BT-N-X-I-NO-BHA,pics in folder 8/1/2016 8/1/2016 1.50 PROD1 DRILL PULD P PJSM-MU/PD BHA#6,0.4°AKO 0.0 72.2 03:30 05:00 motor and RB HYC Bi-center bit,MU to CoilTrak,surface test. 8/1/2016 8/1/2016 1.50 PROD1 DRILL TRIP P RIH with BHA#6 lateral driiling 72.2 7,966.0 05:00 06:30 assembly. 8/1/2016 8/1/2016 0.10 PROD1 DRILL DLOG P Tie-in to HRZ,+7.5 ft correction,29.0K 7,966.0 7,935.0 06:30 06:36 PUW 8/1/2016 8/1/2016 0.40 PROD1 DRILL TRIP P Close EDC,continue to RIH 7,935.0 8,410.0 06:36 07:00 8/1/2016 8/1/2016 5.50 PROD1 DRILL DRLG P OBD, 1.7 bpm,losing returns 20 to 30 8,410.0 8,810.0 07:00 12:30 bph from 8465 ft to 8515 ft,adjust MP choke to get back to 1:1,SOW ranging from 5.0K to 10K,WOB ranging from 0.5 to 2.0K,difficulty maintaining WOB,pump 30 bbl Hi-vis pill with beads in 5 bbl increments. 8/1/2016 8/1/2016 0.90 PROD1 DRILL WPRT P Short wiper trip#1,32K PUW,trap. 8,810.0 8,810.0 12:30 13:24 1045 psi WHP,pumps off for 10 min BHP,3858 psi AP,RBIH 8/1/2016 8/1/2016 0.75 PROD1 DRILL DRLG P OBD 1.4 bpm at 3,440 psi FS,BHP 8,810.0 8,855.0 13:24 14:09 3,890 psi,make 1 BHA wiper trip, RBIH, 8/1/2016 8/1/2016 4.40 PROD1 DRILL DRLG P BOBD 1.66 bpm at 3,830 psi FS, 8,855.0 9,210.0 14:09 18:33 BHP 3,800 psi,CWT 7.6k,WOB.8k, ROP 60-120,IA 0,OA 38,still lossing, adjust trip schedule-200 psi to comp losses,losing 8-10 bph 8/1/2016 8/1/2016 0.95 PROD1 DRILL WPRT P Wiper trip to window,PUW 33k.Jog at 9,210.0 8,210.0 18:33 19:30 FOB,perform choke calibration from 8,280 ft to 8,250 ft at 5 fpm, BHP 3,753 psi, 1.60 bpm in, 1.58 bpm out, MW in 8.64 ppg, MW out 8.75 ppg, WHP 473 psi Page 4/26 Report Printed: 8/29/2016 • 4110 w Operations Summary (with Timelog Depths) t 1 L-17 conocc thilips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth . Start Time End Time Dur(hr) Phase Op Code Activity Code'.. Time P-T-X '.. Operation (EKE); End Depth(EKE) 8/1/2016 8/1/2016 0.25 PROD1 DRILL DLOG P Log RA for plus 5.5 ft correction. RIH 8,210.0 8,250.0 19:30 19:45 Trap 3,750 psi BHP(12 ppg BHP), close choke and shut down pump, monitor BHP at 8,250 ft bit depth,DPS at 8,207 ft(5,980 ft TVD)monitor 15 minutes, BHP at 3,700 psi(11.9 ppg BHP)and falling slowly. PUW 33k. Make up12.0 ppg trip schedule. 8/1/2016 8/1/2016 0.45 PROD1 DRILL WPRT P Wiper back in hole. 8,250.0 9,210.0 19:45 20:12 8/1/2016 8/2/2016 3.80 PROD1 DRILL DRLG P BOBD 1.65 bpm at 3,697 psi FS,BHP 9,210.0 9,392.0 20:12 00:00 3,845 psi,CWT 7.0k,WOB 1.3k,ROP 45,WHP 437, IA 0,OA 40.Still losing 6-8 bph but appears to healing. 8/2/2016 8/2/2016 5.00 PROD1 DRILL DRLG P OBD 1.70 bpm at 3,927 psi FS,BHP 9,392.0 9,610.0 00:00 05:00 3,880 psi,CWT 8.6k,WOB 1.1k,ROP 56.WHP 433, IA 0,OA 40. 8/2/2016 8/2/2016 0.80 PROD1 DRILL WPRT P 1200'Wiper trip to 8410 ft,PUW 36K, 9,610.0 9,610.0 05:00 05:48 RBIH 8/2/2016 8/2/2016 8.70 PROD1 DRILL DRLG P OBD, 1.67 bpm,3872 psi BHP,9.0K 9,610.0 9,863.0 05:48 14:30 CWT, 1.0K WOB,60 ft/hr ROP,pump 5 x 5 sweep. 8/2/2016 8/2/2016 1.20 PROD1 DRILL WPRT P Wiper trip to window called early per 9,863.0 8,201.0 14:30 15:42 discussion w/town,+4 correction at RA marker,perform choke callibration at 8210 ft,hold 3750 psi BHP(12.38 ppg ECD at window), 1.69 bpm in, 1.66 out,378 pis WHP,3950 psi pump pressure. 8/2/2016 8/2/2016 0.65 PROD1 DRILL WPRT P Wiper trip back in hole • 8,201.0 9,863.0 15:42 16:21 8/2/2016 8/2/2016 3.55 PROD1 DRILL DRLG P BOBD 1.68 bpm at 4,050 psi FS,BHP 9,863.0 9,994.0 16:21 19:54 3,920 psi,CWT 7.8k,WOB 1.3k,ROP 38 8/2/2016 8/2/2016 0.40 PROD1 DRILL WPRT P GEO wiper,confer with town,continue 9,994.0 9,994.0 19:54 20:18 to move forward, RBIH. 8/2/2016 8/3/2016 3.70 PROD1 DRILL DRLG P BOBD 1.65 bpm at 4,050 psi FS,BHP 9,994.0 10,075.0 20:18 00:00 3,975 psi,CWT 3.0k,WOB 2.1k,ROP 28 8/3/2016 8/3/2016 0.90 PROD1 DRILL DRLG P Continue drilling ahead 1.68 bpm at 10,075.0 10,090.0 00:00 00:54 4,060 psi FS,BHP 3,942 psi,CWT- 2.5k,WOB 1.1k,ROP 15.Pump 5x5 sweep 8/3/2016 8/3/2016 0.35 PROD1 DRILL WPRT P Wiper up hole to 9,090 ft,PUW 36k. 10,090.0 9,090.0 00:54 01:15 8/3/2016 8/3/2016 0.40 PROD1 DRILL WPRT P Wiper back in hole.RIW 9.0k 9,090.0 10,090.0 01:15 01:39 8/3/2016 8/3/2016 1.55 PROD1 DRILL DRLG P BOBD 1.67 bpm at 4,150 psi FS,BHP 10,090.0 10,139.0 01:39 03:12 3,958 psi,CWT 7.1k,WOB 1.8k, ROP 40,WHP 303, IA 0,OA 46.Two stalls at 10,132 ft&10,139 ft. 8/3/2016 8/3/2016 0.25 PROD1 DRILL DLOG P Confer with town,Solar interference, 10,139.0 10,139.0 03:12 03:27 missed survey at 10,085 ft.PUW 39k, RBIH,good survey obtained at a 45 ft interval. • Page 5/26 Report Printed: 8/29/2016 oot • 0 ® Operations Summary (with Timelog Depths) 1L-17 ConocoPhimps Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 8/3/2016 8/3/2016 5.50 PROD1 DRILL DRLG P BOBD 1.51 bpm at 3680 psi FS,BHP 10,139.0 10,265.0 03:27 08:57 3,940 psi,CWT 6.0k,WOB 1.9k, ROP35.Slow drilling at 10,162 ft. 8/3/2016 8/3/2016 0.25 PROD1 DRILL DRLG P 10,260 ft, 100ft BHA wiper up hole, 10,265.0 10,265.0 08:57 09:12 RBIH 8/3/2016 8/3/2016 2.85 PROD1 DRILL DRLG P BOBD 1.51 bpm at 3680 psi FS,BHP 10,265.0 10,340.0 09:12 12:03 3,940 psi,CWT 7.0k 8/3/2016 8/3/2016 0.50 PROD1 DRILL WPRT P 10,340 ft,wiper up hole,PUW 36k 10,340.0 9,140.0 12:03 12:33 8/3/2016 8/3/2016 0.25 PROD1 DRILL WPRT P 9,140 ft,wiper back in hole,RIW 8k 9,140.0 10,005.0 12:33 12:48 8/3/2016 8/3/2016 0.50 PROD1 DRILL WPRT P 10,005 ft,pumping 1.2 bpm,high side 10,005.0 10,005.0 12:48 13:18 TF,set down 3k DHWOB,PUH,lower pump rate,RBIH,popped thru,turned around,pulled 10 fpm up thru area, 40k CTSW,minus 3k DHWOB,RBIH clean 8/3/2016 8/3/2016 0.25 PROD1 DRILL WPRT P 10,005 ft,continue RIH to bottom, 10,005.0 10,340.0 13:18 13:33 communicate with town on hole conditions 8/3/2016 8/3/2016 4.95 PROD1 DRILL DRLG P 10,340 ft,BOBD 1.51 bpm at 3,900 10,340.0 10,492.0 13:33 18:30 psi,BHP 3966,WHP 262, 1.3= DHWOB,-4k=CTSW IA 0,OA 48. pull 200 ft wiper,PUW 38k. ****Note: 10,380 ft started lossing 15 bpm and slowly healed up to 2-4 bph. 8/3/2016 8/4/2016 5.50 PROD1 DRILL DRLG P 10,492 ft. BOBD for data 1.50 bpm at 10,492.0 10,683.0 18:30 00:00 3,874 psi FS,BHP 3,972 psi,CWT 3k, WOB 1.7k,ROP 45.pulled four 200 ft wipers with PUW's 35 to 38k,pumped 2, 10 bbl beaded pills. ****Note: 19:45 Lossing 10-12 bph, confer with town,following 11.8 ppg trip schedule at 10,540 ft,losing 4-6 bph. 8/4/2016 8/4/2016 3.10 PROD1 DRILL DRLG P 10,683 ft. OBD 1.5 bpm at 3,846 psi 10,683.0 10,705.0 00:00 03:06 FS,BHP 3,930 psi,CWT-3k,WOB 1.2k,ROP 35,WHP 194,IA 0,OA 50. 8/4/2016 8/4/2016 2.90 PROD1 DRILL TRIP T 10,705 ft.Data TD called-POOH, 10,705.0 72.2 03:06 06:00 PUW 33k,Pull heavy at 10,050 ft, work to 10,000 ft,bit stuck momentarily,down on pump,PU slowly through tight area to 9,950 ft, Jog at EOB.Log HRZ for plus 8 ft correction,continue POOH. 8/4/2016 8/4/2016 2.50 PROD1 DRILL PULD T PJSM-PUD/LD BHA#6,checks aren't 72.2 0.0 06:00 08:30 holding do to beads,continue PUD with open EDC,attempt to bleed down thru bleed port,bleed port plugged with beads,line up to confirm coil is bled down to 0 pressure,flush out bleed port,continue PUD,LD drilling BHA 8/4/2016 8/4/2016 0.75 PROD1 DRILL PULD T PU/MU,Coiltrak tools and BOT setting 0.0 0.0 08:30 09:15 tools with Open hole anchored billet. Page 6/26 Report Printed: 8/29/2016 • • Operations Summary (with Timelog Depths) 1L-17 +Ccxxx. Phitli • Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Lag Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (MKS) End Depth(ftKB) 8/4/2016 8/4/2016 1.50 PROD1 STK PULD T PJSM,inspect checks in upper quick, 0.0 72.9 09:15 10:45 upper checks PD Open Hole Anchored Billet 8/4/2016 8/4/2016 1.50 PROD1 STK TRIP T RIH,with BHA#7 open hole anchored 72.9 7,945.0 10:45 12:15 billet 8/4/2016 8/4/2016 0.25 PROD1 STK DLOG T 7945 ft,tie into the HRZ correction of 7,945.0 7,965.0 12:15 12:30 plus 8.5 ft,PUW 31k 8/4/2016 8/4/2016 0.75 PROD1 STK TRIP T 7965 ft,close EDC,continue IH 7,965.0 8,236.0 12:30 13:15 8/4/2016 8/4/2016 1.50 PROD1 STK TRIP T 8,236 ft,Set down 6k DHWOB,3k 8,236.0 72.9 13:15 14:45 CTSW,PUH clean dragging 1.5k, pulling clean 8,228 ft,RBIH,set down again,dragging 1.3-1.0k DHWOB, PUH thru window,open EDC,POOH to surface for a clean out run. 8/4/2016 8/4/2016 1.35 PROD1 STK PULD T PJSM,undeploy setting tools and 72.9 0.0 14:45 16:06 open hole anchored billet. 8/4/2016 8/4/2016 0.40 PROD1 STK PULD T Inspect billet assembly,LD setting 0.0 16:06 16:30 tools, 8/4/2016 8/4/2016 1.65 PROD1 STK BOPE P Function test BOPE.Pressure test DS 0.0 0.0 16:30 18:09 PDL back from Tuboscope.Service Choke and BOP stack 8/4/2016 8/4/2016 1.15 PROD1 STK PULD T PJSM-PU/MU/PD cleanout BHA#8, 0.0 62.6 18:09 19:18 0.4°AKO motor and same HYC Bi- center bit,check packoffs, MU to CoilTrak,surface test. 8/4/2016 8/4/2016 1.60 PROD1 STK TRIP T RIH with BHA#8,EDC open 62.6 7,945.0 19:18 20:54 8/4/2016 8/4/2016 0.45 PROD1 STK DLOG T 7,945 ft. Log at HRZ questionable, 7,945.0 8,092.0 20:54 21:21 close EDC,PUW 31k,tie in at K1 for plus 16.5 ft correction 8/4/2016 8/4/2016 0.75 PROD1 STK TRIP T RIH,clean thru window,zero 8,092.0 9,800.0 21:21 22:06 correction passing RA,clean thru build area,pump 10x10 to/hi,clean to 9,800 ft. 8/4/2016 8/5/2016 1.90 PROD1 STK WPRT T Wiper trip up hole,PUW 30k 10x10 9,800.0 2,560.0 22:06 00:00 out bit,300 ft jog at EOB,PUW 29k, chase sweeps to swab,clean thru window and pilot hole,continue POOH to 2,560 ft as of midnight. 8/5/2016 8/5/2016 0.75 PROD1 STK WPRT T Continue POOH,300 ft jog at 1,000 ft. 2,560.0 62.6 00:00 00:45 POOH to surface 8/5/2016 8/5/2016 2.00 PROD1 STK PULD T PJSM-PUD/LD BHA#8,bit in good 62.6 0.0 00:45 02:45 shape,pies in folder.MU and load BHA#9 in PDL,change out 2 failed lubricator o-rings(30 minutes),stab on well 8/5/2016 8/5/2016 1.40 PROD1 STK PULD T PJSM- PD BHA#9,OH anchored . 0.0 72.9 02:45 04:09 billet,MU to CoilTrak,surface test. 8/5/2016 8/5/2016 2.00 PROD1 STK TRIP T RIH with BHA#9 EDC open. 72.9 7,945.0 04:09 06:09 8/5/2016 8/5/2016 0.25 PROD1 STK DLOG T 7,945 ft,tie into the HRZ correction of 7,945.0 7,966.0 06:09 06:24 plus 9.0 ft. PUW 32 k. Page 7/26 Report Printed: 8/29/2016 • S = Operations Summary (with Timelog Depths) • ,tom:1,:< 1L-17 Conoc Phiilips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(Er) Phase Op Code Activity.Code Time P-T-X Operation (EKE) End Depth(EKE) 8/5/2016 8/5/2016 1.25 PROD1 STK WPST T 7,966 ft,continue RIH at 25 fpm,close 7,966.0 9,220.0 06:24 07:39 EDC at 7,975 ft,weight bobble of +1.5k at 8236 ft,seeing weight bobbles of 0.5-3.5k from 8,236 ft to 9,237 ft.,hard set down at 9,237 ft, PUW 34 k,minus 4.5 k-5 k.RBIH, set down 5 k,confer with town team on plan forward,decisoin was made to set TOB at 9,220 ft.Bring pump up to 4740 psi setting tools sheared,set down 5 k.PUW 31 k. 8/5/2016 8/5/2016 2.25 PROD1 STK TRIP T 9,220 ft.POOH following MP, 9,220.0 72.9 07:39 09:54 pumping 1.0 bpm at 2,472 psi,IA 0, OA 38 8/5/2016 8/5/2016 2.00 PROD1 STK PULD T At surface,PJSM,undeploy/LD setting 72.9 0.0 09:54 11:54 tools. 8/5/2016 8/5/2016 0.75 PROD1 STK PULD T MU/PU kickoff/drilling BHA#9,load 0.0 0.0 11:54 12:39 PDL • 8/5/2016 8/5/2016 1.00 PROD1 STK CTOP T Swap BHI upper quick out due to hrs 0.0 0.0 12:39 13:39 TT 235 hr 8/5/2016 8/5/2016 1.25 PROD1 STK PULD T PD kickoff/drilling BHA 0.0 72.2 13:39 14:54 8/5/2016 8/5/2016 1.50 PROD1 STK TRIP T RIH,kickoff/drilling BHA w/0.4 ako 72.2 7,945.0 14:54 16:24 bend motor and RB bi-center bit. 8/5/2016 8/5/2016 0.25 PROD1 STK DLOG T 7,945 ft,tie into the HRZ correction of 7,945.0 7,964.0 16:24 16:39 plus 8.5 ft.PUW 31k 8/5/2016 8/5/2016 0.75 PROD1 STK TRIP T 7,964 ft,continue RIH,clean thru 7,964.0 9,222.0 16:39 17:24 window,dry tag billet at 9,222 ft.PUH 33k,establish drilling parameters,RIH 8/5/2016 8/5/2016 4.35 PROD1 STK KOST T 9,222 ft. Kick off billet per 9,222.0 9,250.0 17:24 21:45 recomended practice,4 stalls before establishing pattern,more stalls at 9,226 ft,9,227 ft and 9,228 ft,PUW's 34k,drill to 9,250 ft,PUH 34k,dry drift billet clean.pump 5x5 sweep.start new mud down hole. 8/5/2016 8/5/2016 1.25 PROD1 DRILL DRLG T 9,250 ft. OBD 1.52 bpm at 3,540 psi 9,250.0 9,296.0 21:45 23:00 FS,BHP 3,800 psi,CWT 9.8k,WOB 1.2k, ROP 37. **Note:New 8.6 ppg mud out bit at 9,260 ft. 8/5/2016 8/6/2016 1.00 PROD1 DRILL DRLG T 9,296 ft. New mud around, PU restart 9,296.0 9,335.0 23:00 00:00 1.65 bpm at 3,550 psi FS, BHP 3,807 psi,CWR 9.8k,WOB 1.1k, ROP 55 8/6/2016 8/6/2016 4.75 PROD1 DRILL DRLG T 9,335 ft. OBD 1.65 bpm at 3,550 psi 9,335.0 9,470.0 00:00 04:45 FS,BHP 3,810 psi,CWR 9.8k,WOB 1.1k,ROP 55,WHP 559,IA 0,OA 43 8/6/2016 8/6/2016 0.35 PROD1 DRILL WPRT T Short wiper to billet,RBIH 9,470.0 9,470.0 04:45 05:06 8/6/2016 8/6/2016 7.00 PROD1 DRILL DRLG T 9,470 ft,OBD 1.64 bpm at 3,770 psi 9,470.0 9,730.0 05:06 12:06 FS,BHP 3,790 psi,CWT 8.9k, WOB.9k,ROP 39 8/6/2016 8/6/2016 0.35 PROD1 DRILL WPRT T 9730 ft,wiper up hole PUW 36 k. 9,730.0 8,215.0 12:06 12:27 8/6/2016 8/6/2016 0.60 PROD1 DRILL DLOG T Tie into the RA correction of plus 6.0 8,215.0 8,240.0 12:27 13:03 ft. Page 8/26 Report Printed: 8/29/2016 • • Operations Summary (with Timelog Depths) ri-ii";141r 1 L-17 conocot mps .. Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity' Code Time P-T-X Operation (ftKB) End Depth(ftKS) 8/6/2016 8/6/2016 0.20 PROD1 DRILL WPRT T Perform choke calibration at 8,233 ft, 8,240.0 8,240.0 13:03 13:15 hold 3,665 psi BHP,(11.8ppg), 1.51 bpm in, 1.46 bpm out,361 psi choke pressure,3,523 pump pressure. 8/6/2016 8/6/2016 0.55 PROD1 DRILL WPRT T 8,233 ft,wiper back in hole RIW 10 k 8,240.0 9,730.0 13:15 13:48 • 8/6/2016 8/6/2016 4.20 PROD1 DRILL DRLG T 9,730 ft, BOBD 1.58 bpm at 3,660 psi 9,730.0 9,850.0 13:48 18:00 FS,BHP 3,785,WHP 350,IA 0,OA 51,New trip schedule to 11.6 at window, NOTE:Changed from highline to gen power @ 14:50 8/6/2016 8/7/2016 6.00 PROD1 DRILL DRLG T 9,850 ft. OBD 1.56 bpm at 3,713 psi 9,850.0 9,921.0 18:00 00:00 FS,BHP 3,776 psi,CWT 3.8k,WOB 1.5k,ROP 8,hard drilling,pump 5x5, 200 ft wiper at 9,892 ft, ROP picked up to 40. 8/7/2016 8/7/2016 2.10 PROD1 DRILL DRLG T 9,920 ft. OBD 1.56 bpm at 3,720 psi 9,920.0 9,980.0 00:00 02:06 FS,BHP 3,845 psi,CWT 7.5k,WOB 1.1k,ROP 37,WHP 305, IA 0,OA 53, pump 5x5. 8/7/2016 8/7/2016 0.50 PROD1 DRILL WPRT T Wiper up hole to 8,900 ft, PUW 35k. 9,980.0 8,900.0 02:06 02:36 8/7/2016 8/7/2016 0.50 PROD1 DRILL WPRT T Wiper back in hole,RIW 10.2k 8,900.0 9,980.0 02:36 03:06 8/7/2016 8/7/2016 3.15 PROD1 DRILL DRLG T 9,980 ft. BOBD 1.56 at 3,746 psi FS, 9,980.0 10,058.0 03:06 06:15 BHP 3,784 psi,CWT 8.0k,WOB 1.7k, ROP 35. Losses-2 bph. 8/7/2016 8/7/2016 0.10 PROD1 DRILL WPRT T 200'wiper up hole, PUW 32k. 10,058.0 9,860.0 06:15 06:21 8/7/2016 8/7/2016 0.15 PROD1 DRILL WPRT T Wiper back in hole,RIW 9.7k. 9,860.0 10,057.0 06:21 06:30 8/7/2016 8/7/2016 2.10 PROD1 DRILL DRLG T BOBD, 1.4 BPM @ 3410 psi FS, BHP 10,057.0 10,111.0 06:30 08:36 4090 psi,CTSW 9.7k,WOB 1.3k, ROP 26. 8/7/2016 8/7/2016 0.15 PROD1 DRILL WPRT T 200'wiper up hole,PUW 32k. 10,111.0 9,910.0 08:36 08:45 8/7/2016 8/7/2016 0.15 PROD1 DRILL WPRT T Wiper back in hole,RIW 6.9k. 9,910.0 10,111.0 08:45 08:54 8/7/2016 8/7/2016 2.40 PROD1 DRILL DRLG T BOBD, 1.68 BPM @ 4175 psi FS, 10,111.0 10,202.0 08:54 11:18 BHP 4470 psi,CTSW 6.9k,WOB 1.3k, ROP 16. 8/7/2016 8/7/2016 0.10 PROD1 DRILL WPRT T 200'wiper up hole,PUW 34k. 10,202.0 10,000.0 11:18 11:24 8/7/2016 8/7/2016 0.10 PROD1 DRILL WPRT T Wiper back in hole,RIW 7.2k. 10,000.0 10,202.0 11:24 11:30 8/7/2016 8/7/2016 0.50 PROD1 DRILL DRLG T BOBD, 1.61 BPM @ 3900 psi FS, 10,202.0 10,209.0 11:30 12:00 BHP 4355 psi,CTSW 7.2k,WOB 7.2k,ROP 14.Losses-2 bph. 8/7/2016 8/7/2016 3.75 PROD1 DRILL DRLG T PUH,PUW 43k,WOB-5k.Working 10,209.0 10,250.0 12:00 15:45 back to bottom,several stalls,PUWs 40-43k.Losses increased to 1 bpm. Lowered annular pressure target from 11.6 to 11.5 ppg equivalent. 8/7/2016 8/7/2016 0.15 PROD1 DRILL WPRT T 200'wiper after motor stall,PUW 40k. 10,250.0 10,050.0 15:45 15:54 Lost returns while PUH. 8/7/2016 8/7/2016 0.20 PROD1 DRILL WPRT T Wiper back in hole,RIW 8.6k.Full 10,050.0 10,250.0 15:54 16:06 losses, 1.58 bpm @ 3700 psi FS. Page 9/26 Report Printed: 8/29/2016 40 �. Operations Summary (with Timelog Depths) Ko ,w ` 1L-17 Cone►catkiiiips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth start Time End Time Dur(hr) _ Phase Op Code Activity Code Time P-T-X Operation {ftKS) End Depth(ftKB) 8/7/2016 8/7/2016 0.40 PROD1 DRILL DRLG T BOBD,low ROP,no returns. 10,250.0 10,254.0 16:06 16:30 8/7/2016 8/7/2016 0.40 PROD1 DRILL WPRT T 1000'wiper up hole,PUW 43k.Full 10,254.0 9,260.0 16:30 16:54 losses.confer with town.WHP increasing to 900 psi?BHP stable at 3,570 psi,choke closed. 8/7/2016 8/7/2016 1.65 PROD1 DRILL WPRT T Wiper back in hole,RIW 11k,open 9,260.0 10,252.0 16:54 18:33 choke to 400 psi,getting.25 bpm returns pumping 1.3 bpm,confer with town on path forward. 8/7/2016 8/7/2016 4.50 PROD1 DRILL DRLG T BOBD 1.57 bpm at 3,720 psi FS, 10,252.0 10,347.0 18:33 23:03 BHP 3,842 psi,CWT 10k,WOB 1.7k, ROP 20,returns short lived,stall at 10,255 ft,drilling ahead full losses 1.6 bpm at 3,554 psi FS,BHP 3,621 psi, CWT 10k,WOP 1.2k,ROP 24,losing 90+bph Stalls at 10,227 ft, 10,283 ft, 10,287 ft and 10,300 ft 8/7/2016 8/7/2016 0.40 PROD1 DRILL WPRT T Stall at 10,347 ft, PU 37k 100 ft,RBIH, 10,347.0 10,347.0 23:03 23:27 stacked at 10,257 ft, 10,309 ft and 10,322 ft,lowered pump rate to get to bottom. Note:confer with town,pump 10 bbl 100k LSRV pill. 8/7/2016 8/7/2016 0.40 PROD1 DRILL DRLG T BOBD 1.66 bpm at 3,540 psi FS,BHP 10,347.0 10,353.0 23:27 23:51 3,604 psi,CWT11.0k,WOB 1.0k, . ROP 16 8/7/2016 8/8/2016 0.15 PROD1 DRILL WPRT T PUH slow while Hi-visc pill exits bit, 10,353.0 10,353.0 23:51 00:00 PUW 35k,seen drag at 10,340 ft.Hi- visc pill out, BHP to 3,628 and climbing, RBIH, 8/8/2016 8/8/2016 1.00 PROD1 DRILL DRLG T BOBD 1.6 bpm at 3,573 psi FS,BHP 10,353.0 10,370.0 00:00 01:00 3,643 psi,CWT 11.4k,WOB 0.6k, ROP 22,WHP 750,IA 0,OA 50,BHP droping back to 3,616 psi,pump another 13 bbl 100k Hi-visc pill 8/8/2016 8/8/2016 0.25 PROD1 DRILL WPRT T PU while Hi-visc pill exits bit,RBIH, 10,370.0 10,370.0 01:00 01:15 RIW 11k. 8/8/2016 8/8/2016 1.90 PROD1 DRILL DRLG T BOBD 1.5 bpm at 3,325 psi FS,BHP 10,370.0 10,434.0 01:15 03:09 6,345 psi,CWT 11k,WOB, 1.3k,ROP 22.BHP slowly coming up,stabilized at 3,680 psi.Pump 24 bbl of 100k Hi- viscpill. 8/8/2016 8/8/2016 0.50 PROD1 DRILL WPRT T Short wiper up to 10,350 ft, WHP 834 10,434.0 10,434.0 03:09 03:39 psi to 1072 psi,BHP 3,680 psi to 3,606 psi,RBIH,RIW 11.3k. 8/8/2016 8/8/2016 1.75 PROD1 DRILL DRLG T BOBD 1.4 bpm at 3,856 psi FS,BHP 10,434.0 10,480.0 03:39 05:24 3,638 psi,CWT 10k,WOB 1.3k,ROP 18,PU while pill exits bit, BHP to 3,710 psi,RBIH,OBD 1.43 bpm at 3,200 FS,BHP 3,668 psi,CWT 10k, WOB.8 to 1.5k, ROP 10-40 8/8/2016 8/8/2016 1.00 PROD1 DRILL WPRT T 10480 ft,Wiper up hole to window , 10,480.0 8,210.0 05:24 06:24 PUW 41k 8/8/2016 8/8/2016 0.25 PROD1 DRILL DLOG T 8210 ft,Tie into the RA marker 8,210.0 8,228.0 06:24 06:39 correction of plus 9.0 ft, 8/8/2016 8/8/2016 1.00 PROD1 DRILL WPRT T 8228 ft,wiper back in hole RIW 10.2k 8,228.0 10,480.0 06:39 07:39 Page 10/26 Report Printed: 8/29/2016 • Operations Summary (with Timelog Depths) 1 L-17 Conocxit'°hilllps Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log • Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code'. Time P-T-X Operation (MKS),, End,Depth MKS) 8/8/2016 8/8/2016 4.00 PROD1 DRILL DRLG T 10480 ft,BOBD 1.4 bpm at 3290 psi, 10,480.0 10,622.0 07:39 11:39 BHP 3690,WHP 768,IA 0,OA 62 8/8/2016 8/8/2016 0.80 PROD1 DRILL WPRT T 10,622 ft,do to 100%losses and not 10,622.0 8,210.0 11:39 12:27 being able to obtain objectives, decision was made to POOH,for Plug back,PUW 36k 8/8/2016 8/8/2016 0.25 PROD1 DRILL DLOG T 8,210 ft,Tie into the RA correction of 8,210.0 8,230.0 12:27 12:42 plus 3.0 ft, 8/8/2016 8/8/2016 0.75 PROD1 DRILL WPRT T 8,230 ft,RIH to clean hole down past 8,230.0 9,900.0 12:42 13:27 setting depth. 8/8/2016 8/8/2016 0.75 PROD1 DRILL WPRT T 9900 ft,POOH,chasing 5x5 sweep up 9,900.0 8,048.0 13:27 14:12 to the window,losing 100%returns, pumping 1.4 bpm 8/8/2016 8/8/2016 0.25 PROD1 DRILL TRIP T 8,048 ft,Park and perform static 8,048.0 8,048.0 14:12 14:27 pressure survey,788 psi WHP,3270 psi AP 8/8/2016 8/8/2016 1.25 PROD1 DRILL TRIP T POOH,pumping 1.57 bpm at 3,500 8,048.0 72:2 14:27 15:42 psi 8/8/2016 8/8/2016 2.00 PROD1 DRILL PULD T PJSM-PUD/LD BHA#10,bit 72.2 0.0 15:42 17:42 condition-2-1-CT-N-X-I-NO-FM, reconfigure BHA for IBP run. 8/8/2016 8/8/2016 1.00 PROD1 DRILL WAIT T Wait on Weatherford IBP coming from 0.0 0.0 17:42 18:42 Prudhoe. 8/8/2016 8/8/2016 3.00 PROD1 DRILL PULD T Bring in Weatherford tools,PJSM- 0.0 48.8 18:42 21:42 MU/PD 2.125"IBP,FVS noticed in, BHA needs to be removed,PJSM- Scope change.PUD,and remove FVS from BHA,PJSM-PD IBP MU to CoilTrak,surface test. 8/8/2016 8/8/2016 1.60 PROD1 DRILL TRIP T RIH with BHA#11 EDC open 48.8 7,910.0 21:42 23:18 8/8/2016 8/8/2016 0.35 PROD1 DRILL DLOG T Tie in to HRZ for plus 8 ft correction. 7,910.0 7,970.0 23:18 23:39 8/8/2016 8/9/2016 0.35 PROD1 DRILL TRIP T RIH,clean thru window. 7,970.0 8,640.0 23:39 00:00 8/9/2016 8/9/2016 0.70 PROD1 DRILL TRIP T Continue RIH with IBP BHA#11 EDC 8,640.0 9,858.0 00:00 00:42 open pumping.5 bpm,annulus 3,473 psi 8/9/2016 8/9/2016 1.20 PROD1 DRILL PACK T On depth,shut down pump,close 9,858.0 9,858.0 00:42 01:54 EDC,climatize IBP 40 minutes,BHP 3,460 psi down to 3,275 psi(10.7 ppg equivalent) temp 114°to 128°, differential stable at 395 psi,set IBP in stages,appeares to have set early at 600 psi diff,pinned for 1,800 psi diff. Pick off clean. 8/9/2016 8/9/2016 2.60 PROD1 DRILL TRIP T POOH,attempt to get to 11.4 ppg 9,858.0 48.8 01:54 04:30 equivalent trip schedule,losing-1 bpm coming out of hole,confer with town,stop at 8,040 ft(5,880 ft TVD at DPS)on line 1.5 bpm,hold 3,473 psi at DPS depth(5,880 ft TVD=11.4 ppg EMW)stabilize out at 1.5 bpm in, .9 bpm out, 1 bpm losses.continue POOH while town gets plan forward. 8/9/2016 8/9/2016 2.00 PROD1 DRILL PULD T PJSM-PUD/LD BHA#11,IBP still on 48.8 0.0 04:30 06:30 BHA,inform town 8/9/2016 8/9/2016 1.50 PROD1 DRILL PULD T Inspect/change pac-offs,service INJH, 0.0 0.0 06:30 08:00 Weatherforrd to inspect bands and packer element, Page 11/26 Report Printed: 8/29/2016 a 0 Operations Summary (with Timelog Depths) 1 L-17 ituu Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(EKE)'.. 8/9/2016 8/9/2016 2.00 PROD1 DRILL PULD T PJSM,PD second IBP 0.0 48.8 08:00 10:00 8/9/2016 8/9/2016 1.75 PROD1 DRILL TRIP T RIH,with open EDC pumping 0.5 bpm 48.8 7,940.0 10:00 11:45 at 1700 psi,trying to maintain 11.4 ppg MP schedule. 8/9/2016 8/9/2016 0.25 PROD1 DRILL DLOG T 7940 ft,log HRZ correction of 9.5 ft 7,940.0 7,952.8 11:45 12:00 8/9/2016 8/9/2016 1.50 PROD1 DRILL TRIP T Continue RIH to setting depth,. 7,952.8 9,303.0 12:00 13:30 8/9/2016 8/9/2016 0.50 PROD1 DRILL PACK T At depth, PU to free weight.Close 9,303.0 9,303.0 13:30 14:00 EDC.Temp 110°.Wait for temp to stabilize, 126°.Differential 492 psi. WHP 664 psi. 8/9/2016 8/9/2016 1.50 PROD1 DRILL PACK T Begin staging up to set IBP. 9,303.0 9,303.0 14:00 15:30 Pump Pres:800 psi, Diff:468 psi,bled down-not good Pump Pres: 1500 psi,Diff:492 psi bled towards 0 psi. Pump Pres:2000 psi,Diff:645 psi bled towards 0 psi. Pump Pres:2000 psi,Diff:638 psi, bled towards 0 psi. Pump Pres:2000 psi,Diff: 1005 psi, bled towards 0 psi. Pump Pres:3000 psi,Diff: 1443 psi, bled towards 0 psi. Pumped up to 1800 psi Diff,and tried to pull off tool(req 4000 psi overpull). No indication that it worked. 8/9/2016 8/9/2016 2.25 PROD1 DRILL TRIP T Decision made to POOH w/EDC 9,303.0 48.8 15:30 17:45 closed,sleeve on IBP tool closed, pumping down the backside to maintain 11.4ppg MP schedule. 8/9/2016 8/9/2016 1.75 PROD1 DRILL PULD T PJSM,PUD/LD BHA#12. 48.8 0.0 17:45 19:30 Weatherford IBP tool at surface,outer rubber split down the length of tool, inner bladder hole @ bottom of element. 8/9/2016 8/9/2016 1.00 PROD1 DRILL WAIT T Discuss path forward with town. 0.0 0.0 19:30 20:30 Compare Weatherford(damaged)and Baker tools side by side. 8/9/2016 8/9/2016 3.00 PROD1 DRILL PULD T PJSM,PU/PD BHA#13(BOT 0.0 55.4 20:30 23:30 inflatable cement retainer plug). Attempt to deploy with ball on seat and EDC open.Would have resulted in single barrier deployment.PU and close EDC.Redeploy BHA. 8/9/2016 8/10/2016 0.50 PROD1 DRILL TRIP T Bump up. Reset depth. RIH with BHA 55.4 2,000.0 23:30 00:00 #13 with EDC open. 8/10/2016 8/10/2016 1.25 PROD1 DRILL TRIP T Continue running in the hole with BHA 2,000.0 7,775.0 00:00 01:15 #13,Inflatable cement retainer with ball on seat. 8/10/2016 8/10/2016 1.00 PROD1 DRILL TRIP T While running in the hole at 7775 ft, 7,775.0 7,775.0 01:15 02:15 LEL alarm indicated gas at the shaker. Closed the choke. LEL quickly dropped off. 8/10/2016 8/10/2016 1.25 PROD1 DRILL TRIP T Lined up to the tiger tank,brought 7,775.0 9,905.0 02:15 03:30 pump back online and continued in the hole to ICR set depth.Tied in to the HRZ for a+9.5 ft crrection. Page 12/26 Report Printed: 8/29/2016 el 0 Operations Summary (with Timelog Depths) ' .,44 s 1L-17 C.onocoPhillips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB)', 8/10/2016 8/10/2016 0.25 PROD1 DRILL PACK T Wt check=34 Klbs.Close EDC. 9,905.0 9,905.0 03:30 03:45 Stage up pump and shear ball seat at 3600 psi.Pull up to release from ICR. Pins sheared at 46 Klbs CTW. 8/10/2016 8/10/2016 0.75 PROD1 DRILL CIRC T PUH.Circulate gas cut mud out to 9,905.0 8,050.0 03:45 04:30 tiger tank. 8/10/2016 8/10/2016 2.00 PROD1 DRILL TRIP T Continue POOH,slowly circulating 8,050.0 7,450.0 04:30 06:30 bottoms up. 8/10/2016 8/10/2016 1.00 PROD1 DRILL TRIP T 7450 ft,POOH with setting tools, 7,450.0 55.5 06:30 07:30 BHA#13 8/10/2016 8/10/2016 1.00 PROD1 DRILL PULD T At surface,PJSM,undeploy setting 55.5 0.0 07:30 08:30 tools, 8/10/2016 8/10/2016 0.50 PROD1 DRILL PULD T Reconfigure BHA,with HOT,DGS, 0.0 0.0 08:30 09:00 and FVS 8/10/2016 8/10/2016 1.25 PROD1 STK PULD T PJSM,PD Open Hole Anchored Billet. 72.9 72.9 09:00 10:15 8/10/2016 8/10/2016 1.50 PROD1 STK TRIP T RIH,with open hole anchored billet 72.9 7,940.0 10:15 11:45 BHA#14 8/10/2016 8/10/2016 0.25 PROD1 STK DLOG T Log the HRZ correction of plus 7.5 ft. 7,950.0 7,970.0 11:45 12:00 PUW 30k 8/10/2016 8/10/2016 0.75 PROD1 STK TRIP T 7970 ft,continue RIH thru window 7,970.0 9,176.8 12:00 12:45 8/10/2016 8/10/2016 0.25 PROD1 STK WPST T 9,165 ft,Set TOB,bring pump up,tool 9,176.8 9,176.8 12:45 13:00 sheared at 4600 psi,PUW 31k, 8/10/2016 8/10/2016 1.75 PROD1 STK TRIP T POOH,pumping 0.68 bpm at 1866 psi 9,176.8 79.0 13:00 14:45 8/10/2016 8/10/2016 1.50 PROD1 STK PULD T PJSM,PUD BHA#14.LD BHA 79.0 0.0 14:45 16:15 components. 8/10/2016 8/10/2016 3.50 PROD1 WHDBOP RURD P Clean and clear rig floor in preparation 0.0 0.0 16:15 19:45 for BOP test.MU nozzle.Flush stack, flush surface lines. Valve crew on location greasing tree valves. Crew change. 8/10/2016 8/11/2016 4.25 PROD1 WHDBOP BOPE P Shell test BOP to 500 psi. Inner reel 0.0 0.0 19:45 00:00 valve test to 3750 psi.Begin Bi Weekly BOPE test.State witness waived by AOGCC Matt Herrera. Back on MP after Test#9,WHP 670 psi when lining back up on well. 8/11/2016 8/11/2016 4.00 PROD1 WHDBOP BOPE P Complete bi-weekly BOPE test. 0.0 0.0 00:00 04:00 Witness waived by AOGCC Matt Herrera.No failures. 8/11/2016 8/11/2016 0.75 PROD1 STK CIRC P MU injector. Displace coil back to , 0.0 0.0 04:00 . 04:45 drilling mud. 8/11/2016 8/11/2016 1.50 PROD1 STK PULD T PD,drilling BHA 0.0 72.2 04:45 06:15 8/11/2016 8/11/2016 2.00 PROD1 STK PULD T RIH,with kickoff/drilling BHA#15 with 0.0 7,925.0 06:15 08:15 0.4°ako motor. ""Note:7,899.21 ft.stack out weight, PUH clean rotate TF from low side to high side.passed thru clean. 8/11/2016 8/11/2016 0.30 PROD1 STK DLOG T 7,925 ft,tie into the HRZ correction of 7,925.0 7,966.0 08:15 08:33 plus 7.5 ft.PUW 30k Page 13/26 Report Printed: 8/29/2016 0 • Operations Summary (with Timelog Depths) 1 L-17 Conocoi;hilliprs Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth eStart Trine End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 8/11/2016 8/11/2016 1.15 PROD1 STK TRIP T Continue RIH 7,966.0 9,165.0 08:33 09:42 ""*"Note:Pressure survey at 8,048 ft. (censor depth 8,005 ft.(5,849 TVD w/130 ft RKB),shut choke in,monitor pressures for 15 min,Annular pressure 3,407,choke pressure 794,= 11.199 ppg. 8/11/2016 8/11/2016 4.20 PROD1 'STK KOST T Dry tag TOB @ 9,165 ft PUW 35k, 9,165.0 9,220.0 09:42 13:54 bring pump up kickoff billet,1.54 bpm at 3,400 psi FS,BHP 3,650,WHP 394, IA 0,OA 0 • ""Note:stall motor getting started. 8/11/2016 8/11/2016 0.35 PROD1 STK DRLG T PUH,clean dry drift across billet. 9,220.0 9,220.0 13:54 14:15 Small WOB bobble when PUH through billet @ 0.3 bpm. 8/11/2016 8/11/2016 4.00 PROD1 DRILL DRLG T BOBD, 1.5 bpm @ 3800 psi,CTW 7- 9,220.0 9,434.0 14:15 18:15 9KIbs,WOB 1.1, ROP 40-80 fph. New 8.5ppg FloPro Mud System#3 at the bit @ 9,256'. 8/11/2016 8/11/2016 0.50 PROD1 DRILL WPRT T PUH fora short wiper. 9,434.0 9,434.0 18:15 18:45 8/11/2016 8/11/2016 1.75 PROD1 DRILL DRLG T BOBD, 1.5 bpm @ 4200 psi downhole 9,434.0 9,565.0 18:45 20:30 bore pressure,CTSW 8.1k,WOB 1.1, ROP 100 8/11/2016 8/11/2016 0.50 PROD1 DRILL WPRT T PUH for planned wiper trip to 8420 ft. 9,565.0 9,565.0 20:30 21:00 PUW 34Klbs.Clean trip up and down 8/11/2016 8/12/2016 3.00 PROD1 DRILL WPRT T BOBD, 1.6 bpm @ 3900 psi,CTW 5- 9,565.0 9,681.0 21:00 00:00 6KIbs,WOB 1.3KIbs, ROP variable between30-120 fph. 8/12/2016 8/12/2016 1.00 PROD1 DRILL DRLG T BOBD, 1.8 bpm @ 3900 psi,CTW 9,681.0 9,708.0 00:00 01:00 7KIbs,WOB 2KIbs,ROP variable between 30 fph. 8/12/2016 8/12/2016 0.50 PROD1 DRILL TRIP T GR track showing possible 9,708.0 9,708.0 01:00 01:30 communication fault.MAD pass interval from 9650 to 9700. Could not get repeatable results.Made decsion to POOH and swap tools. 8/12/2016 8/12/2016 2.00 PROD1 DRILL TRIP T POOH with BHA#15. 9,708.0 72.0 01:30 03:30 8/12/2016 8/12/2016 1.50 PROD1 DRILL PULD T At surface.PUD and LD BHA#15. 72.0 0.0 03:30 05:00 8/12/2016 8/12/2016 1.00 PROD1 DRILL PULD T PU/PD,BHA#16.0.4°AKO motor and 0.0 72.3 05:00 06:00 RB HCC bit. 8/12/2016 8/12/2016 1.50 PROD1 DRILL TRIP T RIH,with BHA#16,open EDC. 72.3 7,925.0 06:00 07:30 8/12/2016 8/12/2016 0.25 PROD1 DRILL DLOG T 7,925 ft,log the HRZ correction of plus 7,925.0 7,964.0 07:30 07:45 7.5 ft.PUW 33k,close EDC 8/12/2016 8/12/2016 0.75 PROD1 DRILL TRIP T Continue RIH to bottom 7,964.0 9,708.0 07:45 08:30 8/12/2016 8/12/2016 0.25 PROD1 DRILL DLOG T 9,708 ft.PUH,log up to 9,615 ft. 9,708.0 9,615.0 08:30 08:45 8/12/2016 8/12/2016 0.25 PROD1 DRILL DRLG T 9,615 ft,RIH to bottom 9,615.0 9,710.0 08:45 09:00 Page 14/26 Report Printed: 8/29/2016 • 0 Operations Summary (with Timelog Depths) 0, 1L-17 OanocciPhillips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation , (EKE) End Depth MKS) 8/12/2016 8/12/2016 4.50 PROD1 DRILL DRLG T 9,710 ft.,OBD 1.59 bpm at 3660 psi 9,710.0 9,845.5 09:00 13:30 FS,BHP 3718,WHP 294, IA 0,OA 43 "**Note:7.5 NPT Time Tool Failure BHI 8/12/2016 8/12/2016 2.00 PROD1 DRILL DRLG T 9,845 ft,OBD 1.57 bpm at 3,868 psi, 9,845.5 9,910.0 13:30 15:30 BHP 3755,WHP 291, IA 0,OA 47 8/12/2016 8/12/2016 2.75 PROD1 DRILL DRLG T 9,907 ft,OBD 1.59 bpm at 3,872 psi, 9,910.0 9,960.0 15:30 18:15 BHP 3763,WHP 290, IA 0,OA 48, 6k=CTSW, 1.5k=DHWOB,average ROP 30 fph. 8/12/2016 8/12/2016 0.75 PROD1 DRILL WPRT T PUH for wiper trip to 9196 ft. PUW= 9,960.0 9,960.0 18:15 19:00 37 Klbs. Clean trip up and down. 8/12/2016 8/13/2016 5.00 PROD1 DRILL DRLG T BOBD. 1.61 BPM at 4000 psi.WOB 9,960.0 10,052.0 19:00 00:00 1.9 Klbs.BHP 3728 psi.WHP 250 psi. CTSW=4-8 Klbs.ROP 10-30 fph. 8/13/2016 8/13/2016 5.50 PROD1 DRILL DRLG T Drilling ahead. 1.61 BPM at 4080 psi. 10,052.0 10,180.0 00:00 05:30 WOB 2 Klbs.BHP 3750 psi.WHP 190 psi.CTSW=4-8 Klbs.ROP 10-20 fph. 8/13/2016 8/13/2016 1.00 PROD1 DRILL WPRT T PUH for wiper trip up hole to 9,210'. 10,180.0 10,180.0 05:30 06:30 PUW=36 k 8/13/2016 8/13/2016 2.00 PROD1 DRILL DRLG T 10,180 ft,BOBD 1.45 bpm at 3680 psi 10,180.0 10,207.0 06:30 08:30 FS,BHP 3740,WHP 204, IA 0,OA 52 8/13/2016 8/13/2016 5.25 PROD1 DRILL DRLG T PUH,bypass filters,pump 15 bbl anti- 10,207.0 10,369.0 08:30 13:45 balling pill(2.5%SkreenKleen/1 ppb alpine beads),continue drilling ahead 1.5 bpm at 3,845 psi FS,BHP 3,728, WHP 205, IA 0,OA 52 8/13/2016 8/13/2016 0.25 PROD1 DRILL WPRT T 10,369 ft,BHA wiper up hole,PUW 10,369.0 10,369.0 13:45 14:00 36k 8/13/2016 8/13/2016 1.75 PROD1 DRILL DRLG T BOBD 1.5 bpm at 3,800 psi,BHP 10,369.0 10,430.0 14:00 15:45 3770,WHP 192, IA 0,OA 52 ROP 35 fph. 8/13/2016 8/13/2016 1.00 PROD1 DRILL WPRT T PUH for tie in wiper trip.36Klbs PUW. 10,430.0 8,215.0 15:45 16:45 Pull heavy through 10,105 ft.Tie in to the RA for a+4.5 ft correction. 8/13/2016 8/13/2016 1.00 PROD1 DRILL WPRT T RBIH.Stack out at 10110 ft.Reduce 8,215.0 10,430.0 16:45 17:45 pumps to minimum rate.Continue running in the hole. 8/13/2016 8/13/2016 4.50 PROD1 DRILL DRLG T BOBD 1.5 bpm at 4200 psi,BHP 10,430.0 10,595.0 17:45 22:15 3780,WHP 165,ROP 30-40 fph. Mud swap,with new mud at the bit at 10514 ft. 8/13/2016 8/13/2016 0.25 PROD1 DRILL WPRT T Short wiper.PUW 36KIbs. 10,595.0 10,595.0 22:15 22:30 8/13/2016 8/13/2016 0.67 PROD1 DRILL DRLG T BOBD 1.5 bpm at 4030 psi,BHP 10,595.0 10,622.0 22:30 23:10 3790,WHP 220, ROP 30 fph. 8/13/2016 8/14/2016 0.83 PROD1 DRILL DRLG T BOBD 1.5 bpm at 4030 psi,BHP 10,622.0 10,641.0 23:10 00:00 3790,WHP 220, ROP 30 fph. 8/14/2016 8/14/2016 1.25 PROD1 DRILL DRLG T BOBD 1.5 bpm at 4030 psi,BHP 10,641.0 10,680.0 00:00 01:15 3790,WHP 220,ROP 30 fph. 8/14/2016 8/14/2016 0.50 PROD1 DRILL WPRT T PUH for wiper trip.PUW=33KIbs. 10,680.0 9,680.0 01:15 01:45 Pull heavy at 10105 ft.-4klbs WOB. Pull through at minimum rate. Page 15/26 Report Printed: 8/29/2016 • { Operations Summary (with Timelog Depths) -. - � 1L-17 Csssxscoi'hiiilps '' �t»rka Rig: NABORS CDR2-AC Job' DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(EKE) 8/14/2016 8/14/2016 0.50 PROD1 DRILL WPRT T RBIH.reduce pump rate to get 9,680.0 10,680.0 01:45 02:15 through 10,105 ft.COntinue RIH to bottom. 8/14/2016 8/14/2016 3.75 PROD1 DRILL DRLG P BOBD 1.5 bpm at 4100 psi, BHP 10,680.0 10,827.0 02:15 06:00 3805,WHP 290,ROP 30-90 fph. 8/14/2016 8/14/2016 3.30 PROD1 DRILL DRLG P 10,827 ft,OBD 1.5 bpm at 3796 psi, 10,827.0 10,930.0 06:00 09:18 BHP 3795,WHP 295, IA 0,OA 55 8/14/2016 8/14/2016 0.50 PROD1 DRILL WPRT P 10,930 ft,wiper up hole to 10,150 ft, 10,930.0 10,150.0 09:18 09:48 PUW 35 8/14/2016 8/14/2016 0.50'PROD1 DRILL WPRT P 10150 ft.wiper back in hole,RIW 9 k 10,150.0 10,930.0 09:48 10:18 8/14/2016 8/14/2016 7.70 PROD1 DRILL DRLG P 10,930 ft,BOBD 1.5 bpm at 3800 psi 10,930.0 11,180.0 10:18 18:00 FS,BHP 3796,WHP 301, IA 0,OA 56 8/14/2016 8/14/2016 1.50 PROD1 DRILL WPRT P 11,180 ft,tie in wiper up hole,PUW= 11,180.0 8,205.0 18:00 19:30 35Klbs. Pulled heavy from 10115- 10100 ft.Stalled motor.Work BHA down,PUH at minimum rate.Bring rate back up and continue out of the hole. 8/14/2016 8/14/2016 1.25 PROD1 DRILL WPRT P Tie in to the RA for a+5ft correction. 8,205.0 11,180.0 19:30 20:45 RBIH.Minimum rate through high GR section around 10,110 ft. 8/14/2016 8/15/2016 3.25 PROD1 DRILL DRLG P BOBD 1.5 bpm at 3900 psi, BHP ' 11,180.0 11,292.0 20:45 00:00 3800,WHP 280, IA 0,OA 56 Stacking weight,multiple PU's and restarts.Erratic ROP. 8/15/2016 8/15/2016 1.50 PROD1 DRILL DRLG P BOBD 1.5 bpm at 3900 psi,BHP 11,292.0 11,342.0 00:00 01:30 3812,WHP 214, ROP variable between 15 fph and 110 fph. 8/15/2016 8/15/2016 0.50 PROD1 DRILL DRLG P Loss rate increase from 6 BPH to 20 11,342.0 11,367.0 01:30 02:00 BPH. Continue drilling ahead,losses steadily increasing to 60+BPH. 8/15/2016 8/15/2016 6.00 PROD1 DRILL DRLG P Drilling ahead. 1.5 bpm at 3887 psi, 11,367.0 11,520.0 02:00 08:00 BHP 3797,WHP 485, ROP variable between 20 fph and 80 fph. Loss rate 60-75 BPH. 8/15/2016 8/15/2016 1.00 PROD1 DRILL WPRT P 11,520 ft,wiper up hole to 10,500 ft, 11,520.0 10,528.0 08:00 09:00 PUW 41k.Pull tight,work pipe from 11,321'to 11,260'(CTSW 50k,WOB- 5k).Close choke,full losses. Cont PUH. Pulled tight,work pipe from 11,156'to 11,145'(not bit stuck). Temporarily detained @ 11,150'(CTSW 55k pull,WOB-9k, CTSW-7.5k push).Worked free.Cont PUH on wiper. 8/15/2016 8/15/2016 0.70 PROD1 DRILL WPRT P 10,500 ft,wiper back in hole.RIW 10,528.0 11,520.0- 09:00 09:42 9.4k.RBIH,took weight @ 11,370'but pushed through(loss zone)pumping 1 BPM. PUH to 11,350 to clean the loss zone, still pumping 1 BPM.Pass through clean.Cont.RBIH on full losses. Page 16/26 Report Printed: 8/29/2016 • ar. Operations Summary (with Timelog Depths) `^w � 1L-17 ConocoPhillips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase s Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(MKB)f 8/15/2016 8/15/2016 0.55 PROD1 DRILL DRLG P 11,520 ft, BOBD,CTSW 7.5k,WOB 11,520.0 11,540.0 09:42 10:15 0.8k,ROP 38 FPH, 1.5 BPM, IA 0,OA 55. 1.5 BPM in,0.8 BPM out,partial returns when BOB holding 11.4ppg annular pressure target. 8/15/2016 8/15/2016 1.50 PROD1 DRILL WPRT P 11,540 ft,wiper to the window,PUW 11,540.0 8,209.0 10:15 11:45 34k 8/15/2016 8/15/2016 0.25 PROD1 DRILL DLOG P 8,209 ft,log RA marker correction of 8,209.0 8,231.0 11:45 12:00 plus 5.0 ft. 8/15/2016 8/15/2016 0.25 PROD1 DRILL WPRT P RIH to 8,251 ft,PUH performing 8,231.0 8,235.0 12:00 12:15 pressure survey logging returns at 0.71 bpm,0.95 bpm,and 1.19 bpm, 0.71 bpm returns/choke 270 psi/0.80 bpm in MM/Annular 3416 psi at SD 8202.5 ft. 0.95 bpm returns/choke 250 psi/1.16 bpm in MM/Annular 3405 psi at SD 8,197.5 ft, 1.2 bpm returns/choke 230 psi/1.49 bpm in MM/Annular 3,440 psi at 8193.5 ft. 8/15/2016 8/15/2016 1.50 PROD1 DRILL WPRT P 8,235 ft,wiper back in hole. RIW 6 k 8,235.0 11,540.0 12:15 13:45 8/15/2016 8/15/2016 4.25 PROD1 DRILL DRLG P 11,540 ft,BOBD 1.56 bpm at 3,452 11,540.0 11,652.0 13:45 18:00 psi,BHP 3679,IA 0,OA 55 8/15/2016 8/15/2016 5.00 PROD1 DRILL DRLG P BHA wiper.Continue drilling ahead. 11,652.0 11,790.0 18:00 23:00 1.6 bpm at 3,452 psi,BHP 3670, Additional BHA wipers at 11636 ft and 11682 ft.Multiple PU's and restarts. Losses 20 BPH. 8/15/2016 8/15/2016 0.50 PROD1 DRILL WPRT P PUH to 10,785 ft for wiper trip.PUW 11,790.0 11,790.0 23:00 23:30 33 Klbs.RBIH.No issues in or out of the hole. 8/15/2016 8/16/2016 0.50 PROD1 DRILL DRLG P BOBD 1.56 bpm at 3,500 psi,BHP 11,790.0 11,810.0 23:30 00:00 3700,IA 0,OA 55. ROP 40 fph. 8/16/2016 8/16/2016 8.00 PROD1 DRILL DRLG P Drilling ahead. 1.56 bpm at 3,712 psi, 11,810.0 12,020.0 00:00 08:00 BHP 3745,IA 0,OA 55 ROP 40-90 fph. Multiple BHA wipers and PU's to help improve ROP and weight transfer.30 bph losses. 8/16/2016 8/16/2016 0.75 PROD1 DRILL WPRT P Wiper up hole,PUW 32k.At 11,594', 12,020.0 11,002.0 08:00 08:45 pulled CTSW 40k,WOB-2k. 8/16/2016 8/16/2016 0.50 PROD1 DRILL WPRT P Wiper back in hole,RIW 9k.BOBD. 11,002.0 12,020.0 08:45 09:15 8/16/2016 8/16/2016 8.75 PROD1 DRILL DRLG P Drilling ahead. 1.40 bpm at 3,465 psi, 12,020.0 12,155.0 09:15 18:00 BHP 3750, IA 0,OA 50 ROP 25-50 fph. Multiple BHA wipers and PU's to help improve ROP and weight transfer,losses still @ 30 bph. 8/16/2016 8/16/2016 2.50 PROD1 DRILL DRLG P BHA wiper,pump 5x5 sweep. 12,155.0 12,270.0 18:00 20:30 Continue drilling ahead. 1.55 bpm at 3,505 psi,BHP 3750, IA 0,OA 50 ROP 25-60 fph. BHA wipers and PU's to maintain ROP and weight transfer. Page 17/26 Report Printed: 8/29/2016 i Operations Summary (with Timelog Depths) 1L-17 +Canocaithillips cr:rk;a Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log '.. Start Depth Start Time End Time Dur(hr) Phase. Op Code Activity Code'.. Time P-T-X Operation (EKE)'I End Depth(EKE)', 8/16/2016 8/17/2016 3.50 PROD1 DRILL DRLG P PUH for tie in wiper trip. PUW=34 12,270.0 12,270.0 20:30 00:00 Klbs. Slight bobble at 11,966 ft, 11914 ft, Tie in to the RA for a+6 ft correction. RBIH.Clean trip to bottom.Reduced pump rate across interval from 10,020 to 10,160 ft both in and out. 8/17/2016 8/17/2016 8.90 PROD1 DRILL DRLG P BOBD. 1.40 bpm at 3,600 psi,BHP 12,270.0 12,500.0 00:00 08:54 3750,IA 0,OA 50 ROP 20-60 fph. Multiple BHA wipers and PU's to help improve ROP and weight transfer,losses still @ 30 bph. Many BHA wipers.Drill ahead to called TD @ 12,500'. 8/17/2016 8/17/2016 3.50 PROD1 DRILL WPRT P Pump 10 x 10 to/hi vis sweeps,chase 12,500.0 74.0 08:54 12:24 to swab,no jogs necessary,hole clean. 8/17/2016 8/17/2016 4.10 PROD1 DRILL DLOG P Tag. Reset depth counter.RBIH,tie-in 74.0 12,500.0 12:24 16:30 to HRZ for+7.5'correction.RIH, • weight check @ 8,070'(34K),continue in hole,tag corrected TD @ 12,500'. Start pumping beaded pill. 8/17/2016 8/17/2016 3.75 PROD1 DRILL DISP P POOH laying in 75bb1 beaded liner pill 12,500.0 100.0 16:30 20:15 followed by 11.4 ppg completion fluid. Painted EOP flags at 9550 ft and 5200 ft. 8/17/2016 8/17/2016 0.75 PROD1 DRILL OWFF P At surface,flow check well.Static. 100.0 100.0 20:15 21:00 8/17/2016 8/17/2016 1.00 PROD1 DRILL PULD P PJSM.PUH and LD BHA#16. Bit 100.0 0.0 21:00 22:00 graded 1-1-TD. 8/17/2016 8/18/2016 2.00 COMPZ1 CASING PUTB P Prep floor to run liner.PJSM.Begin 0.0 960.0 22:00 00:00 picking up first segment of liner.Joint 32 at midnight.Filling hole every 5 joints.Losses average 8 bbls/hr. 8/18/2016 8/18/2016 3.00 COMPZ1 CASING PUTB P Continue picking up first segment of 960.0 2,898.0 00:00 03:00 liner. Non ported bull nose,56 joints 2- 3/8"slotted liner,36 joints of 2-3/8" blank liner,3 joints of slotted liner,and shorty deployment. Fill hole every 10 joints. Losses 10-12 bph. 8/18/2016 8/18/2016 1.00 COMPZ1 CASING OTHR P 248 circulating hours on UQC. BHI is 2,898.0 2,898.0 03:00 04:00 required to change it out before RIH with liner,as circulating hour limit of 250 hrs will be exceeded during trip. Continue to monitor the hole.Losses 10 bph.Pressure test UQC to 4,000 psi. 8/18/2016 8/18/2016 1.35 COMPZ1 CASING PULD P MU BHA#17,liner running BHA.Stab 2,898.0 2,942.0 04:00 05:21 injector. 8/18/2016 8/18/2016 4.55 COMPZ1 CASING RUNL P RIH w/lower liner assembly,tie-in 2,942.0 12,495.0 05:21 09:54 EOP flag for+2.5'correction, weight check @ 10,790'(36K).Had to work pipe,heavy pick-ups,stacking to 10,750'to 11,000',pushing @ 10 fpm, after 11,000',increased to 25-30 fpm. Stack weight @ 12,495',weight check 41K,set back down,release from liner,PUW=32K.PUH,reset bit depth. Page 18/26 Report Printed: 8/29/2016 i 0 Operations Summary (with Timelog Depths) V 1 L-17 ConocoPhiillips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log StartDepth Start Time >. End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKS)', 8/18/2016 8/18/2016 2.05 COMPZ1 CASING TRIP P POOH.tie-in to RA tag for+6' 12,495.0 64.0 09:54 11:57 correction,corrected TOL @ 9,602'. POOH w/BHA#17. 8/18/2016 8/18/2016 0.25 COMPZ1 CASING OWFF P No flow check 64.0 64.0 11:57 12:12 8/18/2016 8/18/2016 1.25 COMPZ1 CASING PULD P PJSM.LD BHA#17,check coil above 64.0 0.0 12:12 13:27 CC,found flat spot(0.062).Perform function test on BOP. 8/18/2016 8/18/2016 2.55 COMPZ1 CASING CTOP P Cut 20'of coil,install CTC and test. 0.0 0.0 13:27 16:00 8/18/2016 8/18/2016 2.50 COMPZ1 CASING PUTB P PJSM.MU upper liner assembly: BN, 0.0 1,253.0 16:00 18:30 40 jts slotted,three pups,OH anchored billet. 8/18/2016 8/18/2016 1.50 COMPZ1 CASING PULD P PU CoilTrak BHA and MU to liner. 1,253.0 1,313.0 18:30 20:00 Strip over and make up injector.Open EDC. • 8/18/2016 8/18/2016 3.00 COMPZ1 CASING RUNL P RIH with upper liner segment.Tie-in to 1,313.0 9,600.0 20:00 23:00 EOP flag for+5.3 ft correction. Continue running in the hole.Tie in to the HRZ for+2 ft correction. Close EDC.RIH.Took weight briefly at 9551 ft.Tagged top of lower segment at 9,600 ft. PU to neutral weight.Confirm anchor orientation of 30°ROHS.Bring up pump.Anchor set with 3,800 psi.Set 5 Klbs down.Confirm set. 8/18/2016 8/19/2016 1.00 COMPZ1 CASING RUNL P PUH. Reset depth to setting sleeve. 9,600.0 2,661.0 23:00 00:00 Continue POOH with liner running tools. 8/19/2016 8/19/2016 0.50 COMPZ1 CASING TRIP P Continue POOH with liner running 2,661.0 100.0 00:00 00:30 tools. 8/19/2016 8/19/2016 0.50 COMPZ1 CASING TRIP P Flow check well.Static. 100.0 100.0 00:30 01:00 8/19/2016 8/19/2016 1.00 COMPZ1 CASING PULD P LD liner running BHA#18.Check CT 100.0 0.0 01:00 02:00 for flat spots. 8/19/2016 8/19/2016 1.00 PROD2 STK PULD P PU/MU build BHA#19,with 2.2°AKO 0.0 72.0 02:00 03:00 motor and RR HCC bit.Surface test. 8/19/2016 8/19/2016 2.00 PROD2 STK TRIP P RIH with BHA#19.RIH wt=11 Klbs. 72.0 7,840.0 03:00 05:00 Tie-in HRZ for+14'correction, continue in hole. 8/19/2016 8/19/2016 1.50 PROD2 STK DISP P Circulate well back to used drilling • 7,840.0 7,840.0 05:00 06:30 mud,close EDC,PUW=29K. 8/19/2016 8/19/2016 2.85 PROD2 STK KOST P RIH,dry tag billet @ 8,347'.PUH,start 7,840.0 8,347.0 06:30 09:21 pumps.Backream uphole to 8,320'@ 1 fpm.RBIH,one stall.Stick drill @ 8,345',wait,repeat till we see WOB. Time drill off billet: 1.53 bpm @ 3,250 PSI,CTW=11.5K,WOB=1.5. Aluminum at shaker,start seeing"C" sand in returns,off billet. 8/19/2016 8/19/2016 4.15 PROD2 DRILL DRLG P Drill ahead All build section: 1.54 8,347.0 8,380.0 09:21 13:30 BPM @ 3,360 PSI,BHP=3,560 PSI, CTW=11.4K,WOB=1.7K,ROP=25. Dry drift billet,clean. Page 19/26 Report Printed: 8/29/2016 • R ,Sss fOperations Summary (with Timelog Depths) 1L-17 coo hi mps Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dor(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(ftKB) 8/19/2016 8/20/2016 10.50 PROD2 DRILL DRLG P RBIH and continue drilling ahead. 1.51 8,380.0 8,565.0 13:30 00:00 BPM @ 3,280 PSI,BHP=3,590 PSI, CTW=10.5K,WOB=1.5-2K,ROP has been variable between 7 fph to 80+ fph in the build section. Stacking weight.Multiple PU and restarts to keep drilling.DLS over the build section average=52°. 8/20/2016 8/20/2016 2.00 PROD2 DRILL TRIP P POOH with build BHA after section TD 8,565.0 72.0 00:00 02:00 of 8565 ft. PUW=34 Klbs. 8/20/2016 8/20/2016 1.00 PROD2 DRILL PULD P PUD BHA#19. 72.0 0.0 02:00 03:00 8/20/2016 8/20/2016 1.50 PROD2 DRILL PULD P MU,MU,PD BHA#20 with 0.4°+AKO 0.0 72.0 03:00 04:30 motor and RB HCC bit. • 8/20/2016 8/20/2016 2.35 PROD2 DRILL TRIP P RIH w/lateral drilling assembly,tie-in 72.0 8,565.0 04:30 06:51 HRZ for+7'correction,continue in hole. 8/20/2016 8/20/2016 1.65 PROD2 DRILL DRLG P BOBD: 1.55 BPM @ 3390 PSI, 8,565.0 8,630.0 06:51 08:30 BHP=3590 PSI,CTW=10.5K, WOB=1.5K,ROP=20-50.Start pumping new mud system,new mud at bit 8,630'. 8/20/2016 8/20/2016 4.50 PROD2 DRILL DRLG P Drilling 1.57 BPM @ 3,600 PSI, 8,630.0 8,738.0 08:30 13:00 BHP=3586 PSI,CTW=9-10.5K, WOB=1.5K, ROP=20-50. Saw slight decrease in mud density out. Mud appeared aired up.Treated active system with defoamer. 8/20/2016 8/20/2016 5.50 PROD2 DRILL DRLG P Stall and restart at 8738 ft and 8754 ft. 8,738.0 8,960.0 13:00 18:30 Continue drilling ahead.ROP 12 fph to 200+fph. 8/20/2016 8/20/2016 0.75 PROD2 DRILL WPRT P PUH for wiper trip.PUW=31 Klbs. 8,960.0 8,960.0 18:30 19:15 Clean trip in and out. 8/20/2016 8/21/2016 4.75 PROD2 DRILL DRLG P Continue drilling ahead.Having 8,960.0 9,247.0 19:15 00:00 trouble building angle.Adjust drilling parameters to try and increase motor DLS output.Vary WOB from 0.9-2.5 Klbs. Increase pump rate as high as 1.7 bpm. Appears formation related. Able to meet adjusted geo targets. • 8/21/2016 8/21/2016 4.00 PROD2 DRILL DRLG P Continue drilling ahead. Pumping 1.8 9,247.0 9,360.0 00:00 04:00 BPM at 4107 psi.BHP=3680 psi. CTW=9Klbs,ROP=20-150 fph. 8/21/2016 8/21/2016 0.50 PROD2 DRILL WPRT P PUH for wiper trip.PUW=32 Klbs. 9,360.0 9,360.0 04:00 04:30 RBIH. 8/21/2016 8/21/2016 3.35 PROD2 DRILL DRLG P BOBD: 1.83 BPM @ 4075 PSI,BHP= 9,360.0 9,430.0 04:30 07:51 3670 PSI,CTW=9K,WOB=1.3K, ROP=20-40.At @ 9,430',started losing returns,down to almost nothing, reduce pump rate to 1.60 BPM, continue drilling,returns returning, crude/gas back in returns. 8/21/2016 8/21/2016 0.50 PROD2 DRILL WPRT P Short wiper to stabilize returns, 9,430.0 9,430.0 07:51 08:21 increase pump rate back 1.83 BPM, returns stabilizing. Increase choke press by 20 PSI. Losses currently @ 8 BPH. Page 20/26 Report Printed: 8/29/2016 III II Operations Summary (with Timelog Depths) 1L-17 • Conocot'hitlmps Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X ';Operation (EKE) End Depth(EKE) 8/21/2016 8/21/2016 5.90 PROD2 DRILL DRLG P BOBD: 1.83 BPM @ 4115 PSI,BHP= 9,430.0 9,608.0 08:21 14:15 3690 PSI,CTW=9K,WOB=1K, ROP=20-40.Losing have increased slowly to 15 BPH,continue drilling. Pumped 10 bbl Hi-Vis pills. Experienced more losses. 8/21/2016 8/21/2016 0.50 PROD2 DRILL WPRT P Short wiper to stablize return, 9,608.0 9,608.0 14:15 14:45 PUW=33K.RBIH. 8/21/2016 8/21/2016 6.00 PROD2 DRILL DRLG P BOBD: 1.83 BPM @ 4115 PSI,BHP= 9,608.0 9,760.0 14:45 20:45 3690 PSI,CTW=9K,WOB=1K, ROP=20-40.Losses currently @ 18- 20 bpm. 8/21/2016 8/21/2016 1.50 PROD2 DRILL -WPRT P PUH for tie in wiper trip.PUW=32 9,760.0 9,760.0 20:45 22:15 Klbs.Tie in to the RA for a+5 ft correction.RBIH.Clean trip in and out. Observed an increase in cuttings over the shaker. 8/21/2016 8/22/2016 1.75 PROD2 DRILL DRLG P BOBD: 1.82 BPM @ 4120 PSI,BHP= 9,760.0 9,766.0 22:15 00:00 3740 PSI,CTW=7K,WOB=1.5K,ROP slowed from 18 fph to 1 fph.Losses @ 18-20 bpm. 8/22/2016 8/22/2016 5.15 PROD2 DRILL DRLG P Drilling ahead at 1.82 BPM @ 4120 9,766.0 9,805.0 00:00 05:09 PSI,BHP=3740 PSI,CTW=7K, , WOB=1.5K,ROP at1 to 2 fph. Vary drilling parameters.Able to work up to 8 fph. Losses @ 18-20 bpm. 8/22/2016 8/22/2016 0.25 PROD2 DRILL WPRT P Mini wiper,PUW=35K,RBIH. 9,805.0 9,805.0 05:09 05:24 8/22/2016 8/22/2016 2.00 PROD2 DRILL DRLG P Drilling ahead at 1.53 BPM @ 3610 9,805.0 9,841.0 05:24 07:24 PSI,BHP=3745 PSI,CTW=6.5K, WOB=1.2K,ROP=10-20. Losses still 15-20 BPH. 8/22/2016 8/22/2016 0.25 PROD2 DRILL WPRT P BHA wiper,PUW=35K,RBIH. 9,841.0 9,841.0 07:24 07:39 8/22/2016 8/22/2016 7.05 PROD2 DRILL DRLG P Drilling ahead at 1.53 BPM @ 3810 9,841.0 9,944.0 07:39 14:42 PSI,BHP=3765 PSI,CTW=5.5K, WOB=1.3K,ROP=10-15.Losses remain @ 15-17 BPH.GEO up 90 degrees. 8/22/2016 8/22/2016 0.15 PROD2 DRILL WPRT P Mini wiper/weight check,PUW=37K, 9,944.0 9,944.0 14:42 14:51 RBIH. 8/22/2016 8/22/2016 2.40 PROD2 DRILL DRLG P Drilling ahead at 1.53 BPM @ 3755 9,944.0 9,977.0 14:51 17:15 PSI,BHP=3745 PSI,CTW=5.3K, WOB=1.1K,ROP=15-20.Losses remain @ 15-17 BPH.GEO up 93 degrees. 8/22/2016 8/22/2016 0.25 PROD2 DRILL WPRT P BHA wiper.PUW=39KIbs. 9,977.0 9,977.0 17:15 17:30 8/22/2016 8/22/2016 2.50 PROD2 DRILL DRLG P Drilling ahead at 1.53 BPM @ 3760, 9,977.0 10,003.0 17:30 20:00 PSI,BHP=3778 PSI,CTW=3-8K, WOB=1.2K,ROP average 10 fph. Losses remain @ 15-17 BPH. 8/22/2016 8/22/2016 0.50 PROD2 DRILL WPRT P PUH for wiper trip to help improve 10,003.0 8,995.0 20:00 20:30 drilling rate.PUW=38 Klbs.Clean trip up. 8/22/2016 8/22/2016 0.50 PROD2 DRILL WPRT P RBIH.RIH wt=9 Klbs.Clean trip in 8,995.0 10,003.0 20:30 21:00 and out. Page 21/26 Report Printed: 8/29/2016 0 Operations Summary (with Timelog Depths) 0i, 0 1L-17 ConocoPhinips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth, Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T X Operation (ftKB) End Depth(ftKB) 8/22/2016 8/23/2016 3.00 PROD2 DRILL WPRT P Continue drilling ahead.ROP between 10,003.0 10,017.0 21:00 00:00 1 fph-2 fph. Difficulty drilling past 10,003 ft.ROP increased after 10,005 ft to 10 fph. 8/23/2016 8/23/2016 4.50 PROD2 DRILL DRLG P Drilling ahead at 1.53 BPM @ 3760 10,017.0 10,090.0 00:00 04:30 PSI,BHP=3758 PSI,CTW=7K, WOB=1.2K,ROP average 20 fph. Losses @ 15 BPH. Drilling break from10,080-10,088 ft. 8/23/2016 8/23/2016 0.25 PROD2 DRILL WPRT P Mini wiper,PUW=36K, RBIH. 10,090.0 10,090.0 04:30 04:45 8/23/2016 8/23/2016 4.70 PROD2 DRILL DRLG P Drilling ahead at 1.53 BPM @ 3760 10,090.0 10,157.0 04:45 09:27 PSI,BHP=3778 PSI,CTW=6.5K, WOB=1.4K,ROP=10-15. 8/23/2016 8/23/2016 0.25 PROD2 DRILL WPRT P BHA wiper trip,PUW=32K,RBIH. 10,157.0 10,157.0 09:27 09:42 8/23/2016 8/23/2016 1.00 PROD2 DRILL DRLG P Drilling ahead at 1.63 BPM @ 4090 10,157.0 10,172.0 09:42 10:42 PSI,BHP=3780 PSI,CTW=5.8K, WOB=1K,ROP=10. 8/23/2016 8/23/2016 0.25 PROD2 DRILL WPRT P BHA wiper trip,PUW=31K,RBIH. 10,172.0 10,172.0 10:42 10:57 8/23/2016 8/23/2016 7.55 PROD2 DRILL DRLG P Drilling ahead at 1.63 BPM @ 4090 10,172.0 10,253.0 10:57 18:30 PSI,BHP=3780 PSI,CTW=5.8K, WOB=1K, ROP=10.Started pumping new mud system,new mud @ bit ' 10,177',minimal improvement. Drill ahead,pump 10x10 to/hi sweep. 8/23/2016 8/23/2016 2.60 PROD2 DRILL TRIP P POOH chasing sweeps.PUW 34k, 10,253.0 72.2 18:30 21:06 300 ft jog at EOB 8,621 ft,continue POOH,clean past billet,window and pilot hole,close EDC at 7,940 ft, continue POOH for Bi-weekly BOPE test and BHA Change. 8/23/2016 8/23/2016 1.50 PROD2 DRILL PULD P On surface,tag up,spae out,PJSM, 72.2 0.0 21:06 22:36 PUD/LD BHA#20.Bit condition 2-1- BT-N-X-I-CT-PR. 8/23/2016 8/24/2016 1.40 PROD2 WHDBOP RURD P PJSM-Prep for BOPE test,clean and 0.0 0.0 22:36 00:00 clear floors,pull checks,install nozzle, flush surface lines,coil and jet stack, service tree. 8/24/2016 8/24/2016 1.00 PROD2 WHDBOP RURD P Continue prep for BOPE test,grease 0.0 0.0 00:00 01:00 choke and stack.Test inner reel iron, stripper 250/3,500 psi.fluid pack, shell test. 8/24/2016 8/24/2016 9.50 PROD2 WHDBOP BOPE P Test BOPE 250/3,750 psi,annular 0.0 0.0 01:00 10:30 2,500 psi,witnessed by AOGCC rep. Brian Bixby.Four failures,three fail/pass,greased&retested.Annular bag was replaced w/OEM equip. 8/24/2016 8/24/2016 2.00 PROD2 WHDBOP RURD P RD test equipment,grease valves, 0.0 0.0 10:30 12:30 service injector head,stab on with . checks&nozzel and swap coil back to 8.5 FloPro mud 8/24/2016 8/24/2016 2.89 PROD2 DRILL PULD P MU/PD BHA#21 with 0.5°AKO 0.0 74.8 12:30 15:23 Weatherford 2-3/8",RB HYC bicenter bit Page 22/26 Report Printed: 8/29/2016 °' •0 0 Operations Summary (with Timelog Depths) CI 1 L-17 Ccanoco hiliips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start',Depth Start Tame::. End Time ..Dur(hr) Phase Op Code Activity Code Time P-T-X ';Operation ` (EKE) End Depth(EKE) 8/24/2016 8/24/2016 1.87 PROD2 DRILL TRIP P RIH with lateral drilling BHA,stop at 74.8 7,930.0 15:23 17:15 2600 ft to establish Weatherford motor parameters,@ 1.55 bpm(60 gpm), 700 psi dp,3740 psi pump pressure. 8/24/2016 8/24/2016 0.25 PROD2 DRILL DLOG P 7940 ft log HRZ tie-in,+7 ft correction 7,935.0 7,977.0 17:15 17:30 8/24/2016 8/24/2016 1.00 PROD2 DRILL TRIP P RIH take two survey checks at min 7,977.0 10,253.0 17:30 18:30 rate and 10 fpm,surveys acceptable, establish free spin at 1.54 bpm,700 psi differential,3762 psi AP 8/24/2016 8/25/2016 5.50 PROD2 DRILL DRLG P Drilling ahead at 10253 ft, 1.54 bpm, 10,253.0 10,486.0 18:30 00:00 3830 psi,3763 psi BHP,8.5K CTW, attempt to manage ROP and lateral vibration,lower rate to 1.45 bpm and vary WOB between 1.5 and 2K. 8/25/2016 8/25/2016 0.65 PROD2 DRILL DRLG P Continue drilling AL1 lateral from 10,486.0 10,510.0 00:00 00:39 10,486 ft 1.53 bpm at 3,550 psi FS, BHP 3,775 psi,-0.5k CWT,WOB 1.1k, ROP 33,WHP 267,IA 0,OA 49 8/25/2016 8/25/2016 0.35 PROD2 DRILL WPRT P Wiper trip up hole,PUW 36k. 10,510.0 9,515.0 00:39 01:00 8/25/2016 8/25/2016 0.40 PROD2 DRILL WPRT P Wiper trip in hole, RIW 6k. 9,515.0 10,510.0 01:00 01:24 8/25/2016 8/25/2016 2.85 PROD2 DRILL DRLG P Drilling ahead at 10,510 ft. 1.53 bpm 10,510.0 10,618.0 01:24 04:15 at 3,690 psi FS,BHP 3,800 psi,CWT -.5k,WOB 1.95k,ROP 40, 8/25/2016 8/25/2016 0.25 PROD2 DRILL WPRT P BHA wiper,PUW=41K,RBIH. 10,618.0 10,618.0 04:15 04:30 8/25/2016 8/25/2016 2.50 PROD2 DRILL DRLG P Drilling ahead: 1.53 bpm at 3,690 psi 10,618.0 10,760.0 04:30 07:00 FS, BHP 3,805 psi,CWT 2k,WOB 1k, ROP=45 8/25/2016 8/25/2016 0.85 PROD2 DRILL WPRT P 1000'wiper trip,PUW=35K,RBIH. 10,760.0 10,760.0 07:00 07:51 Good solids returns across shaker. 8/25/2016 8/25/2016 1.50 PROD2 DRILL DRLG P BOBD: 1.54 bpm at 3,780 psi FS, 10,760.0 10,830.0 07:51 09:21 BHP 3,815 psi,CWT 3k,WOB.8k, ROP=35.Trying to GEO steer down, near bit inclination 91 degrees. 8/25/2016 8/25/2016 0.25 PROD2 DRILL WPRT P BHA wiper,PUW=36K,RBIH. 10,830.0 10,830.0 09:21 09:36 8/25/2016 8/25/2016 6.80 PROD2 DRILL DRLG P BOBD: 1.54 bpm at 3,780 psi FS, 10,830.0 11,010.0 09:36 16:24 BHP 3,815 psi,CWT 3k,WOB.8k, ROP=35.Try GEO steer up then down cutting upper C4 zone at steeper angle,unsuccessful.GEO steer down at 88 degrees. 8/25/2016 8/25/2016 1.00 PROD2 DRILL WPRT P Wiper trip to window,PUW=35K,tie-in 11,010.0 8,220.0 16:24 17:24 to RA marker,+5 ft correction 8/25/2016 8/25/2016 1.00 PROD2 DRILL WPRT P Wiper trip in hole,RIW=6K 8,220.0 11,010.0 17:24 18:24 8/25/2016 8/26/2016 5.60 PROD2 DRILL DRLG P Drilling ahead at 11010', 1.54 bpm, 11,010.0 11,230.0 18:24 00:00 3630 psi FS,3822 psi BHP,CWT- K, WOB 1K,trying to GEO steer up,max pump rate up to 1.65 bpm,CWT-8k, WOB 2.2k,BHA and mini wipers as needed. Page 23/26 Report Printed: 8/29/2016 • Operations Summary (with Timelog Depths) 1 L-17 ConocoPhilltp ,tilr;.k::a Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X ',Operation (ftKB) End Depth(ftKB)': 8/26/2016 8/26/2016 0.75 PROD2 DRILL DRLG P Continue drilling AL1 lateral from 11,230.0 11,260.0 00:00 00:45 11,230 ft 1.54 bpm at 3,620 psi FS, BHP 3,827 psi,CWT-5k,WOB 1.1k, WHP 249, IA 0,OA 58,trouble getting tools to invert up,unable to build inclination,formation pushng tools down,pump 5x5. 8/26/2016 8/26/2016 0.50 PROD2 DRILL WPRT P Wiper trip up hole,PUW 37k. 11,260.0 10,060.0 00:45 01:15 8/26/2016 8/26/2016 0.50 PROD2 DRILL WPRT P Wiper trip in hole,RIW 5k. 10,060.0 11,260.0 01:15 01:45 8/26/2016 8/26/2016 7.55 PROD2 DRILL DRLG P On bottom,back ream 1 fpm HS for 11,260.0 11,510.0 01:45 09:18 15',RBIH drilling ahead 1.54 bpm at 3,649 psi,BHP 3,820 psi,CWT-9k, WOB 2k,pump 50 bbls new mud,able to get from 88°to 91°an get kicked back down,attempt different pump rates,TF's-HS 10°L/R,drill ahead 1.54 bpm at 3640 psi FS,BHP 3,828 psi,CWT-10k,WOB 1.4k, ROP 30- 120 8/26/2016 8/26/2016 1.25 PROD2 DRILL WPRT P Wiper trip,PUW=35k, RBIH. 11,510.0 11,510.0 09:18 10:33 8/26/2016 8/26/2016 2.25 PROD2 DRILL DRLG P BOBD: 1.40 bpm at 3,480 psi FS, 11,510.0 11,595.0 10:33 12:48 BHP 3,830 psi,CWT-8k,WOB 1.2K, ROP=20-70.Keep trying GEO up, formation kicking us down,slower , drilling, have encountered the B2. Trying to GEO back up. 8/26/2016 8/26/2016 0.25 PROD2 DRILL WPRT P BHA wiper, PUW=38K,RBIH. 11,595.0 11,595.0 12:48 13:03 8/26/2016 8/26/2016 4.30 PROD2 DRILL DRLG P BOBD: 1.54 bpm at 3,610 psi FS, 11,595.0 11,630.0 13:03 17:21 BHP 3,830 psi,CWT-9k,WOB 1.3K, ROP=10-30. Trying to GEO back up. Mini wiper @ 11,432',PUW=42K, RBIH,continue drilling to progress slowed at 11,631 ft,TD called,pump 10x10 sweep. 8/26/2016 8/26/2016 3.50 PROD2 DRILL WPRT P POOH chasing sweep to FOB,open 11,630.0 74.8 17:21 20:51 hole clean,300 ft jog at FOB,clean past billet,window and pilot hole, POOH,jog at 500 ft. 8/26/2016 _ 8/26/2016 1.40 PROD2 DRILL TRIP P Tag up,space out,reset counters, 74.8 7,935.0 20:51 22:15 RBIH. 8/26/2016 8/26/2016 0.25 PROD2 DRILL DLOG P Tie in at HRZ for plus 7.5 ft correction, 7,935.0 7,977.0 22:15 22:30 PUW 29k. 8/26/2016 8/27/2016 1.50 PROD2 DRILL TRIP P Continue RIH,stacked at 11,610 ft, 7,977.0 11,610.0 22:30 00:00 PUW 39k,confer with town,pump beaded liner pill. 8/27/2016 8/27/2016 0.40 PROD2 DRILL DISP P Pumping beaded liner pill while 11,610.0 11,600.0 00:00 00:24 reciprocating pipe. 8/27/2016 8/27/2016 1.60 PROD2 DRILL DISP P POOH laying in beaded liner running 11,600.0 3,300.0 00:24 02:00 pill/11.6 ppg completion fluid from 11,600 ft,paint flags at 7,900 ft and 4,400 ft,continue POOH Page 24/26 Report Printed: 8/29/2016 • • Operations Summary (with Timelog Depths) 1L-17 Q:mmaagttiiiips - :�Aacka Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation '.. '. . v (EKE) End Depth(ftKB)'; 8/27/2016 8/27/2016 3.00 PROD2 DRILL DISP T Heavy losses(40-45 bph)slow speed 3,300.0 3,150.0 02:00 05:00 and pump rate,losses slowed to 18- 20 bph pumping minimum rate.confer with town,fluids to manage losses coming,perform 5 minute static at 3,120 ft(2,342 ft TVD at DPS)AP 1,566 psi to 1,531 psi,come on line minimum rate,2.5 bbls to get returns. KWF fluid to manage losses off loaded. 8/27/2016 8/27/2016 4.75 PROD2 DRILL TRIP T RIH to window for static,static 3,150.0 8,190.0 05:00 09:45 pressure 20 mins,starting preesure 3,612 PSI,ending pressure 3550', EMD @ 11.5 ppg. Losses still 15-20 bph.Called town,decide to POOH laying in 50 bbl beaded pill from top of window. 8/27/2016 8/27/2016 1.60 PROD2 DRILL DISP P POOH laying in beaded liner pill,paint 8,190.0 97.0 09:45 11:21 EOP flag @ 4,500',continue OOH laying in liner pill. 8/27/2016 8/27/2016 0.50 PROD2 DRILL OWFF P Monitor well for flow,no flow. 97.0 97.0 11:21 11:51 8/27/2016 8/27/2016 1.00 PROD2 DRILL PULD P PJSM.LD BHA#21,bit grade 1-1, 97.0 0.0 11:51 12:51 some balling,pictures on"S"drive. Weatherford motor will be sent to shop for Dyno test.Test top drive. 8/27/2016 8/27/2016 1.00 COMPZ2 CASING PUTB P Prep rig floor for liner run. 0.0 0.0 12:51 13:51 • 8/27/2016 8/27/2016 4.15 COMPZ2 CASING PUTB P PJSM.MU AL1 liner assembly:BN, 0.0 3,549.4 13:51 18:00 109 jts slotted,shorty deployment sleeve. 8/27/2016 8/27/2016 1.50 COMPZ2 CASING PUTB P PJSM-MU liner assembly to BHA 3,549.4 3,593.6 18:00 19:30 #22,change out check valves,MU BHA to CoilTrak,surface test. 8/27/2016 8/28/2016 4.50 COMPZ2 CASING RUNL P RIH with BHA#22,Plus 3.5 ft 3,593.6 11,148.0 19:30 00:00 correction at flag,sat down at 10,240 ft,start working down,break over at 46k-48k,continue working liner down to 11,148 ft as of midnight. 8/28/2016 8/28/2016 1.35 COMPZ2 CASING RUNL P Continue working liner down from 11,148.0 11,600.0 00:00 01:21 11,148 ft,work thru tight area 11,085 ft to 11,150 ft,PUW 47k,RIH getting good surface weight back,log HRZ for plus 1.5 ft correction.on depth at 11,598 ft(11,600 ft corrected from HZR)release off liner at 1.4 bpm, PUW 29k,top of liner at 8,050 ft,reset counters. 8/28/2016 8/28/2016 3.15 COMPZ2 CASING DISP P Displace well to seawater,POOH, 8,030.0 2,500.0 01:21 04:30 PJSM with LRS,RU LRS,P/T lines and equipment, 8/28/2016 8/28/2016 1.95 COMPZ2 CASING FRZP P Freeze protect from 2,500 ft.POOH. 2,500.0 44.2 04:30 06:27 8/28/2016 8/28/2016 1.45 COMPZ2 CASING PULD P PJSM-PUD BHA#22, LD BHA, 44.2 0.0 06:27 07:54 remove floats, UQC. • 8/28/2016 8/28/2016 1.30 DEMOB WHDBOP MPSP P PJSM.Rig up valve crew lubricator, 0.0 0.0 07:54 09:12 set BPVm WHP=1035 PSI.LD surface equipment. 8/28/2016 8/28/2016 1.90 DEMOB WHDBOP RURD P Displace coil to fresh water.LD 0.0 0.0 09:12 11:06 mouseholes. Page 25/26 Report Printed: 8/29/2016 • Operations Summary (with Timelog Depths) 1 L-17 Con000thilltps Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code, Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 8/28/2016 8/28/2016 4.00 DEMOB WHDBOP RURD P PJSM.remove UQC,start cutting 0.0 0.0 11:06 15:06 1,400'coil,LD cutting equipment, 8/28/2016 8/28/2016 5.40 DEMOB WHDBOP RURD P Install external connector,pull test, 0.0 0.0 15:06 20:30 boot wire,install nozzle,stab on wellhead.Pump corrision inhibitor, chase with freshwater.LD PDL. Blow down coil,stack,and surface lines, complete off loading fluids from rig. 8/28/2016 8/28/2016 2.00 DEMOB WHDBOP NUND P PJSM-Freeze protect tree.ND BOPE, 0.0 0.0 20:30 22:30 torque checked(40 minutes)remove Kill,deployment lines. 8/28/2016 8/29/2016 1.50 DEMOB WHDBOP RURD P Complete rig down checklist. 0.0 0.0 22:30 00:00 Rig Released at 00:00 on 08-29-2016 Page 26/26 Report Printed: 8/29/2016 REcEivED JUN 08 2015 2:1 G ,.• WELL LOG TRANSMITTAL#903265090 To: Alaska Oil and Gas Conservation Comm. May 24, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 to i 9 i2 v1.K.BENDER RE: Perforation Record: 1L-17 Run Date: 4/30/2016 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 1L-17 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-22151-00 Perforation Record (Field Print) 1 color log 50-029-22151-00 CANNE0 JAN 0 6 n17 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed��`A�� ILes.c.et yOF T�, THE STAT• ,, Alaska Oil and Gas • o • Conservation Commission ti ►,.—�� f�Ll1a�J�e 1-1 Lltatt -_== - 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 (4' Q. Main: 907.279.1433 ALAE* Fax: 907.276.7542 www.aogcc.alaska.gov Jason Burke CTD Drilling Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1L-17 Permit to Drill Number: 191-043 Sundry Number: 316-209 Dear Mr. Burke: 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, /9k.,,c/ . Cathy P. Foerster �,//,� Chair DATED this `�Y day of April, 2016. RBDMS v1/ APR 1 4 2016 RECEIVED • STATE OF ALASKA • MAR 3 0 2016 ' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Arms �ri 1 b� n 20 AAC 25.280 ` A 1.Type of Request: Abandon ❑ Plug Perforations Q Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑, 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 ❑ 191-043 3.Address: 6.API Number: Stratigraphic ❑ Service 2 PO Box 10036,Anchorage,AK 99510 50-029-22151 7.If perforating: Pit 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA- Will planned perforations require a spacing exception? Yes ❑ No 2 KRU 1L-17 9. Property Designation(Lease Number): 10.Field/Pool(s): ADL 25659 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): V 8700' 6322' 8586' 6244' 3295 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural N/A N/A N/A N/A N/A N/A Conductor 122' 16" 122' 122' 1640 psi 630 psi Surface 4608' 9-5/8" 4608' 3571' 3520 psi 2020 psi Production 8675' 7" 8675' 6305' 4980 psi 4330 psi Tubing 8018' 3.5" 8018' 5858' 10160 psi 10540 psi Tubing 64' 3.5" 8082' 5901' 6990 psi 7400 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8170'-8460' 5961'-6158' 3.5" L-80/J-55 8082' Packers and SSSV Type: Baker FHL Packer Packers and SSSV MD(ft)and TVD(ft): 7954'MD/5815'TVD Baker HB Retrievable Packer 8032'MD/5867'TVD 12.Attachments: Proposal Summary 2 Wellbore schematic 2 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: 1-Jul-16 Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑✓ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved Jason Burke herein will not be deviated from without prior written approval. Contact CTD Engineer Email jason.burke(a�conocophillips.com Printed Name Jason Burke Title CTD Drilling Engineer 907-265-6097 Signature - - Phone Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3\LZ. -2-09 Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: 5of2 j -57- t 0 3 750 p 5 �-nnv1aY pr-tvrv1tC✓ "h" to ZSUCpsig 4/i-c- r X71 v 1Cictnv,tret appro vfd pc b- .,2t, f}r4G ZS,/ t2 (� Post Initial Injection MIT Req'd? Yes I No NV Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: it —4.0'_. RBDMS LV APR 1 4 2016 APPROVED BY Approved by: .1e4.4vifi90.,e,,vi.,1--- COMMISSIONERATHE COMMISSION Date:4.43_ ��t� / ` Submit FormDuplicate and Form 10-403 Revised 11/20150 I io Ed for 12 months from a date of approval. Attachments in Duplicate VT-1- 4 )z/)to T143 3/31/lc .e /4 • ConocoPhilli RECEIVED s p MAR 3 0 2016 Alaska P.O. BOX 100360 AOGCC ANCHORAGE,ALASKA 99510-0360 March 22, 2016 Commissioner-State of Alaska Alaska Oil &Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill a dual-lateral out of the Kuparuk Well 1L-17 using the coiled tubing drilling rig, Nabors CDR2-AC. CTD operations are scheduled to begin in July 2015. The objective will be to drill laterals KRU 1 L-17A and 1 L- 17AL1 targeting the Kuparuk C-sand. A separate sundry application is attached to plug the KRU 1L-17 (191- 043) perforations to allow these laterals to be drilled. As detailed in the attachments, ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1)to plug the NC-sand perforations in 1 L-17. Attached to this application are the following documents: — 10-403 Sundry Application to Abandon KRU 1L-17 (191-043) — Operations Summary in support of the 10-403 sundry application — 10-401 Applications for 1 L-17A& 1 L-17AL1 — Detailed Summary of Operations — Directional Plans for 1L-17A& 1 L-17AL1 — Proposed CTD Schematic If you have any questions or require additional information, please contact me at 907-265-6097. Sincerely, Jason Burke ConocoPhillips Alaska Coiled Tubing Drilling Engineer • • KRU 1L-17 CTD Summary for Plugging Sundry (10-403) Summary of Operations: KRU well 1L-17 is a Kuparuk A/C-sand injector equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize two laterals to target the C4 sand to the southeast and northwest of 1L-17. The laterals will support nearby producers 1L-13 and 1L-23. Prior to CTD operations, E-Line will punch 2' of holes in the 3-1/2" tubing tail at 8052' MD and the "D" nipple at 8048' MD will be milled out to a 2.80" ID. The existing A-sand and C-sand perforations will be squeezed with cement and the 3-1/2" tubing tail will be cemented in place to provide a means to kick out of the 7" casing. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1) to plug the A-sand and C-sand perforations in this manner. Following the cement squeeze Nabors CDR2-AC will drill a pilot hole to 8200' MD and set a mechanical whip-stock in the 2.80" pilot hole to kick off at 8193' MD. Both laterals will be completed with 2-3/8" slotted liner from TD with the second lateral liner top located inside the 3-1/2" tubing tail. Using the maximum formation pressure in the area of 3790 psi in 1L-16, the maximum potential surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 3295 psi. CTD Drill and Complete 1L-17 Laterals: July 2016 Pre-CTD Work 1. RU Slickline: Obtain SBHP, dummy off gas lift mandrels, and pressure test. 2. RU E-line: Punch 2' of holes in the 3W tubing tail at 8052' MD. 3. RU Pumping Unit: perform injectivity test down the tubing. 4. RU Service Coil: Mill out"D" nipple and cement squeeze the A-sand and C-sand perforations up to the holes in the tubing tail. 5. RU Slick-line: Tag top of cement and pressure test cement. 6. Prep site for Nabors CDR2-AC and set BPV. Riq Work Thy S svh cl�� 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 1 L-17A Sidetrack(C4 sand - Southeast) a. Drill 2.80" high-side pilot hole through cement to 8225' MD b. Caliper pilot hole c. Set top of whip-stock at 8193' MD d. Mill 2.80"window at 8193' MD. e. Drill 3" bi-center lateral to TD of 12500' MD. f. Run 23/" slotted liner with an aluminum billet from TD up to 8240' MD. 3. 1 L-17AL1 Lateral (C4 sand - Northwest) a. Kick off of the aluminum billet at 8240' MD. b. Drill 3" bi-center lateral to TD of 11800' MD. c. Run 2%" slotted liner with deployment sleeve from TD up to 8045' MD. /view PTD D 4. Freeze protect, set BPV, ND BOPE, and RDMO Nabors CRD2-AC. Cdnvo/'. l ropc� / '- k k1-.'// �e Cc4f,/feel t'-,'r f/0 / ,% e✓ , 5CA j 2nd %��d 6C C 61� o� aPrui�`hli Toe fellrvl Cu fir P ei41 racy(/'et/, Page 1 of 2 / 3/// 3/17/2016 • • Post-Riq Work 1. Pull BPV 2. Obtain SBHP 3. Install gas lift design 4. Pre produce for less than 30 days 5. Return to injection Page 2 of 2 3/17/2016 KUP 1 L-17 ConocoPhillips O Well Attrib Max Ang1ID TD • Alaska.Inc. Wellbore API/UWI Field Name Wellbore Status ncl rt MD OMB) Act Btrn(ftKB) Conocophiirips 500292215100 KUPARUK RIVER UNIT INJ 4922 4,400.00 8,700.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1L-17,3/29/2016 7:24:38 PMSSSV:NIPPLE Last WO: 12/23/2013 42.01 4/11/1991 Vertical schamabc(actual) Annotation Depth(ftKB) End Date Annotation last Mod By End Date Last Tag:SLM 8,421.0 5/27/2015 Rev Reason:TAG,MANDREL ORIENTATION hipshkf 6/7/2015 Casing Strings HANGER;38.5 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 43.0 122.0 122.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE 95/8 8.921 42.0 4,607.2 3,571.5 36.00 J-55 BTC •° Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth)TVD)...Wt/Len(I...Grade Top Thread �•' "� PRODUCTION 7 6.276 32.3 8,675.3 6,305.6 26.00 J-55 BTC-MOD TubingStrings Tubing Description String Ma...ID(in) Top(NAB) Set Depth(ft.Set Depth(TVD)(...Wt(Ib/ft) Grade Tap Connection I TUBING WO 31/2 2.992 38.5 8,018.4 5,858.7 9.30 L-80 EUE-M Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl rt Item Des Corn (in) 38.5 38.5 0.17 HANGER FMC TUBING HANGER 2.992 -1ti CONDUCTOR;43.0-122.06.-40-""d es..^../Q1e,.. 491.1 490.8 6.08 NIPPLE CAMCO DS LANDING NIPPLE w 2.875"Profile 2.875 7,946.8 5,810.7 47.89 LOCATOR BAKER LOCATOR ' 2.990 7,947.1 5,810.9 47.89 SEAL ASSY BAKER 80-40 SEAL ASSY,Stick up 7'off NoGo Seals 2.990 NIPPLE;491.1El Engaged 14.67' 7,954.1 5,815.6 47.89 PACKER BAKER FHL PACKER w/PBR(Center element on 2.930 packer 7980.73') 7,998.9 5,845.6 47.91 NIPPLE CAMCO DS LANDING NIPPLE w 2.812"Profile 2.812 - 8,016.6 5,857.4 47.84 LOCATOR BAKER LOCATOR 2.990 Ill 8,017.4 5,858.0 47.84 SEAL ASSY BAKER 80-40 SEAL ASSY.Fully Located 1'Spaced Off 2.990 GAS LIFT;2,313.4 NoGo Seals Engaged 10.86' -Tubing Description 'String Ma...I ID(in) 'Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING-Original 31/21 2.992 8,018.4 8,082.3 5,901.7 9.30 J-55 EUE8rdABMOD Completion Details Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com Nominal ID(in) 8,018.4 5,858.6 47.83 PBR BAKER 10'STROKE PBR 3.000 8,032.1 5,867.9 47.77 PACKER BAKER HB RETRIEVABLE PACKER 3.500 8,048.4 5,878.9 47.69 NIPPLE CAMCO D NIPPLE NO GO 2.750 8,081.6 5,901.2 47.54 SOS BAKER SHEAR OUT SUB 2.992 SURFACE;42.0-4,607.2 , . Perforations&Slots Shot Dens Itif Top(ND) Btm(ND) - hots/ GAS LIFT;7,890.8 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date (s ft) Type Com 8,170.0 8,242.0 5,961.0 6,009.9 C-4,1L-17 8/18/1991 6.0 APERF 21/8"Flow Jet Perf;0 deg.ph 8,342.0 8,370.0 6,078.1 6,097.3 A-5,1L-17 6/21/1991 4.0 (PERF 4.5"Csg Guns;180 deg. ph;Oriented 25 deg. CCW LOCATOR;7,946.8 8,405.0 8,420.0 6,121.1 6,131.3 A-4,1L-17 3/27/2012 6.0 (PERF HES 2.5"Perf Gun,60 Deg,DP Charges SEAL ASSY;7,947.1 - 8,446.0- 8,460.0 6,149.1 6,158.6 A-4,1L-17 6/21/1991 4.0 (PERF 4.5"Csg Guns;180 deg. PACKER;7,954.7- ph;Oriented 25 deg. CCW 4 Mandrel Inserts NIPPLE;7,998.9 In St N Tap(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com LOCATOR;8,016.6 1 2,313.4 1,997.3 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 1/11/2014 4:30 2 7,890.8 5,773.1 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/29/2013 7:30 SEAL ASSY;8,017.4 Notes:General&Safety PBR;8,016.4 End Date Annotation PACKER;8,032.1 10/4/2010 NOTE:View Schematic w/Alaska Schematic9.0 NIPPLE;8,048.4 50S;8,081.6 ~ APERF;R F;8,170.0-8,242.0^ P � ` IPERF;8,342.08,370.0---. IPERF;8,405.0-8,420.0 IPERF;8,446.DA,460.0.-. PRODUCTION;32.3-8,675.3 • S 1L-17 Proposed CTD Schematic 3-1/2"Camco DS Landing Nipple @ 491'MD(2.875"ID) 3-1/2"9.3#L-80 EUE 8rd Tubing to surface 16"62#H-40 shoe @ 122 MD 3-1/2"Camco MMG gas lift mandrel @ 2313'&7890'MD 9-5/8"36#J-55 shoe „N ` Baker 80-40 Seal Assy @ 7947'RKB(7940'ELM) @ 4607'MD Baker FHL packer @ 7954'RKB(7947'ELM)(2.93"ID) 3-1/2"Camco DS Landing Nipple @ 7999'RKB(7992'ELM) (2.812"ID) Baker 80-40 Seal Assy @ 8017'RKB(8010'ELM)(2.99"ID) Baker PBR @ 8018-8036'RKB(8011'-8029'ELM) 1991 Completion Baker HB Retrievable Packer @ 8032'RKB(8025'ELM)(3.5" ID) 3-1/2"Camco D-Nipple @ 8048'RKB (8041'ELM) (2.75"min ID. Will be drilled out to 2.80"ID) 3-1/2"Baker SOS @ 8082'RKB(8075'ELM) 1L-17AL1 WPO(north-west) KOP @ 8193'MD TD @ 11,800'MD Liner top @ 8075'MD C-sand perfs --- ----------------- 8170'-8242'MD ---- _---_--'""--"------ A-sand perfs 8342'-8370'MD 8405'-8420'MD 8446'-8460'MD 1 L-17A WP04(south-east) TD @ 12,500'MD — _ Billet @ 8240'MD 7"26#J-55 shoe @ 8675'MD • • Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re- drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box Geologist in the upper left corner of Form 10-403 is checked. If the "Abandon" or cn "Suspend" boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Geologist 2K(23 work) the initial reviewer will cross out that erroneous entry and initial then it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended" box and initial that change. Drilling Engineer v The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill" box, she will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, she will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, she will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding"user query in RBDMS to ensure that all of the Plug for Redrill wells have been Geologist handled properly. At this same time, they will also review the list of suspended wells for accuracy. Vit-oat3 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. June 4, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 R E `.! i v e DATA LOGGED Anchorage, Alaska 99501 t i of i2o15 JUN 18 21,1L K BENDER f+CG C RE: Multi Finger Caliper(MFC): 1L-17 Run Date: 5/29/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1L-17 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-22151-00 scoff Ju' 1 Z PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signe . ✓a 2",01 L �P'c4 WELL HISTORY FILE COVER PAGE XHVZS This page identifies oversize material and digital infonnation available for this individual Well History file and weather or not it is available in the LaserFiche file. Please insure that it remains as the first page in this file. t1 ' œ/3 Well History File # Digital Data Added to LaserFiche File CD's - # Yes No Yes No Yes No DVD's - # Diskettes - # Oversized Material Added to LaserFiche File Maps # Yes No Yes No Yes No Mud Logs # Other # General Notes or Comments about this file. If any of the information listed above is not available in the LaserFiche file, or if you have any questions or infonnation requests regarding this file, you may contact the Alaska Oil & Gas Conservation Commission to request copies at 279-1433, or email us at: AOGCC - Librarian@admin.state.ak.us s,OF Tye • e„ v7„-- THE STATE Alaska Oil and Gas FF# � Of ALASI:A Conservation Commission - GOVERNOR SEAN PARNELL 333 West Seventh Avenue 0 �-- � Anchorage, Alaska 99501-3572 ALAS* Main: 907.279.1433 Fax: 907.276.7542 Paul Chan ��E Workover Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 f I Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk Oil Pool, 1L-17 Sundry Number: 313-599 Dear Mr. Chan: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair, Commissioner DATED this Li day of November, 2013. Encl. C & RECEIVED STATE OF ALASKA \ A OIL AND GAS CONSERVATION COMMI ON ��,��i NOV 1 9 2013 APPLICATION FOR SUNDRY APPROVALS p� 20 AAC 25.280 1.Type of Request: Abandon r Plug for Redrill r Perforate New Fool r Repair w ell 17: Change Approved Program r Suspend r Rug Perforations r Perforate r Pull Tubing - Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casing r Other: r; 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development r 191-043 3.Address: 6.API Number: Stratigraphic r Service P.O. Box 100360,Anchorage,Alaska 99510 50-029-22151-00 • 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No Fr, 1 L-17 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25659 - Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY 1 Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 8700 6323 8586' 6244' 8049' none Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 122' 122' SURFACE 4565 9.625 4607' 3572' PRODUCTION 8643 7 8675' 6306' Perforation Depth MD(ft): _ Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8170-8242,8342-8370,8405-8420,8446-8460 5961-6010,6078-6097,6121-6131,6149-6159 3.5 J-55 8082 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER HB RETRIEVABLE PACKER MD=8032 TVD=5868 SSSV-CAMCO TRDP-4A SSSV MD=1791 TVD=1636. 12.Attachments: Description Surrniary of Proposal rq 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service • 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 12/14/2013 Oil r Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r GINJ r WAG p' Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correc o the best of my knowledge. Contact: Paul Chan @ 263-4759 Email: Paul.Chanacontractor.cop.com Printed Name Paul Chan Title: Workover Engineer t t ■ I� Signature Phone:263-4759 Date Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 3\3^ 5 � ck Plug Integrity ID BOP Test r✓ Mechanical Integrity Test Location Clearance r � K. 5.. 1,'8 a -c t RBI= NOV 2 5 ,24,\- Ot3her. ✓dOl) 5 Spacing Exception Required? Yes ❑ No [ Subsequent Form Required: `V --L/044 APPROVED BY / / Approved by: C ! �/� 5���� COMMISSIONER THE COMMISSION Date: (1— at 3 Approved appllca ion is valid tor 12 months tr thq.da e t approval. Form 10-403(Revised 10/2012) - 0 J I G I N A L /�/ Submit Form and Attachments in Duplicate • • • v • ConocoPhillips Alaska RECEIVED P.O. BOX 100360 NOV 1 9 2013 ANCHORAGE,ALASKA 99510-0360 AOGCC November 19,2013 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 workover Kuparuk Injection Well 1L-17(PTD# 191-043). 1L-10 was drilled in April 1991 and completed with a simple completion in June 1991. The well is currently shut-in due to a one way packer leak at 8032'MD and secured with a CA-2 plug in the D nipple at 8048'MD. The scope of work is to pull the 3-'/2" tubing string, change the casing packoff, and run a new 3-'/z" 9.3# L-80 stacker packer completion. If you have any questions or require any further information,please contact me at 263-4759. Sincerely, fff4 � Paul Chan Workover Engineer CPAI Drilling and Wells " • 1L-17 Ri g Workover Pull and Run Tubing (PTD #: 191-043) Current Status: This well has been SI since 3/04/13 due to a one way packer leak at 8032'MD. Scope of Work: Pull 3 ''/2"tubing,change casing packoff,and run new 3-'/2"stacker packer completion. General Well info: Well Type: Injector MPSP: 2,240 psi using max SITP on 3/02/13 Reservoir Pressure/TVD: 3,703 psi/6,015'TVD(11.8 ppg)from Panex gauges on 7/05/13. Wellhead type/pressure rating: FMC Gen 4,7-'/16"5M psi top flange BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT results: MIT-IA passed on 3/2/13,MIT-T passed on 7/06/13,MIT-OA passed 7/12/13 Earliest Estimated Start Date: December 14,2013 Production Engineer: David Lagerlef/Dana Glessner Workover Engineer: Paul Chan(263-4759/pchan4 @conocophillips.com) Pre-Rig Work 1. RU SL and set catcher sub on top of plug at 8048'. Pull dummy valve from GLM @ 7964' MD and leave pocket open for circulation point. 2. Set BPV w/i 24 hrs of rig arrival. Proposed Procedure 1. MIRU. 2. Pull BPV. Circulate 12.2 ppg KWF. Verify well is dead. 3. Set BPV and ND tree. NU BOPE&test BOP's to 250/3000 psi. 4. Pull BPV. MU landing joint,BOLDS,and pull tubing hanger to rig floor. a. If the seals cannot be pulled from the Baker HB packer at 8032'MD,the tubing will be cut with e- line and an attempt will be made to fish the seals. 5. POOH to SSSV @ 1791'MD and PU storm packer. 6. Set storm packer at 100'MD. P.- P c... . t.Q-cv p 3 7. ND BOPE and tubing spool. Replace IC packoffs and test. NU tubing spool and BOPE. Test breaks. 8. Unseat storm packer,POOH,and LD storm packer. 9. Continue POOH and laying down 3-'/2"tubing. 10. RIH w/scraper and washover assembly on 3-'/2"tubing to the PBR at 8018'MD. Circulate well clean. 11. POOH and stand back 3-'/2"tubing. LD cleanout BHA. 12. PU stacker packer w/PBR and seal assembly and RIH on 3-'h"tubing. L--11.SAO-% ? 13. Sting into PBR and space out. Spot corrosion inhibited pill around the packer and tailpipe. Drop bar and rod and set Baker FHL packer(set 7971' or deeper). PT tubing and IA. c ito4 / o , ;r 1 Zoe 14. Shear off the PBR and space out. Circulate well with corrosion inhibited brine. 15. Space out with pups. MU hanger. Land the hanger,RILDS. 16. PT the IA,ramp up pressure to shear the SOV. 17. Install BPV,ND BOPE,NU tree. Pull BPV,install tree test plug&test tree. Pull tree test plug. • • 1L-17 Rig Workover Pull and Run Tubing (PTD #: 191-043) 18. Freeze protect through the SOV. Set BPV. 19. RDMO. Post-Rig Work 1. Reset well house(s)and flowlines of adjacent wells. 2. Pull BPV. 3. RU Slickline: a. Pull ball and rod, b. Pull RHC plug, c. Pull SOV from GLM and replace w/DV, d. Pull catcher sub and CA-2 plug in Camco D nipple at 8048'MD. e. RDMO 4. Turn well over to operations. e n w;-E-'t a SSJ ,Gl t r- / s�-4.,1h: .-rY Z • • ConocoPhillips Well: KRU 1 L-17 Current Completion 16"62.5#H-40 to 122'MD MTh 4 3'1/2"TRSV @1791'MD • 3-Y2"9.3#/ft J-55 EUE 8rd-mod tubing 9-5/8"36#J-55 to 4,607'MD • 3.Y"McMurray FMHO GLM @ 2184'MD • • 3;1/2'McMurray FMHO GLM @ 3458'MD • 3-1/2"McMurray FMHO GLM @ 4334'MD • 3-1/2"McMurray FMHO GLM @ 5093'MD • 3-1/2"McMurray FMHO GLM @ 5849'MD • 3-1/2"McMurray FMHO GLM @ 6602'MD 4 3-1/2"McMurray FMHO GLM @ 7328'MD 4 3'/2'McMurray FMHO GLM @ 7964'MD Baker PBR @ 8018'MD = Baker HB packer @ 8032'MD P4)ir o 3- 'Cameo D profile @ 8048'MD 4 -1/2'Baker Shear Out Sub @ 8082'MD 7"26#J-55 shoe at,8675'MD • • Conoco Phillips Well: KRU 1L-17 Proposed Completion os • 3-Y2"DS 2.875"Profile®—500'MD 16"62.5#H-40 to 12T MD • 3-'/2"9.3#/ft L-80 EUE 8rd-mod tubing 9-5/8"36#J-55 to 4,60T MD 4 3-Y2"Camco GLM • Baker Seal Stem 1 • Baker PBR Baker FHL Stacker Packer l o i -4 32"Camco 2.813"D profile • Baker Seal Stem l f Baker PBR @ 801W MD I Baker HB packer @ 803T MD o t• 3-W Camco 2.75"D profile @ 8048'MD • 3-1/2'Baker Shear Out Sub @ 8082'MD 7"26#J-55 shoe at,8675'MD 111■—_ # KUP 1L-17 ConocoPhillips 1 Well Attributes Max Angle&MD TD /i]Slt.§111.., Wellbore API/UWI Field Name Well Status Incin MD(ftKB) Act Btm(ftKB) catexdPhdeps 500292215100 KUPARUK RIVER UNIT INJ 49.22 4,400.00 8,700.0 ' Comment H2S(ppm) Date Annotation End Date KB-Ord(ft) Rig Release Date "' SSSV:TRDP Last WO: 42.01 4/11/1991 Well Conk;:-1 1, 7/812013 9:2646 AM Shematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:SLM 8,479.0 7/5/2013 Rev Reason:TAG,SET PLUG haggea Casing Strings Casing Description 'String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd HANGER,38 -•'� •"'; o.• CONDUCTOR 16 15.062 43.0 122.0 122.0 62.50 H-40 WELDED Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thed nc SURFACE 95/8 8.921 42.0 4,607.2 3,571.7 36.00 .1-55 BTC casing Description String 0... String ID...Top(ftKB) Set Depth f.Set Depth(TVD)•••String Wt..String• String Top Thrd 1 "t! , PRODUCTION 7 6.276 32.3 8,675.3 6305.6 26.00 J-55 BTC-MOD Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)..String Wt...String.. String Top Thrd TUBING 31/2 2.992 38.1 8082.3 5,901.7 9.30 .1-55 EUE8r4ABMOD CONDUCTOR, Completion Details 43-122 Top Depth (TVD) Top Ind Nand... Top(ftKB) (ftKB) (°) Item Description Comment ID(In) 38.1 38.1 0.51 HANGER FMC GEN IV TUBING HANGER 3.500 SAFETY VLV. 1,791 1 . ■i 1,790.7 1,635.8 46.07 SAFETY VLV CAMCO TRDP-4-A SAFETY VALVE 2.812 8,018.4 5,858.6 47.61 PBR BAKER 10'STROKE PBR 3.000 8,032.1 5,867.8 47.59 PACKER BAKER HB RETRIEVABLE PACKER 3.500 8,048.5 5,878.9 47.56 NIPPLE CAMCO D NIPPLE NO GO 2.750 GAS LIFT, 2,184 ., 8,081.6 5,901.2 47.49 SOS BAKER SHEAR OUT SUB 2.992 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) GAS LIFT, Top Depth 3,458 (TVD) Top Ind --- Top(ftKB) (RKB) (°) Description Comment Run Date ID(in) 8,048.5 5,878.9 47.56 PLUG 2.75"CA-2 PLUG 7/6/2013 0.000 GAS LIFT. 4.334 Perforations&Slots Shot Top(TVD) Btm(TVD) Dens Top(ftKB)Bun(ftKB) (ftKB) (ftKB) Zone Date (oh... Type Comment „\ 8,170.0 8,242.0 5,961.0 6,009.8 C-4,1L-17 8/18/1991 6.0 APERF 21/8"Flow Jet Pert;0 deg.ph 8,342.0 8,370.0 6,078.1 6,097.2 A-5,1L-17 6/21/1991 4.0 IPERF 4.5"Csg Guns;180 deg.ph;Oriented r. ,, 25 deg.CCW 8,405.0 8,420.0 6,121.0 6,131.3 A-4,1L-17 3/272012 6.0 IPERF HES 2.5"Per)Gun,60 Deg,DP SURFACE, •• Charges 42-4'607 8,446.0 8,460.0 6,149.0 6,158.6 A-4,1L-17 6/21/1991 4.0 IPERF 4.5"Csg Guns;180 deg.ph;Oriented - 25 deg.CCW GAS LIFT, 5,093 Notes:General&Safety End Date Annotation 10/4/2010 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT, 5,849 III GAS LIFT, 8102 M GAS LIFT, 7.328 GAS 7LIFT, I,964 PBR,8,018 PACKER,8,032 W NIPPLE,8,0/8 11. PLUG,8,049 Ir SOS,8,082 { ■ APERF, 8,170-8.242 Mandrel Details IPERF, ii' Top Depth Top Port 8,342$,370 S (TVD) Ind OD Valve Latch Sloe TRO Run N...Top(ftKB) (ftKB) 1°) Make Model (In) Sery Type Type (in) (Pei) Run Date Coin... 1 2,183.8 1,908.1 45.00 MMH FMHO 1 GAS LIFT DMY BK2 0.000 0.0 6/24/1991 8,4 $420 2 3,457.7 2,792.3 48.04 MMH FMHO 1 GAS LIFT DMY BK2 0.000 0.0 9/12/1991 3 4,334.1 3,390.0 47.85 MMH FMHO 1 GAS LIFT DMY BK2 0.000 0.0 6/24/1991 IPERF, _ = 4 5,093.3 3,898.8 48.49 MMH FMHO 1 GAS LIFT DMY BK2 0.000 0.0 6/24/1991 8,44s-e,4sa E 5 5,849.3 4,405.5 47.46 MMH FMHO 1 GAS LIFT DMY BK2 0.000 0.0 6/24/1991 1 6 6,602.2 4,908.6 50.34 MMH FMHO 1 GAS LIFT DMY BK2 0.000 0.0 6/24/1991 7 7,327.7 5,395.5 47.89 MMH FMHO 1 GAS LIFT DMY BK2 0.000 0.0 6/24/1991 8 7,964.4 5,822.4 47.90 MACCO SPM-2 1 12 GAS LIFT DMY RK 0.000 0.0 9/12/1991 PRODUCTION, 32-8,675 A IL TD,8700 STATE OF ALASKA ALA* OIL AND GAS CONSERVATION COM.ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r" Repair w ell r Plug Ferforations r Perforate 17 Other r Alter Casing r Pull Tubing r Stimulate - Frac r Waiver r Time Extension r Change Approved Program r Operat. Shutdow n r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r '. 191 - 043 3. Address: 6. API Number: Stratigraphic r Service J;• P. O. Box 100360, Anchorage, Alaska 99510 " 50 - 029 - 22151 - 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25659 - • 1L 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): none Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 8700 feet Plugs (measured) None true vertical 6323 feet Junk (measured) None Effective Depth measured 8586 feet Packer (measured) 8032 true vertical 6244 feet (true vertucal) 5868 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 122 122 SURFACE 4565 9.625 4607 3572 PRODUCTION 8643 7 8675 6306 AF' t���1` RECEIVED APR 1 9 2912 Perforation depth: Measured depth: 8170'- 8242', 8342'- 8370', 8405'- 8420', 8446' -8460' A�GC/� VV True Vertical Depth: 5961'- 6010', 6078'- 6097', 6121'- 6131', 6149' -6159' Tubing (size, grade, MD, and TVD) 3.5, J - 55, 8082 MD, 5901 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER HB RETRIEVABLE PACKER @ 8032 MD and 5868 TVD SSSV - CAMCO TRDP -4A @ 1791' MD and 1636 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 3975 Subsequent to operation 1889 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service 17 Stratigraphic r 16. Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WIND WAG Pc GINJ r SUSP r SPLUG I 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact John Peirce 265 -6471 Printed Name John Peirce Title Wells Engineer Signature Phone: 265 -6471 Date A, f ,S 11 f 2 I l R APR 19 21)11 ifl9,12. Form 10-404 Revised 11/2011 Submit Original Only 1 L -17 Well Work Summary DATE, SUMMARY • 3/25/12 DRIFT TBG WITH 2.29 "; TAG G411@ 8491' SLM. IN PROGRESS. 3/26/12 DRIFTED TBG WITH 22.5' x 2.58" DUMMY GUN TO 8420' SLM, EST. 8446' RKB. WELL LEFT S /I, READY FOR E /L. 3/27/12 RIH WITH HES 2 1/2" PERFORATING GUN 15' / 6SPF / 60 DEG / DP CHARGES AND PERFORATE FROM 8405 -8420' / RIG OOH • KUP 1L-17 ConocoPhillips 01 Well Attributes Max Angle l & MD TD Alaska,If10 Welibore API/UWI Field Name Well Status Inc! (°) MD (ftKB) Act 858 (ftKB) Car,yNps 500292215100 KUPARUK RIVER UNIT INJ 49.22 4,400.00 8,700.0 ' Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date wellconea - lL- n,3/2anm220815PM - SSSV:TRDP ,Last WO: 42.01 4/11/1991 Schematic - Aduai Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 8,491.0 3/25/2012 Rev Reason: ADD PERFS, TAG ninam 3/28/2012 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 43.0 122.0 122.0 62.50 H - 40 WELDED HANGER. 38 Casing Description String 0... String ID ... Top (fd(8) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.921 42.0 4,607.2 3,571.7 36.00 J - 55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd I PRODUCTION 7 6.276 32 8 6 26 J -55 BTC -MOD Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 31/2 2.992 38.1 8,082.3 5,901.7 9.30 J -55 EUE8rdABMOD CONDUCTOR, Completion Details 43-122 Top Depth (TVD) Top Inc/ Noml... Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) 38.1 38.1 0.51 HANGER FMC GEN IV TUBING HANGER 3.500 SAFETY VLV, 1,791 1 ' 1,790.7 1,635.8 46.07 SAFETY VLV CAMCO TRDP -4 -A SAFETY VALVE 2.812 8,018.4 5,858.6 47.61 PBR BAKER 10' STROKE PBR 3.000 8,032.1 5,867.8 47.59 PACKER BAKER HB RETRIEVABLE PACKER 3.500 8,048.5 5,878.9 47.56'NIPPLE CAMCO D NIPPLE NO GO 2.750 GAS LIFT, 2,184 8,081.6 5,901.2 47.49 SOS BAKER SHEAR OUT SUB 2.992 Perforations & Slots GAS LIFT, J .s Shot Mil 3'458 Top (ND) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date OK- Type Comment 8,170 8,242 5,961.0 6,009.8 C-4, 1L -17 8/18/1991 6.0 APERF 2 1/8" Flow Jet Perf; 0 deg. ph GAS q 334 8,342 8,370 6,078.1 6,097.2 A -5, 1L -17 6/21/1991 4.0 IPERF 4.5" Csg Guns; 180 deg. ph; Oriented 25 deg. CCW II 8,405 8,420 6,121.0 6,131.3 A -4, 1L -17 3/27/2012 6.0 IPERF HES 2.5" Perf Gun, 60 Deg, DP Charges g 8,446 8,460 6,149.0 6,158.6 A-4, 1L -17 6/21/1991 4.0 IPERF 4.5" Csg Guns; 180 deg. ph; Oriented 25 deg. CCW Notes: General & Safety End Date Annotation 42 - 4,807 • SURFACE, 1 0/4/2010 NOTE: View Schematic w/ Alaska Schematic9.0 GAS LIFT, 5,093 GAS LIFT, 5,849 4 GAS LIFT, 6,802 GAS LIFT, 7,328 p GA8 .9 4 7,984 MI PBR, 8,018 PACKER. 8,032 III NIPPLE, 8,048 SOS. 8,082 APERF, 8,170 -8,242 Mandrel Details IPERF, Top Depth Top Port 3342 -8,370 (TVD) Ind OD Valve Latch 5140 TRO Run Stn Top (ftKB) (ftKB) (1 Make Model (in) Son/ Type Type (in) (psi) Run Date Cont... 1 2,183.8 1,908.1 45.00 McMu... FMHO 1 GAS LIFT DMY BK2 0.000 0.0 6/24/1991 8,405.8420 2 3,457.7 2,792.3 48.04 McMu... FMHO 1 GAS LIFT DMY BK2 0.000 0.0 9/12/1991 3 4,334.1 3,390.0 47.85 McMu... FMHO 1 GAS LIFT DMY BK2 0.000 0.0 6/24/1991 IPERF, . 4 5,093.3 3,898.8 48.49 McMu... FMHO 1 GAS LIFT DMY BK2 0.000 0.0 6/24/1991 8,448-8,480 l 111 5 5,849.3 4,405.5 47.46 McMu... FMHO 1 GAS LIFT DMY BK2 0.000 0.0 6/24/1991 6 6,602.2 4,908.6 50.34 McMu... FMHO 1 GAS LIFT DMY BK2 0.000 0.0 6/24/1991 7 7,327.7 5,395.5 47.89 McMu... FMHO 1 GAS LIFT DMY BK2 0.000 0.0 6/24/1991 8 7,964.4 5,822.4 47.90 MACCO SPM -2 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/12/1991 PRODUCTION, 32 -8,675-\ • TD, 8,700 2.1 52g WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. March 29, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 MPY �Z 2C1�2 RE: Perforating Record: 1L-17 Run Date: 3/27/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1L -17 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 22151 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com 5 Signed: Date: � ConocoPhllips aas~ P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360---- --- February 1, 2010 Mr. Dan Seamount Alaska Oil &-Gas Commission 333 West 7d' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Dan Seamount: .,~'' ~3 Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRIS. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped December 5~`, 2009. The corrosion inhibitor/sealant was pumped December 22nd, 25~', 26d' & 28~', 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, v Klei3f ~E~EIVED ~lastca Oit F~ 6as Cans. Corrsnissifln Anchorage ConocoPhillips Well Integrity Projects Supervisor • .i~ ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 3/1/2010 1 G.1 L & 1 R Pad Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1 G-17 50029229450000 1990620 SF n/a 17" n/a 7.65 12/26/2009 1 L-01 50029211960000 1841730 52' 7.7 31" 12/5/2009 10.15 12/22/2009 1 L-02 50029211930000 1841700 45' 5.7 35" 12!5/2009 10.15 12/22/2009 1 L-04 50029211790000 1841540 40' 3.9 24" 12/5/2009 5.8 12/22/2009 1 L-06 50029211640000 1841330 2'5" n/a 2'5" - n/a 7.22 12/26/2009 1 L-08 50029211750000 1841500 34' 3.7 40" 12/5/2009 10.2 12/26/2009 1L-09 50029220250000 1900340 11" n/a 11" n/a 1.27 12/26/2009 1 L-11 50029220340000 1900450 16" n/a 17" n/a 2.25 12/25/2009 i L-12 50029220330000 1900440 7" n/a 15" n/a 3.4 12/25/2009 1 L-13 50029221500000 1910420 13' 2.2 27" 12/5/2009 5.52 12/26/2009 1 L-17 50029221510000 1910430 26' 4.0 18" 12/5/2009 9.35 12/26/2009 1 L-19 50029220490000 1900610 9' 2.5 19" 12/5/2009 4.25 12/25/2009 1 L-23 50029221670000 1910620 SF n/a 17" n/a 2.12 12/26/2009 1 L-26A 50029221730100 2000150 SF n/a 17" n/a 2.97 12/25/2009 1 R-14 50029213860000 1851510 SF n/a 29" n/a 5.95 12/28/2009 1 R-31 50029225380000 1941680 6" n/a 24" n/a 7.22 12/28/2009 1 R-32 50029225230000 1941460 SF n/a 24" n/a 5.95 12/28/2009 1 R-33 50029225290000 1941560 SF n/a 24" n/a 4.67 12/28/2009 • ~'' , , ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 1 l, 2009 • ~tECEI V EL~ OCT l ~ 2[_lQ9 Alaska Oil & Gas Cons. Commission Anchorage Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 ~ ~ f:: ~ ~~ Dear Mr. Maunder: Enclosed please find the10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. well 1 L-17 PTD 191-043 surface casing starter head repair. Please call Perry Klein or MJ Loveland at 659-7043 if you have any questions. Sincerely, Perry Klein ConocoPhillips Well Integrity Projects Supervisor - - - - - - - - - - - - ~REGEIV~L~ ~ ~ oCz ~ ~ zoo~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oil & Gas Cons. C4111~11SSipt1 REPORT OF SUNDRY WELL OPERATIONS Anchorage 1. O erations Performed: Abandoll ~ P ^ Repair Well ^ Plu Perforations g ~ Stimulate Other ~ StaRer head seal ~ ~ weld Aiter Casing ^ Pull Tubing ^ Pedorate New Pool ~ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Ciass Before Work: 5. P it to Drill Number: ConocoPhillips Alaska, I~C. Derelaprnent ^ ExpEoratory ^ ~ 191-043 3. Address: stratigraphic ^ Service ^~ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 ~ 50-Q29-22151-00 `~L-KB Elevation (ft): 9. Weli Name d Number; ~ RKB 130' . 1 L-17 8. Property Designation: 10. FieidlPoo!{s}: `\ ADL0025659 ALK2585 Kuparuk River Field / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured ~ 8700' feet true vertical ~ 6323' fe~t Plugs (measured: Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 122` 16" 122' SURFACE 4~78` 9-518° 4608' PRODUCTION 854~' 7" 8675' Perforation depth: Measured depth: 8170',8342',8446' true vertical depth: 6009',6078.1',6149' Tubing (size, grade, and measured depth) ,,~_~~, gpg~ ~p, ~ ~~ Packers & SSSV (type & measured depth) pkr= Baker ^HB" Packor. ~ Pkr- 8032' SSSV=Camco "Ti2DP-4-A" SSSV= 1791' 12. Stimulation or cement squeeze summary: Intervais treated (measured) i~/,q Treatment descriptions including volumes used and finai pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14. Attachments 15. Well Class after work: ~ Copies of Logs and Surveys run _ Exploratory ^ Development ^ Sern'ce ^`~ Daily Report of Well Operations X 16. Well Status after work: CQ Ga~ WAGQ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and c ct to the best of my Imowledge. sundry Number or wA if C.O. Exempt: NIA contact erry ei / M ov land Printed Na Perry Kie' ~titie WI Project Supervisor Signature Phone: 659-7043 e _ _" __ _ Date 10/11l2009 U ~~ ~~')~(~~ ~~v' ~ ~~~yoy Cn.w~ 1f1 AAA Omric~.'1 f1/IMl1l1R Q~J+mi# flrinin~l~(lnlv • . 1 L-17 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 9/25/2009 9/27/2009 9/28/2009 BH prep. Initial T/I/0= 40l11/20. Bled down the TBG to 0 psi. FL on OA @ 60 feet. Filled OA with fluid to 3 feet of BH. Remove VR plug on IA and install purge manifold. Final T/I/0= 0/0/0. BH weld complete. Seal weld casing head. Install Both VR plugs on IA & OA. Install original manifolds on IA & OA and installed 1/2" flush plugs on the conductor. Kakivik will inspect weld this evening. T/I/O = 0/0/0. MIT OA - Passed. Initial T/I/O = 0/0/0, pressured up OA to 1800 psi. start T/I/O = 0/0/1800, 15 minute reading T/I/O = 0/0/1750, 30 minute reading T/I/O = 0/0/1730. Pumped 1.5 bbls of diesel. Bleed down OA to 30 psi, no fluids to surface. Final T/I/O = 0/0/30. a • ~ ~ ~ ~ ~. ` ~ ~~ ~~~ ~ _ ~ ~ ~ ~ ~~ :~:: ~ _ :~.A ;~ ~ . ~ ::~: ~~~ Y yc F . ,y ~ ~~~~ ~ ~ y ;'• - ) ~~~ ~~ 5Y p~ L ~ ~. ~ ,p • ,i, ~~ + ~' ~;~, 4 ~~~ ' . ~ -...., ~~~~~ ~. •; . 'L ' ~~ ~ ~rtM. ~ ~'. ~ # d"~ ~'~, ~ ~~.~ . ~ .c `£ . ~,4~.~ ... ~ l ' ~ ~ T~~ _ :,.~ ~ ~ t.,. ~ i ~ tfi' . a~ Y 1`~ ~~ " f . f~` . . r at ,Y `'. ~ °~,/:~ ~{~ ~ $ . ~^'. +. F `~ ~' y s- .t ae -, ~ ' :~ ~ 3~ i~t. ,~ - +~'h. ; " ~ ~ ;~. a t . 4 . ~ ~ i a ' .~' ~ , 'o ~ ~ •: ~ ~ , r:, i ;~ ~ _~. ' ~ ~ ~ , ~ ~ .~'3 f ;~ ~~'~ +yi ` x ~ . : ~:. ~ ~,~r~,. ~ a V~. y ~ ~ ' ~ , . . r~ . ~~3• e; ~J~ - ,. . s:'~ ~' .. : ~- '`~ _ _ N { ' ~.~ ~ yq.. e . p ~ ~ 1 ~ ~`'~ ~'^ " i ~ .: ( ~r , ' (~ ~ ~ ~ ~~ g,r s t , . : y.. s _~~~ ~.~ A ~ ~ ~ a ` ~~ t ~ ~ ` a } ~± ~. ; a _~• ;~ '~'~ r ~ ~ ~ f ti ~ ~ ~~ ? ~ ~ ~ ~ ~ ~'l. ~ _' . ~h~Z ~'. [ ..~ t .. . + . ~ ` _.~~ ~ . F ~ .~~ ! t ~ _~~ . _ 1 .i .. ~ i ~ ~ - ~ .~ ~~ i;;: ~ `~~ b bf ,,~y ._ [__-- _. _" . . ( v ~ ~ ~ ~ ~p i +~ ~f ~ ~ y_ ' F~.'a'~, . ~ ~ ( . ~ ~ , . .. .:r . . ' ~ ~ ~ ~ `~ ~ • 1 ` 1 ;' . _ f . . . 4 + ~ a r 111 ~ ~b' ; ~ ~ r. ' 6 a~ ~ ~ ,. • ; e ~~.•~ 3i •i '' ~- 1 ~~ `; `.. t'~ ~ . ¢ _ ~J < ~ + ~ / . t a ~ ~~ . . ~ ~ ~ ~ { ~ ~+ ! ~~ ~ ` E + rr; a ~ "_,f ' ~'r %~ . r }wC ~i+s~ : `~ ~,. ~° ~ ~y~ . Y4 ~: ~~ ~ ~;. ~ . .4 ~ ; ~'~ ~ ~ t ~? I ~ ~. ~, _ K ~K ~ ~ ~,~~ f. . q ~'n :'. ~~ ~ , r , ~ :. 1, x~~, # 4 ~~~ • ~^ e n ~~ ~~ y` _ ~.y~ ~4 y ' ~M1 ~~~ °" ~. To: Jim Regg 1~ P.I. Supervisor ' 1~JC~' ~'I ~ 7(C~'l'^ FROM: Jeff Jones Petroleum Inspector State Df Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, June l I, 2008 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1 L-17 KUPARUK RIV UNIT iL-17 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv~n~ Comm Well Name: KUPARUK RN UNIT IL-t7 API Well Number 50-029-22151-00-00 Inspector Name• Jefflones Insp Num: mitJJ0806101 13856 Permit Number: 191-043-0 i Inspection Date: 6/t/2008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ IL-17Type Inj. W T VD ~ 5868 ~ jA I 850 ~ ~~ 3000 ~ 2970 ~ ~ 2970 - - -- - - P.T. 19IOa3o TYPeTest sPT_Test psi -- - '- isoo :~A~ 90 ~ 90 --~- - 90 -- 90 -- -- - Interval 4YRTST p~F__ P -./ - Tubing 2345 - - - 2350 ~ 2350 L -2350-~'~ Notes• 3.4 BBLS diesel pumped; no exceptions noted. ~~N~~ JUL ~. 4~ 2008 Wednesday, June 11, 2008 Page I of 1 4 2D07 08/30/07 Se ,_8r~)1n.:;" f\ \", ¡,:>·~or ;).~ ::¡/ S~~NED SEP 1 8 2007 NO, 4398 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth /1\ ~ Field: Kuparuk Well Job# Log Description Date BL Color CD 2H-02 11846438 INJECTION PROFILE l )t:l' J"ð4- C)T-~ 08/21/07 1 2P-427 11846437 INJECTION PROFILE (), (' ,qÎ) '::4 - N-'?(' 08/20107 1 1A-07 11850429 INJECTION PROFILE l ) I C_ , 15' , - J ~T 08/22/07 1 10-08 11850427 SBHP SURVEY I~ -O.ç~ 08/20107 1 3A-09 11850426 GLS ¡q /-IC¡q 08/20107 1 2W-09 11850428 INJECTION PROFILE U IC- /W- ';:)l'1 08/21/07 1 1 L-17 11839642 INJECTION PROFILE UrC'_ , £1/ - ö43 08/23/07 1 2M-13 11839643 PRODUCTION PROFILE 08/24/07 1 1 G-04 11837494 INJECTION PROFILE ()/I'_ IL,(~-JVJI 08/24/07 1 2N-350 11839644 DDL dbl - l--:t.< 08/25/07 1 2N·350 11839645 PM IT ..aI, I - ,og ,") 08/26/07 1 1A-05 11839646 INJECTION PROFILE ()T ~ I iç" I -/ÆÝ-I 08/27/07 1 2H-15 11837498 INJECTION PROFILE () Ie. 1"64 -r.'irl.. 08/29/07 1 2A-04 11839649 INJECTION PROFILE 0 :r:{\~ J 1rlI- â5~~ 08/29/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . Schlumberger NO. 3357 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth /7'/- ðt/S 02/28/05 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 seA" t..iME'-f""! iU"'i 1 "'I' "on~ . JY~V W v 1'.¿.1. ! L_ wV Field: Well Job # Log Description Date BL i'ð5 -c5D 2V-12 10942845 PROD PROFILE/DEFT 02/16/05 1 18'-1-153 20-03 10922538 PROD PROFILEJDEFT 02/06/05 1 &l û-'O - 2.i &? 10-39 10942838 INJECTION PROFILE 02/11/05 1 /g'j--Dlfr 2V-10 10942846 PROD PROFILE/DEFT 02/17/05 1 J.O(- J:63 1 C-131 10942848 INJECTION PROFILE 02/19/05 1 /90 - /t?! 1A-19 10942839 PRODUCTION PROFILE 02/12/05 1 /79...0/0 2N-308 10942843 PRODUCTION PROFILE 02/14/05 1 19/-~ 1 L-17 10942850 INJECTION PROFILE 02/21/05 1 '"1 0 J.I. ..... J? h 1B-15A 10922540 SCMT 02/24/05 ;1'- {' 1 L-24 (REDO) 10942834 RST WFL & PPROF 01/26/05 1 tì /..,!Jfv ~ Kuparuk .~ Color CD 1 ~ SIGNdÁt~! áth~ DATE: ~þ- Please sign and returie copy of this transm iltal to Beth at the above address or fax to (907) 561-8317. Than k you. $(2.. bl \h l04 Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us; and Jim_Regg@admin.state.a STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test OPERATOR: ConocoPhillips Alaska Inc. FIELD 1 UNIT 1 PAD: KRU 1L DATE: 06/14/04 OPERATOR REP: Brake 1 Rogers AOGCC REP: Waived Packer Depth Pretest Initial 15 Min. 30 Min. Well\1 L-01 I Type Inj I N I 1.V.D. I 5762 I Tubing I 8°1 8°1 8°\ 8°I,nterva, 4 P.TD. 1841730 Type Test P Test psi 1500 Casing 240 1740 1720 1720 P/F P Notes: well11L-03A I Type Inj I S I T. VD. 4456 I Tubing 1 255°1 255°1 255°1 255°\ Interval \ 4 P.TD. 1990370 Type Test P Test psi 1500 Casing 450 1800 1760 1760 P/F P Notes: well11L-05 I Type Inj I G I T. VD. I 5826 I Tubing I 354°1 354°\ 354°1 354°1 Interval 1 4 P.T.D. 1841230 Type Test P Test psi 1500 Casing 700 1740 1710 1700 P/F P Notes: well 1L-07 Type Inj I S I 1. VD. I 5738 I Tubing 255°\ 255°1 2550 I 255°I,nterva, 4 P.T.D. 1841450 Type Test P Test psi 1500 Casing 560 1740 1740 1740 P/F P Notes: well 1L-10 I Type Inj I S I T.VD. I 5866\ Tubing 179°1 179°1 179°1 179°\ Interval I 4 P.T.D. 1900350 Type Test P Test psi 1500 Casing 1240 2500 2450 2450 P/F P Notes: well 1L-14 I Type Inj I G I T.VD. I 5768 I Tubing I 28°°1 28°°1 28°°1 280011nterval 4 P.TD. 1910100 Type Test P Test psi 1500 Casing 650 1700 1680 1680 P/F P Notes: well11 L-16 1 Type Inj I N I TV.D. 1 5794 1 Tubing 1 9°1 9°1 9°1 9°I,nterva, 4 P.TD. 1841810 Type Test P Test psi 1500 Casing 125 1625 1620 1620 P/F P Notes: well 1L-17 1 Type Inj I G \ TVD. I 5868 I Tubing 326°1 326°1 33°°1 33001,nterval 4 P.TD. 1910430 Type Test P Test psi 1500 Casing 725 1725 1720 1720 P/F P Notes: we1l11L-18 I Type Inj I S \ TVD. I 5859 \ Tubing I 189°1 189°1 189°1 189°I,nterval 4 P.TD. 1910350 Type Test P Test psi 1500 Casing 470 2600 2550 2540 P/F P Notes: Well\1L-21DPNI Type Inj I S \ T.VD. I 57691 Tubing 229°1 229°1 229°1 229011nterval 4 P.T.D. 1910060 Type Test P Test psi 1500 Casing 60 1760 1760 1760 P/F P Notes: Well 11 L-22 1 Type Inj Is 1 TV.D. 5909 Tubing 23°°1 23°°1 23°°1 23001'nterva' 4 P.TD. 1901640 Type Test P Test psi 1500 Casing 60 1760 1750 1750 P/F P Notes: well 1 L-25 I Type Inj IN I T.V.D. I 5884 Tubing I 125°\ 125°1 125°1 125°1 Interval 1 4 P.TD. 1910700 Type Test P Test psi 1500 Casing 410 1760 1720 1720 P/F P Notes: MIT Report Form Revised: 05/19/02 MIT KRU 1L 06-14-04.xls 6/15/2004 1; Operations Perfonned: Abandon STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS w:JA1f 10 tJAG¡ , [] , "s~spend" 0 ,': ' Operation Shutdown D Perforàtë ,0'" , " Variance 0 Annuiar Disp. 0 ::'0°, ',:',: ,',',Rp',:"U~IPI"~T',i:ur"bw,' ':n',êgÌI",::OO",":"" ,'" ,':PI,~~r~~~,',m,',:ti,'O,;:n.s:,:,:",':"D,'[J',, ' Stimulate [:J:,', ",' ,',Time:EXtension 0,' ':,' :'9Ítier'0 , ¡:»e~pra~~"New Poo!,', " :~~~edj~r ?USpended' Well, :' 0 ' , ,,'4"C:;~:~::~õ ' ,~tOry[j,'" 5. Permit to ~:~~:~ber. 'St~ti~~phiC ' 0 SerVice' ' '0:' 6. API Number: 50-029-22151-00 . ... , 'Alter:"C~~si~Q: " : Change A,pproved :Pr9g~~Yf , 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 130' 9. Well Name and Number: 1 L-17 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: 10. Field/Pool(s): Kuparuk Oil Pool Total Depth Effective Depth Casing Structural CONDUCTOR SUR. CASING PROD. CASING Perforation depth: measured 8700' feet true vertical 6323' feet measured 8560 feet true vertical 7545 feet Length Size' MD 122' 16" 122' 4478' 9-5/8" 4608' 8545' 7" 8675' Plugs (measured) , Junk (measured) TVD Burst Collapse 122' 4435' 7535' Measured depth: 8170-8242; 5342-8370; 8446-8460 RECEIVED FEe 0 3 2004 Alaska Oìl & G C ' as ons" Comrm:\~,s¡(Jn Anchorage true vertical depth: 5961-6010; 6078-6097; 6149-6159 Tubing (size, grade, and measured depth) 3-1/2" ,J-55, 8082' MD. Packers & SSSV (type & measured depth) pkr= BAKER 'HB' pkr= 8032' SSSV= SSSV SSSV= 1791' , :12.'Sti"mulation or cement squeez~ summarY;," ' '" , In~~rvals t~eated (measured) "N/A "13. , ' Trèatmënt descriptions .Including volumes' ~sed and final ,pressure: Repressl)tative:Daily,'Aver,age Production. orlnjëction Data: " , Gas~Mcf.., ' .., Watër-Bbl " , " , 2206 : " 4ç¡04: ,', , ' ' ,: ", '15; Well Class after, proposed wor,l<:, ,: ExploratorY,' 0 'D,~~ßlopmedt [j ': SerVice, " 0 , ' .. ... Daily Heport of Well Operations ,_X ,16. Well StatLis 'after proposed work " , " ' QilO', GasO' WAGŒ] , ,:(3INJO WINJ 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: ,Oil-Bbl' Casíri Pre'sslire 11"5Ö' .1'1 ~ö, Tubin PressLire 2~90 " 3704 Prior, tp well C?peration, , , ,Supsequent ,to 'operation, "14.. A~aëhments ',' ,,:' , , Copies of Logs arid SurVeys: run. - ' :,ØQÖt~çf' , , WDSPLO Title Phone Form 10-404 ~7r\~~ rEB 1 8 200¡~ ORI G\NAL IBJMS l FEB O:,i :8 SUBMIT IN DUPLICATE 1 L-17 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 01/15/04ICo.m'meiic.ed,:WAG :~iqn :, '":' , :1 "'1 MEMORANDUM TO: Dan Seamount~~t') Commissioner THRU: Blair Wondzell P.I. Supervisor FROM: John CrisP: ,~,~ Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: September 11, 2000 SUBJECT: Mechanical Integrity Tests Phillips Alaska Inc. 1L Pad 16,17,18,21,22 Kuparuk River Unit Kuparuk River Field NON- CONFIDENTIAL I Packer Depth Pretest Initial 15 Min. 30 Min. WellI 1L-16 I Typelnj.! S } T.V.D. I 5800 J Tubi~g 12650 I 2650 I 2650 I 2650 I,n{erv.,l 4 I P'T'D'I 1841810 ITypetestl P I Testpsil 1450'J CasingI 490 116751163O116251 .P/FIE" I Notes: WellI 1L-17 ITypelnj. I S I T.V.D. I 5871 ~ i~ i~ Jlnte~alI 4 P.T.D.I 1910430 ITypetestI P I TestpsiI 1468 I Casingl 600 I' 1550 I ~840 I ~520 I P/F I E' Notes: WellI 1L-18 J Typelnj.I S I T.V.D. J 5857 I TubingJ 2250 I 2250 J 2250 J 2250 J lntewalJ 4 P.T.D,.I 1910350 ITypetestl , P JTestpsiI 1464 I Casingl 500 ,I '1580 I ~860 I ~850 I P/F I E~ Notes: ' WellI 1L-21 I Typelnj.! 'S I'T.V.D. I .5678 I Tubingl ~ I ~ ! ~ I lnte~all'4 'P.T.D.I 1900540 ITypetestl P ITes{psil 1420 I Casingl 520 I ~590 I ~580 I ~575I P/FIE' Notes: WellI 1L-22 I Type,nj.I , ]T.V.D. IS924 I Tubingl ~300'l ~32S ]~32S 1~325 I,.,.~.,I 4 ,. P.T.D.I 1901640 ITypetestl P ITestpsil.~4~. I Cas~n,l s20 I 1590l 1580 I 1575 I P/F, I - P' Notes: Type INJ, Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details No failures witnessed. Testing went well with no problems.cncounta'ed. Interval I= Initial Test 4= Four Year Cycle V= Required by Vadance W= Test during Workover O= Other (describe in notes) .I.T.'s performed: 5_ Number of Failures: 0_ Attachments: Total Time during tests: 2 hrs. c.c; MIT report form 5/12/00 L.G. MIT KRU 1 Lb 9-11-00jc.xls 9/13/00 j. ARCO Alaska, Ipr-~ *~% -~' Post Off' !ox 100360 Anchora~=, Alaska 99510-0360 Telephone 907 276 1215 October 26, 1993 ~ Russell A. Douglass, Commissioner AMl;~ska Oil and Gas Conservation Commission ~ ~,,~_ , 3001 Porcupine Drive · Anchorage, Alaska 99501 *~/~'o,~.., '"~'~ Re: Third Quarter 1993 Kuparuk River Field Injection Surveys Dear Mr. DouglasS: Attached are injection surveys consisting of separate zone tests and cased-' hole logs performed or analyzed by ARCO Alaska as operator of the Kuparuk River Field during the third quarter of 1993. These surveys are pedormed on wells with both A and C Sand injection as required by Rule 4 of Conservation Order No. 198. Blue-line and sepia copies of. all logs are included. :? If you have any questions concerning these injection profiles, please call me at 263-4241. Sincerely, P. S. White ~ Senior Engineer Kuparuk Petroleum Engineering ARCO Alaska. Inc. is ,1 Subsidiary of AtlanticRichlleldCompany , Alaska Oil Gas Conscr~,ation Commission 300i Porcupine Drive Anchorage, Alaska §§501-3192 9117-279-1z!~ To: Permit # ..... ~.2"- 59 The following data is hereby acknowledged as being received: 0u~nti~ _ Copy sent to sender: Yes ~ Well N',amc ~FY.P~; Run Date Ku@aruk Kupamk Kuparuk Kuparuk Kupamk K.upm'uk River Unit iA..-11 River 'Unit 1L...10 River Unit 1L~14 River Unit 1L- River U'nit 11L-..22 Kupamk River Unit IR 04 Kuparuk River 'Unit 1¥'-10 Kuparuk River [~nit i ¥.,-i i Kuparuk River U'nil 1'Y42 Kupamk River Unit 1¥.-15 Kuparuk Kupamk Kupamk Kuparuk Kupa,ruk iqupam~ Kupamk Kupamk Kuparuk Kuparuk River t, Jnit 213-08 J:~'~- '~' River Unit 2C.-02 ~ver Uni't 2C-04 ~--~ R~ver Unit 2C 05 ~- ~ ~ I~vcr U'nit 2C-06 ~/~ River Unit 2V--i0 ~-- ~ t~ver 'unit 2V.-I 3 ~- ~ o River 'Unit 30-12 ~ ~-- ~ 3 River Unit 3H-02 R~ / ~ 2 River Unit 3G-20 ~--/g ] Water };iow '[.og ('i'q-)T-.P) Injection Profile Injection Profile Injection Profile injection Profile Injection Profile Injection Profile Injection Profile j fi -- in tx: on ~rome Injection l~ofile Injection Profile lnj~:tion Profile Injection Profile Injection Profile Survey Inj~tion Profile Injection ProEle Production i' Production Inj~tion Profile lniection ,Profile Survey injtmtion Profile 07.lA N i g91 10-.1-.91 03 N'O~MBER1991 4 NOVEML-II:';I.~. 1991 4 N'O'vqT!MBER. 1991 11--06..-1991 6/30/91 12--13,.---1991 i i--19..-9i 11..17-..1991 12...2-91 12-..27..1991 26 DEC 1991 10--27.-1991 11/25191 ! 1...16..-1991 §..-.li, iNE..-199i 31 ..,.I'ULY., 1991 11 NOV 1991 10tl 19/91 11.-29.--1991 Received by: Dated: Copy sentto sender: Yes // No ~ RECEIVED MAR 2 6 1992 Alaska 0il & Gas Cons. Commission Anchorage STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMIbSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well GAS SUSPENDED ABANDONED SERVICE ) v~ '.~ 2 Nam r 7 Permit Number ARCqAlaska, Inc 91-43 3 Address ' 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22151 .. , 4 Location of well at surface ~"~.~~ ._ 9 Unit or Lease Name ~ uu'~"~'[[:~'~b~ !.~C_:;:~i~'s~':~:~--'~; KUPARUK RIVER 357' FNL, 143' FEL, SEC 31, T11N, R10E, UM At Top Producing Interval ~.~.~_x/~/,~/~ ~tj=[~ll ! 10 Well Number 1228' FSL, 1167' FWL, SEC 31, T11N, R10E, UM 950' FSL, 893' FWL, SEC 31, T11N, R10E, UM ~ ....... ~'~'~ ' KUPARUK RIVER FIELD 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. KUPARUK RIVER OIL POOL RKB 130, PAD 88' GLJ ADL 25659 ALK 2585 i2 Date Spudded 4/2/91. 13 Date T.D. Reached 4/9/91. 14 Date Comp. , Susp. or Aband.6/24/91. 115 Water Depth' if OffshOre NA feet MSL 116 NO' Of COmpletiOns'l 8700"'i7 Total Depth (MD+TVD)MD, 6322' TVD 8586'18 Plug Back Depth (MD+TVD)19 Directional SurvoYMD, 6244' TVD YES D NO D 120 Depth where SSSV set1791' foot MD I21 Thickness Of permafrOst1500' APPROX 22 Type Electric or Other Logs Run DIL, SFL, LDT, CNL, CET, CBL, GYRO 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Bo'FrOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 SURF 122' 24" 235 SX ASI 9-5/8" 36# J-55 SURF 4608' 12-1/4" 650 SX TYPE E, 450 SX CLASS G 7" 26# J-55 SURF 8675' 8-1/2" 275 SX CLASS G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 8170'-8242' W/2-1/8" STRIP GUN @ 6SPF MD 5961'-6010' TVD 3-1/2" 8082' 8032' ..... 8342'-8370' W/4-1/2" CSG GUN @ 4SPF MD 6078'-6097' TVD 8446'-8460' W/4-1/2" CSG GUN @ 4SPF MD 6149'-6158' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED ,,. SEE ATTACHED ADDENDUM 27 PRODUCTION TEST , Date First Production IMethod 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 Flew Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIV[,D OCT 2 5 lggl Alaska 0il & Gas Cons. 6om~ssiOn Anch0racjO Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KUPARUK C TOP 8166' 5958' NA KUPARUK C BO'I-I'OM 8238' 6006' KUPARUK A TOP 8312' 6057' KUPARUK A BO-FI-OM 8466' 6162' 31. LIST OF ATTACHMENTS GYRO,FRAC, & WELL HISTORY 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion repod and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 7/25/91 1L-17 Frac KRU "A" sand perfs from 8342'-8370, 8446'-8460' @ 4spf in 10 stages as follows: Stage 1. Pmp Stage 2 Pmp Stage 3 Pmp Stage 4 Pmp Stage 5 Pmp Stage 6 Pmp Stage 7 Pmp Stage 8 Pmp Stage 9 Pmp Stage 10 Pmp Pmp Pmp 150 bbls DEL XL GW @ 20 bpm 6280-5040 psi 80 bbls Non XL GW @ 20 bpm 4189 psi 500 bbls DEL XL GW @ 20 bpm 4550 psi 100 bbls DEL XL GW w/2ppg @ 20 bpm 4450 psi 100 bbls DEL XL GW w/4ppg @ 20 bpm 4370 psi 75 bbls DEL XL GW w/6ppg @ 20 bpm 4500 psi 75 bbls DEL XL GW w/8ppg @ 20 bpm 4600 psi 50 bbls DEL XL GW w/10ppg @ 20 bpm 4850 psi 25 bbls DEL XL GW w/12ppg @ 20 bpm 5100 psi 12 bbls DEL XL GW @ 20 bpm 5300 psi 12 bbls Non XL GW @ 20 bpm 5250 psi 32.3 bbls Slick Diesel @ 20 bpm 5250-7800 psi 10# stage @ perfs when well screened out during flush Average Pressure: Fluid to recover: Sand in zone: Sand in casing: 4600 psi 957 bbl, 56 diesel 62,086 13,283 D~rint~ndent ~ ARCO Alaska, Inc~~ Sul3sldia~ of Atlantic Rict~hel0 Company WELL SERVICE REPORT WELL CONTRACTOR REMARKS _ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather : Temp. I Chill Factor ~ Visibility 'Wind Vel. S' Report OF 'F, miles knots__ ARCO ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: UNIT: LEASE: API: PERMIT APPROVAL: AFE: WI: 1L-17 KUPARUK RIVER UNIT ADL 25659 ALK 2585 50-029-22151 91-43 AK5547 55.252072 SPUD: 04/02/91 RELEASE: 04/11/91 OPERATION: DRILLING RIG: POOL 7 04/03/91 ( 1) TD: 416' ( 416) SUPV:JRR 04/04/91 ( 2) TD: 4067'(3651) SUPV:JRR 04/05/91 ( 3) TD: 4627' ( 560) SUPV:JRR 04/06/91 ( 4) TD: 4627'( SUPV:CTD o) 04/07/91 ( 5) TD: 4627'( SUPV:CTD o) TIH W/ DYNADRILL #2 MW: 9.0 VIS: 62 MOVED RIG FROM 1L-13 TO 1L-17. N/U AND FUNCTION TEST DIVERTER. P/U AND ORIENT BHA. DRLD F/ 122'-416'. TOH. L/D DYNADRILL. P/U AND ORIENT NEW DYNADRILL. TIH. DAILY:S47,436 CUM:$47,436 ETD:S47,436 EFC:$1,391,000 DRILLING MW: 9.9 VIS: 48 DRLD F/416'-2035', ROP = 215 FT/HR. KOP AT 300'. INCREASE MUD WT F/9.0 TO 10.0 LB/GAL. DRILL INTO GAS ZONE AT 1390' MD, 1335' TVD. CIRCULATE B/U. SHORT TRIP 11 STANDS. DRLD F/2035'-4067' DAILY:S57,332 CUM:$104,768 ETD:S104,768 EFC:$1,391,000 LAY DOWN 12.25 BHA MW:10.8 VIS: 44 DRLD F/4067'-4627': 9 5/8" CASING POINT. CIRCULATE B/U. SHORT TIH-7 STD, GAS BUBBLING IN BELL NIPPLE. TIH. CIRCULATE OUT GAS CUT MUD. GRADUALLY INCREASE MUD WT FROM 10.2 TO 10.8 PPG. GAS STILL BREAKING OUT AT BELL NIPPLE. SHORT TRIP-39 STD. TIGHT AT 2440' CIRCULATE AND CONDITION MUD, MUD GAS CUT 10.8 TO 10.1 PPG. PUMP SLUG. POH F/9 5/8" CASING. L/D DYNADRILL, MWD, AND BHA FOR INSPECTION. DAILY:S58,547 CUM:$163,315 ETD:S163,315 EFC:$1,391,000 RUNNING 9-5/8" CSG MW:10.9 VIS: 56 FINISH LD BHA FOR INSP. RU CSG TOOLS. RUN 9-5/8" CSG TO 1070' HIT BRIDGE. ATTEMPT TO WASH DOWN, COULD NOT GET PAST BRIDGE. POH W/9-5/8" CSG. RD CSG TOOLS. SLIP AND CUT DRILLING LINE. PU BHA AND TIH. DRILL THROUGH BRIDGE. ALOT OF WOOD IN RETURNS. CLEAN OUT TO 4627'. CIRC AND COND HOLE. POH. RU CSG CREW. BEGIN RUNNING 9-5/8" CSG. NO PROBLEMS @ 1070' DAILY:S56,355 CUM:$219,670 ETD:S219,670 EFC:$1,391,000 TEST BOP 9-5/8"@ 4607' MW:10.9 VIS: 50 FINISH RUNNING 9-5/8" 36 PPF J-55 BTC CSG TO 4607'_ RU CMT HEAD AND CIRC CSG. TEST LINES TO 2500 PSI. PUMP 40 BBL FW SPACER. CMT W/650 SX PERMAFROST E + .25 PPS FLAKES (224 BBL @ 12.3 PPG), TAILED IN W/450 SX CL G + 2% CACL + .25 PPS FLAKES (92 BBL @ 15.8 PPG). DISPL W/350 BBL MUD. BUMPED PLUG TO 2000 PSI. FLOATS HELD. 20 BBL GOOD CMT TO SURF. FLUSH OUT STACK WITH WATER. LD LANDING JT AND CMT HEAD. ND 20" DIVERTER SYSTEM. MU FMC 11-3/4" X 11" 3000 PSI BRADEN HEAD. BAKERLOK IN PLACE. NU 10000 PSI STACK. FUNCTION TEST BOP. PU TEST JT AND SET TEST PLUG. TEST ANNULAR TO 500 AND 2500 PSI. TEST PIPE RAMS, LINES, VALVES, AND CHOKE MANIFOLD TO 500 AND 3000 PSI. HCR VALVE WOULD NOT FUNCTION. CHANGE OUT HCR VALVE TO MANUAL VALVE WITH PERMISSION FROM STATE OF ALASKA BOP INSPECTOR. DAILY:S202,805 CUM:$422,475 ETD:S422,475 EFC:$1,391,000 WELL: 1L-17 OPERATION: DRILLING RIG: POOL 7 PAGE: 2 04/08/91 ( 6) TD: 5957' (1330) SUPV:CTD 04/09/91 ( 7) TD: 8271' (2314) SUPV:CTD 04/10/91 (8) TD: 8700' ( 429) SUPV:CTD 04/11/91 ( 9) TD: 8585'( SUPV:JRR o) DRLG 9-5/8"@ 4607' MW: 9.1 VIS: 41 FINISH CHANGING OUT HCR VALVE FOR MANUAL VALVE. FINISH TESTING BOP - OK. SET WEAR BUSHING. LD 8" NMDC FOR INSP. LD TURBINE FOR INSP. PU 8-1/2" BHA, LOAD SOURCE IN LWD TOOL. RIH. TEST CSG TO 2000 PSI - OK. DRILL FLOAT EQUIP AND 10' OF NEW HOLE TO 4637' CIRC BOTTOMS UP, TEST FORMATION TO 12.5 PPG EMW. DRILL F/4637-5957' · DAILY:S70,897 CUM:$493,372 ETD:S493,372 EFC:$1,391,000 DRLG 9-5/8"@ 4607' MW:10.6 VIS: 40 DRLD F/5957-8271'. ADT 18.5 HR. INCR MW FROM 9.1 PPG TO 10.6 PPG @ 7650' (500' ABOVE TOP OF KUPARUK). DAILY:S68,365 CUM:$561,737 ETD:S561,737 EFC:$1,391,000 LD BHA 9-5/8"@ 4607' MW:10.8 VIS: 42 DRLD F/8271-8700' ADT 10.25 HR. CIRC BOTTOMS UP. SHORT TRIP TO 9-5/8" C~RC AND COND HOLE. MW CUT F/10.6 TO 10.0 PPG. INCR MW TO 10.8 PPG. SPOT DIESEL PILL ON BOTTOM, POH 10 STANDS (PULLING WET). PUMP 2ND SLUG. POH (SLM) . LD BHA AND UNLOAD SOURCE FROM LWD TOOL. DAILY:S64,681 CUM:$626,418 ETD:S626,418 EFC:$1,391,000 FINAL REPORT REL RIG 7"@ 8675' MW:10.8 VIS: 39 FIN LD BHA. PULL WEAR RING. RU CSG CREW. RAN 100 JTS 7" 26 PPF J-55 BTC AND MARKER JT AND 106 JTS 26 PPF J-55 BTC MOD CSG. CIRC AND COND MUD WHILE BATCH MIX CEMENT. TEST LINES TO 4000 PSI. PUMP 10 BBL ARCO PREFLUSH AND 35 BBL ARCO SPACER (11.0 PPG). MIX AND PUMP 275 SX (58 BBL) CL G + LATEX ADDS (15.6 PPG). DROP TOP PLUG, DISPL WITH 10.8 PPG NACL/NABR. RECIP CSG. HAD FULL RETURNS. BUMP PLUG TO 3500 PSI FOR CSG TEST - OK. FLOATS HELD. PU BOP AND SET SLIPS (190,000 LB PULL ON CSG). CUT CSG, SET PACKOFF. SET BACK BOP, NU TBG SPOOL. TEST PACKOFF TO 3000 PSI - OK. REL RIG @ 0600 Il-APR-91. DAILY:S232,821 CUM:$859,239 ETD:S859,239 EFC:$1,391,000 DRILLING 7P~RI[gTENDE~ ARCO ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: UNIT: LEASE: API: PERMIT APPROVAL: AFE: WI: 1L-17 KUPARUK RIVER UNIT ADL 25659 ALK 2585 50-029-22151 91-43 AK5547 55.252072 ACCEPT: 06/20/91 RELEASE: 06/24/91 OPERATION: COMPLETION RIG: NORDIC 06/21/91 (10) TD: 8585 PB: 8586 SUPV:DB/WM 06/22/91 (11) TD: 8585 PB: 8586 SUPV:DB/WM 06/23/91 (12) TD: 8585 PB: 8586 SUPV:DB/WM 06/24/91 (13) TD: 8585 PB: 8586 SUPV:DB/WM RUNNING 3-1/2" COMPLETION 7"@ 8675' MW:10.8 NaCl/Br ACCEPT RIG @ 1000HRS 6-20-91. NU BOP'S AND TEST. RU SWS AND PERFORATE WELL. RU AND RUN 3-1/2" SINGLE COMPLETION. DAILY: $53,759 CUM: $912,998 ETD: $943,759 EFC: $1,360,239 POH W/ RETRIEVING TOOL 7"@ 8675' MW:10.8 NaC1/Br FINISHED RUNNING 3-1/2" COMPLETION. SPACED-OUT AND SET PACKER. SHEARED PBR. TESTED SSSV. PACKER WOULD NOT SEAL. POH AND STAND BACK 3-1/2" COMNPLETION. MU PKR RETRIEVING TOOL AND GIH. COLD NOT LATCH PKR. POH W/ DP AND PKR RETRIEVING TOOL. DAILY:S28,147 CUM:$941,145 ETD:S971,906 EFC:$1,360,239 CIRCULATE 7"@ 8675' MW:10.8 NaC1/Br LD RETRIEVING TOOL AND PU SPEAR AND GRAPPLE. GIH AND SPEAR INTO PBR @ 8008'. PULL PKR OUT OF HOLE AND LD SAME. MADE BIT AND SCRAPER RUN. DAILY:S29,793 CUM:$970,938 ETD:S1,001,699 EFC:$1,360,239 NORDIC 1 RIG RELEASED 7"@ 8675' MW:10.8 NaC1/Br CBU. POH. RU AND RE-RUN 3-1/2" SINGLE COMPLETION. SPACED-OUT AND SET PKR. SHEARED PBR. TEST SSSV. OK. ND BOP'S AND NU TREE. TEST SAME. OK. FREEZE PROTECT AND SECURE WELL. RR @ 0300 HRS, 6-24-91 DAILY:S182,695 CUM:$1,153,633 ETD:S1,184,394 EFC:$1,360,239 RECEIVED ,~-~;,~::,~, Oil a SUB - S URFA CE DIRECTIONAL SURVEY r~ UIDANCE r~ ONTINUOUS r~ OOL Company ARCO ALASKA~ INC. Well Name 1L-17 (357' FNL, 143' FEL, SC 31, T11N, R10E) Field/Location KUPARUK, NORTH SLOPE, ALASKA Job Reference No. 74795 Logged By' MCBRIDE Date: 19-APR-91 Computed By- SINES GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. 1L - 17 KUPARUK RIVER NORTH SLOPE, ALASKA SURVEY DATE: 19-APR-1991 METHODS OF COMPUTATION TOOL LOCATION: INTERPOLATION: VERTICAL SECTION: ENGINEER: M.MCBRIDE TANGENTIAL- Averaged deviation and azimuth LINEAR HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 45 DEG 4 MIN WEST COMPUTATION DATE: 14-AUG-91 PAGE 1 ARCO ALASKA, INC. 1L - 17 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 19-APR-1991 KELLY BUSHING ELEVATION: 130.00 FT ENGINEER: M.MCBRIDE INTERPOLATED VALUES FOR EVEN IO0,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/WESI DIST. AZIMUT~ FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 100 O0 200 O0 3O0 O0 4OO O0 500 O0 600 O0 700 O0 800 O0 900 O0 0.00 -130.00 0 0 100.00 -30.00 0 26 200.00 70.00 0 18 299.99 169,99 0 29 399.97 269 97 2 28 499.65 369 65 6 26 598.72 468 72 9 14 697.08 567 08 11 13 794.88 664 88 12 57 891,79 761 79 15 38 N 0 0 E N 72 44 W N 72 16 W N 71 14 W S 61 35 W S 60 41W S 62 18 W S 63 9 W S 61 41 W S 59 29 W 0 O0 0 03 0 35 0 67 2 44 9 83 22 81 39 97 59 85 83 61 0 O0 0 43 0 20 0 O0 2 27 3 69 3 45 1 20 3 24 2 44 0 O0 N 0 02 N 0 20 N 0 46 N 0 105 3 89 S 10 41 S 18 63 S 28 2! S 40 40 S 0 O0 E 0 06 W 0 70 W 1 40 W 3 35 W lO O0 W 21 84 4' 37 87 W 56 40 w 77 79 W 0.00 N 0 0 E 0.06 N 73 12 W 0.73 N 74 4 W 1.48 N 72 2 W 3.35 S 88 18 W 10.73 S 68 45 W 24. 19 S 64 32 W 42.21 S 63 48 W 63.06 S 63 26 w 87.66 S 62 33 W 1000.00 1100.00 1080.53 950 1200.00 1170.47 1040 1300.00 1257.49 1127 1400.00 1342.41 1212 1500.00 1424.22 1294 1600.00 1501.08 1371 1700.00 1572.40 1442 1800.00 1641.56 1511 1900.00 1710.37 1580 987.35 857 35 19 6 53 23 18 47 28 7 49 30 49 41 33 3 22 37 5 08 42 33 40 45 53 56 46 5 37 47 21 S 57 2 w S 48 19 w 148 S 44 35 w 191 S 45 32 W 240 S 44 33 W 293 S 44 33 w 351 S 44 40 W 415 S 44 29 w 485 S 44 54 W 557 S 42 58 W 629 112 19 11 72 97 76 23 13 20 43 97 5.41 5.17 3.13 2.84 4.01 4.68 5.99 1 .88 1.13 1.40 55.71 S 102.90 W 117 01 S 61 34 W 77.84 S 131.56 W 152 108.36 S 162.72 W 195 142.92 S 197.81 W 244 180.40 S 234.98 W 296 221.30 S 275,36 W 353 266.85 S 320.17 W 416 316,71 S 369.42 W 486 368.19 S 420.08 W 558 420.17 S 470.69 W 630 .86 S 59 23 W 5O S 56 20 W 04 S 54 9 W 24 5 52 29 W 26 5 51 13 W 80 S 50 11 w 60 S 49 24 w 60 S 48 46 w 95 S 48 15 W 2000.00 1778.67 1648 67 46 19 2100.00 1848.43 1718 2200.00 1919.19 1789 2300.00 1988.22 1858 2400.00 2054.98 1924 2500.00 2123.05 1993 2600.00 2192.15 2062 2700.00 2262.03 2132 2800.00 2332.29 2202 2900.00 2402.72 2272 43 45 12 19 44 58 22 48 11 98 47 33 05 46 50 15 45 50 03 45 34 29 45 11 72 45 12 S 43 51 w S 45 3 w 774 S 44 52 w 845 S 39 45 w 917 S 4O 15 w 991 S 40 56 w 1064 S 41 35 w 1136 S 42 5 W 1208 S 42 29 W 1279 S 42 49 W 1350 702 97 61 27 48 62 65 78 20 27 21 1 .28 1.13 1 .78 2.26 1 .62 0.69 0.76 0.33 O.24 O. 64 473.40 S 520.71 W 703.73 S 47 43 W 524.53 S 570.88 W 775.27 S 47 25 W 574.36 S 620.98 W 845.88 S 47 14 W 627.95 S 669.53 W 917.92 S 46 50 W 685.11 S 717.22 W 991.85 S 46 19 w 740.71 S 764.91 W 1064.77 S 45 55 W 795.02 S 812.62 W 1136.84 S 45 38 w 848.31 S 860.33 w t208.22 S 45 24 W 900.97 S 908.19 W 1279.28 S 45 14 W 953.18 S 956.29 W 1350.21 S 45 6 W 3000.00 2473.49 2343.49 44 47 3100.00 2544.65 2414.65 44 21 3200.00 2616.33 2486.33 44 13 3300.00 2686 19 2556.19 47 26 3400.00 2753 45 2623.45 47 51 3500.00 2820 50 2690.50 47 58 3600.00 2887 62 2757.62 47 48 3700.00 2954 79 2824.79 47 35 3800.00 3022 44 2892.44 47 15 3900.00 3091 05 2961.05 46 9 S 43 8 w 1420 81 S 44 2 w 1491 S 44 46 w 1560 S 42 52 w 1632 S 42 55 w 1706 S 43 47 w 1780 S 45 11 w 1854 S 45 47 w 1928 S 46 16 w 2002 S 47 1 w 2074, 03 75 27 21 37 49 57 20 92 0 34 1 O8 1 03 1 94 0 1 0 0 1 0 59 18 72 64 O6 6O 1004 89 S 1004.44 w 1420.81 S 44 59 w 1055 1105 1157 1211 1265 1318 1370 1421 1471 85 S 1052.79 W 1491.04 S 44 55 W 63 S 1101.62 W 1560.76 S 44 54 W 06 S 1151.33 W 1632.28 S 44 51 W 40 S 1201.55 W 1706.23 S 44 46 W 39 S 1252.44 W 1780.40 S 44 42 W 23 S 1304.43 W 1854.53 S 44 42 W 13 S 1357.29 W 1928.60 S 44 44 W 29 S 1410.27 W 2002.23 S 44 47 W 22 S 1463.16 W 2074.93 S 44 51 W COMPUTATION DATE: 14-AUG-91 PAGE 2 ARCO ALASKA, INC. 1L - 17 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 19-APR-1991 KELLY BUSHING ELEVATION: 130.00 FT ENGINEER: M.MCBRIDE INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTZCAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUT~ DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 4000.00 3160 38 3030.38 46 5 4100.00 3229 45 3099.45 46 33 4200 O0 3298 37 3168.37 46 14 4300 O0 3367 45 '3237.45 47 9 4400 O0 3433 65 3303.65 49 13 4500 O0 3499 52 3369.52 48 25 4600 O0 3566.38 3436,38 47 34 4700 O0 3633.71 3503.71 47 59 4800 O0 3700,55 3570,55 47 57 4900.00 3768.20 3638.20 47 4 S 47 21 W 2146.93 5 46 29 W 2219.20 S 46 49 W 2291.64 5 45 36 W 2363.91 S 43 23 W 2438.84 S 43 35 W 2514.05 S 43 35 W 2588.38 5 43 0 W 2662.29 S 42 42 W 2736.60 5 45 26 W 2810.22 041 0 65 0 88 4 79 0 48 0 58 1 15 0 54 0 86 1 49 1520 19 S 1516.03 W 2146 94 S 44 55 W 1569 1619 1669 1722 1777 1831 1885 1939 1992 59 S 1568.84 W 2219 21 S 44 59 W 35 S 1621.52 W 2291 64 S 45 2 W 10 S 1673.97 W 2363 91 S 45 5 W 96 S 1726.08 W 2438 84 S 45 3 W 56 S 1777.84 W 2514 05 S 45 0 W 35 S 1829.19 W 2588 39 S 44 58 W 24 S 1879.81W 2662.29 S 44 55 W 77 S 1930.39 W 2736.62 S 44 52 w 92 S 1981.35 W 2810.25 S 44 50 W 5000.00 3836.22 3706 22 47 19 5100.00 3903.02 3773 5200.00 3969.49 3839 5300 O0 4036.r13 3906 5400 O0 4102,85 3972 5500 O0 4170.48 4040 5600 O0 4238.51 4108 5700 O0 4305.67 4175 5800 O0 4372.21 4242 5900.00 4439.49 4309 O2 48 29 49 48 17 13 48 14 85 47 50 48 47 6 51 47 14 67 48 13 21 48 10 49 47 35 S 45 29 w 2883 52 S 45 17 w 2957 5 44 36 w 3032 S 44 17 w 3107 S 43 38 w 3181 S 42 31 w 3255 5 42 42 w 3328 S 44 17 w 3402 S 45 46 w 3477 S 47 11 w 3551 93 64 2O 67 29 49 57 21 0 95 0 53 1 04 012 1 37 0 73 381 0 70 4.18 0.55 2044.23 S 2033.71 W 2883.54 S 44 51 W 2096 53 S 2086.63 W 2957 95 S 44 52 W 2149 2202 2256 2309 2364 2417 2470 2521 34 S 2139.47 W 3032 65 S 2191.60 W 3107 18 5 2243 40 W 3181 99 S 2293 71 W 3255 26 S 2342 96 W 3328 58 5 2394 41 W 3402 76 S 2446 79 W 3477 25 S 2500 86 W 3551 66 5 44 52 W 22 S 44 51W 70 S 44 50 w 32 S 44 48 W 54 S 44 44 W 63 S 44 43 W 27 S 44 43 W 19 S 44 46 W 6000 O0 4506.77 4376 77 47 48 6100 6200 6300 6400 6500 6600 6700 6800 6900 O0 4573.82 4443 O0 4640.74 4510 O0 4707.21 4577 O0 4773.31 4643 O0 4838.99 4708 O0 4904.65 4774 O0 4970.53 4840 82 47 58 74 48 5 21 48 32 31 48 47 99 49 9 65 48 47 53 48 29 5 47 2 W 3625 O8 O0 5038.44 4908 O0 5107.16 4977 S 46 43 W 3699 S 46 19 w 3773 S 46 5 w 3848 S 45 41 w 3923 S 45 12 w 3998 S 46 0 w 4074 S 46 2 w 4149 44 46 36 S 47 30 w 4222 16 46 53 S 47 5 w 4295 24 52 21 25 65 07 29 64 23 0.56 0.52 0.20 010 0 43 1 34 0 49 2 72 0 75 1 95 2571.60 S 2555 06 W 3625 11 S 44 49 W 2622.34 S 2609 2673.48 S 2663 2725.21 S 2717 2777,41S 2770 2830.38 S 2824 2883.17 S 2878 2935.54 S 2932 2985.40 S 2986 3034.72 S 3039 19 W 3699 O9 W 3773 O0 W 3848 91W 3923 58 W 3998 45 W 4074 45 W 4149 32 w 4222 64 W 4295 26 S 44 51W 54 S 44 53 W 23 S 44 55 W 26 S 44 56 W 66 S 44 56 W 08 S 44 57 W 30 S 44 58 W 64 S 45 1W 23 S 45 3 W 7000.00 5175.07 5045.07 47 7100.00 5242.86 5112.86 47 41 7200.00 5309.79 5179.79 47 58 7300.00 5377.00 5247.00 47 50 7400.00 5443.95 5313.95 48 2 7500.00 5510.89 5380.89 47 58 7600.00 5578.07 5448.07 47 45 7700.00 5645.17 5515.17 47 52 7800.00 5712.18 5582.18 47 57 7900.00 5779.19 5649.19 47 52 S 46 51 W 4368.60 S 46 49 W 4442.07 S 46 31 W 4516.34 S 46 7 W 4590 37 S 45 48 W 4664 64 S 45 21 W 4738 93 S 44 44 W 4813 O0 S 44 27 W 4887 15 S 44 0 w 4961 36 S 43 49 W 5035.58 0.94 1 .32 1.19 O.97 0.39 0.56 0.54 0.58 0.65 0.36 3084.77 S 3093.35 W 4368 60 S 45 5 W 3135 14 S 3146.88 W 4442 3186 3237 3288 3340 3393 3446 3499 3552 06 5 3201.00 W 4516 25 S 3254.51 W 4590 87 S 3307.91 W 4664 85 S 3360.99 W 4738 19 S 3413.41 W 4813 01 S 3465.44 W 4887 21 S 3517.20 W 4961 73 S 3568.64 W 5035 07 S 45 6 W 35 S 45 8 W 38 S 45 9 W 65 S 45 10 W 94 S 45 10 W 01 S 45 10 W 16 S 45 10 W 37 S 45 9 W 58 S 45 8 w COMPUTATION DATE: 14-AUG-91 PAGE 3 ARCO ALASKA, INC. 1L - 17 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 19-APR-1991 KELLY BUSHING ELEVATION: 130.00 FT ENGINEER: M.MCBRIDE INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUT~ DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/100 FEET FEET FEET DEG MIN 8000.00 5846.18 5716.18 47 55 5 43 41 W 5109.80 8100.00 5913.51 5783.51 47 27 S 43 53 W 5183.72 8200.00 5981.20 5851.20 47 16 S 44 30 W 5257.32 8300.00 6049.20 5919.20 46 55 $ 44 45 W 5330.64 8400.00 6117.48 5987.48 47 1 5 44 33 W 5403.70 8500.00 6185.77 6055.77 46 54 S 44 26 W 5476.74 8600.00 6254.02 6124.02 46 58 S 44 26 W 5549.98 8700.00 6322.27 6192.27 46 58 5 44 26 W 5623.07 0 40 3606 39 5 3619 95 w 5109 80 S 45 6 w 0 53 3659 79 S 3671 09 w 5183 72 S 45 5 w 1 16 3712 64 5 3722 33 w 5257 32 S 45 4 w 1 15 3764 64 S 3774 01 w 5330 64 S 45 4 w 0 19 3816 60 S 3825 38 w 5403 70 S 45 4 w 4 01 3868 71 S 3876 57 W 5476 74 S 45 3 w 0 O0 3920 8! S 3928 04 w 5549 98 S 45 3 w 0 O0 3973 01 S 3979 20 w 5623 07 S 45 3 w ARCO ALASKA, INC. 1L - 17 KUPARUK RIVER NORTH SLOPE, ALASKA COMPUTATION DATE: 14-AUG-91 PAGE 4 DATE OF SURVEY: 19-APR-1991 KELLY BUSHING ELEVATION: 130,00 FT ENGINEER: M,MCBRIDE INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTh DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG 0,00 I000,00 987,35 857,35 19 6 S 57 2 W 112 2000,00 1778,67 1648,67 46 19 S 43 51 W 702 3000,00 2473,49 2343 49 44 47 S 43 8 W 1420 4000,00 3160,38 3030 38 46 5 S 47 21 W 2146 5000,00 3836,22 3706 22 47 19 S 45 29 W 2883 6000,00 4506.77 4376 77 47 48 S 47 2 W 3625 7000,00 5175.07 5045 07 47 11 S 46 51 W 4368 8000,00 5846.18 5716 18 47 55 S 43 41 W 5109 8700,00 6322,27 6192 27 46 58 S 44 26 W 5623 0,00 -130,00 0 0 N 0 0 E 0 O0 19 97 81 93 52 08 6O 8O 07 0.00 0 O0 N 5.41 55 1,28 473 0,34 1004 0.41 1520 0.95 2044 0.56 2571 0,94 3084 0,40 3606 0,00 3973 71S 102 40 S 520 .89 S 1004 19 S 1516 23 S 2033 60 S 2555 77 S 3093 39 S 3619 01 S 3979 0 O0 E 0.00 N 0 0 E 90 W 117.01 S 61 34 w 71W 703.73 S 47 43 W 44 W 1420.81 S 44 59 w 03 W 2146.94 S 44 55 W 71W 2883.54 S 44 51W 06 W 3625.11 S 4~ 49 W 35 W 4368,60 S 45 5 ~ 95 W 5109.80 S 45 6 W 20 W 5623.07 S 45 3 W ARCO ALASKA, INC. 1L - 17 KUPARUK RIVER NORTH SLOPE, ALASKA COMPUTATION DATE: 14-AUG-91 TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUT~ DEPTH DEPTH DEPTH DEG MIN DEG PAGE 5 DATE OF SURVEY: 19-APR-1991 KELLY BUSHING ELEVATION: 130.00 FT ENGINEER: M.MCBRIDE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN N 0 0 E 0.00 N 74 49 W O. 14 N 70 15 W 0.43 N 85 56 W 0.82 5 59 49 W 3.94 S 60 37 W 13.35 5 62 47 W 27.9~ S 63 6 t~ 46.32 S 60 34 W 67.92 S 59 3 W 94.35 0.00 0 O0 -130.00 0 0 130.00 130 O0 0.00 0 26 230.00 230 O0 100.00 0 25 330.01 330 O0 200.00 0 37 430.07 430 O0 300.00 3 34 530.57 530 O0 400.00 7 14 631.73 630 O0 500.00 10 8 733.59 730 O0 600.00 11 45 836.11 830.00 700.00 13 51 939.79 930.00 800.00 16 38 1045.44 1030.00 900.00 21 7 · 1154.49 1130.00 1000.00 26 13 1268.11 1230.00 1100.00 30 1 1385.24 1330.00 1200.00 32 33 1507.27 1430 O0 1300.00 37 25 1639.83 1530 O0 1400.00 44 26 1783.31 1630 O0 1500.00 46 15 1928.95 1730 O0 1600.00 47 13 2073.77 1830 O0 1700.00 45 30 2215.31 1930 O0 1800.00 45 10 2362.81 2030.00 1900 O0 48 4 5 52 46 W 127.63 5 45 3 W 170.90 S 45 53 W 224.82 5 44 31 W 285.77 5 44 31 W 355.64 S 44 45 W 442,51 5 44 42 W 545.39 5 42 52 W 65t.23 S 44 47 w 755.95 S 44 16 w 856.12 2510 15 2130.00 2000 2654 23 2230.00 2100 2796 75 2330.00 2200 2938 64 2430.00 2300 3079 48 2530.00 2400 3219 12 2630.00 2500 3365.08 2730.00 2600 3514.19 2830,00 2700 3663.16 2930.00 2800 S 39 53 w S 41 0 w 1072 S 41 54 w 1175 5 42 28 w 1276 5 42 55 w 1377 S 43 48 w 1476 S 44 43 w 1574 5 42 42 w 1680 5 43 59 W 1790 S 45 37 w 1901 964 18 O3 55 96 55 67 13 35 9O 32 S 46 20 W 2010 37 O0 46 45 O0 45 38 O0 45 11 O0 44 58 O0 44 30 O0 44 31 O0 47 48 O0 47 58 O0 47 50 3811.13 3030.00 2900.00 47 9 3956.18 3130.00 3000.00 46 7 4100.79 3230.00 3100.00 46 33 4245.62 3330.00 3200.00 46 2 4394.41 3430.00 3300.00 49 15 4545.80 3530.00 3400.00 48 7 4694,46 3630.00 3500.00 47 58 4843.77 3730.00 3600.00 47 26 4990.83 3830.00 3700.00 47 15 5140.63 3930.00 3800.00 48 20 5 47 13 W 2115 S 46 29 W 2219 5 46 44 W 2324 5 43 23 W 2434 S 43 43 W 2548 5 43 1W 2658 S 43 21W 2768 5 45 33 W 2876 S 45 8 W 2988 38 78 50 22 17 96 78 31 0 O0 0 13 0 67 1 43 4 10 1 90 2 05 2 6~, 2 56 5.44 5.88 2.53 2.99 4.93 2.63 1 .64 1.11 1 .55 3.59 1 38 0 87 0 83 0 24 0 56 1 20 2 22 0 44 1 30 0 78 1 19 012 0 64 0 52 0 29 0 94 071 3 19 0 50 0 46 0 O0 N 0 09 N 0 26 N 051 N 0875 5685 12 87 S 21 65 S 32 28 $ 46 O7 S 0 O0 E 0 28 w 0 87 W 167 w 4 70 w 13 18 w 26 59 w 43 8,3 w 63 74 w 87 32 W 0.00 N 0 0 E 0.29 N 73 13 W 0.91 N 73 27 W 1 .75 N 73 0 W 4 78 S 79 29 W 14 36 S 66 4~ w 29 54 S 64 10 W 48 88 S 63 43 W 71 45 S 63 9 W 98 73 S 62 11 W 64.74 S 115.71 W 132 59 S 60 46 W 93.54 S 148.10 W 175 131.63 S 186.24 W 228 174 70 S 229.38 W 288 224 44 S 278.45 W 357 286 32 S 339.44 W 444 359 66 S 411.59 W 546 435 76 S 485.17 W 652 511 32 5 557.71 W 756 582 16 S 57 43 W 07 S 54 45 W 34 5 52 42 W 64 S 51 8 W 07 S 49 51 W 59 S 48 51W 13 S 48 4 W 62 S 47 29 W 628.58 W 856 72 S 47 12 W 664 03 S 699.49 W 964 48 S 46 29 W 746 824 899 973 1045 1115 1192 1272 1351 30 S 769.76 W 1072 01 S 838.46 W 1175 27 S 906.63 W 1276 25 S 974.90 W 1377 50 S 1042.83 W 1476 13 S 1111.03 W 1574 41 S 1183.97 W 1680 98 S 1259.74 W 1790 15 S 45 53 W 59 S 45 30 W 97 S 45 14 W 55 S 45 3 W 68 S 44 56 W 14 S 44 54 W 37 S 44 48 W 93 5 44 42 w 09 S 1337.79 W 1901 35 S 44 43 w 1426 93 S 1416.17 W 2010.39 S 44 47 W 1498 77 S 1492.83 W 2115.39 S 44 53 W 1569 99 S 1569.26 w 2219.78 S 44 59 w 1641 86 S 1645.47 W 2324.50 S 45 4 w 1719 88 S 1723.17 w 2434 61 S 45 3 W 1802 30 S 1801.43 W 2548 22 S 44 59 W 1882 23 S 1877.00 W 2658 18 S 44 55 W 1963.48 S 1952.44 W 2768 98 S 44 50 W 2039.50 S 2028.90 W 2876 80 S 44 51 W 2117.93 S 2108.20 W 2988 33 S 44 52 W COMPUTATION DATE: 14-AUG-91 PAGE 6 ARCO ALASKA, INC. 1L - 17 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 19-APR-1991 KELLY BUSHING ELEVATION: 130.00 FT ENGINEER: M.MCBRIDE INTERPOLA~L ~ VALUES FOR EVEN 100 FEET OF SUB-SEA 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 MIN 5290.80 4030 O0 3900.00 48 14 5440.32 4130 5587.47 4230 5736.54 4330 5885.94 4430 6034.61 4530 6183.92 4630 6334.42 4730 6486.27 4830 6638.51 4930 O0 4000.00 47 31 O0 4100.00 47 11 O0 4200,00 48 17 O0 4300.00 47 33 O0 4400.00 47 53 O0 4500.00 48 4 O0 4600.00 48 34 O0 4700,00 49 5 O0 4800.00 48 54 S 44 18 w 3100.33 S 43 12 w 3211.47 S 42 18 w 3319.31 S 44 15 w 3429.83 S 47 13 w 3540.77 S 46 54 w 3650.72 S 46 20 w 3761.55 S 46 2 w 3874.01 S 45 14 w 3988.27 S 45 54 w 4103.06 010 1 02 1 82 0 48 0 66 0 66 0 36 0 28 0 94 0 62 2197 74 S 2186 81 w 3100 35 S 44 51 w 2277 2357 2437 2514 2589 2665 2743 2823 2903 84 S 2263 47 S 2336 11 S 2413 19 S 2493 11S 2573 22 S 2654 12 $ 2735 06 S 2817 32 s 2899 88 w 3211 77 w 3319 43 w 3429 24 w 3540 81 w 3650 44 ~ 376~ 57 ~ 3874 2~ W 3988 49 S 44 49 W 36 S 44 45 W 89 S 44 43 W 82 S 44 46 W 75 S 44 50 W 57 S 44 53 4' 02 S 44 55 w 28 S 44 56 w 29 W 4103.07 S 44 58 W 6787.72 5030 O0 4900.00 46 37 6933.56 5130 7080.93 5230 7230.12 5330 7379.14 5430 7528.51 5530 7677.40 5630 7826.59 5730 7975.84 5830 O0 5000.00 47 17 O0 5100.00 47 28 O0 5200.00 47 45 O0 5300.00 48 2 O0 5400.00 47 50 O0 5500.00 47 51 O0 5600.00 47 54 O0 5700.00 47 59 8124.40 5930.00 5800.00 47 30 S 47 36 W 4213.72 S 47 6 w 4319.81 S 46 44 W 4428.00 S 46 21 W 4538.67 S 45 52 W 4649.14 S 45 11 W 4760.09 S 44 31 W 4870.39 S 43 53 W 4981.09 S 43 42 W 5091.87 S 43 58 W 5201,69 071 0 72 1 O5 0 56 0 65 0 98 0 5O 0 5O 0 26 0 32 2979 37 S 2979 73 W 4213.73 S 45 0 W 3051 3125 3201 3278 3355 3434 3513 3593 3672 47 5 3057 50 5 3136 45 S 3217 O7 5 3296 74 S 3376 05 5 3453 42 5 3530 42 S 3607 74 5 3683 66 W 4319.81 S 45 3 W 62 W 4428.00 S 45 6 W 18 W 4538.67 S 45 8 W 79 W 4649.14 S 45 10 W 03 W 4760.10 S 45 10 w 70 W 4870.40 S 45 10 W 89 W 4981.10 S 45 9 W 56 W 5091.87 S 45 7 w 56 W 5201.69 S 45 5 W 8271.84 6030.00 5900.00 47 6 8418.37 6130.00 6000.00 47 0 8564.80 6230.00 6]00.00 46 58 8700.00 6322.27 6192.27 46 58 S 44 53 W 5310.04 S 44 31 W 5417.13 S 44 26 W 5524.25 S 44 26 W 5623.07 1 .45 0.37 0.00 0.00 3750.03 S 3759.49 W 5310.04 S 45 4 W 3826.17 S 3834.80 W 5417.13 S 45 4 W 3902.44 S 3910.03 W 5524.25 S 45 3 W 3973.01 S 3979.20 W 5623.07 S 45 3 W COMPUTATION DATE: 14-AUG-91 PAGE 7 ARCO ALASKA, INC. 1L - 17 KUPARUK RIVER NORTH SLOPE, ALASKA MARKER 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A GCT LAST READING PBTD 7" CASING TD DATE OF SURVEY: 19-APR-1991 KELLY BUSHING ELEVATION: 130.00 FT ENGINEER: M.MCBRIDE INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 357' FNL & 143' FEL, SEC31 TllN RIOE MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 4627 O0 8166 O0 8238 O0 8312 O0 8466 O0 8502 O0 8586 O0 8675 O0 8700 O0 3584 61 5958 14 6006 99 6057 39 6162 53 6187 14 6244 47 6305 21 6322 27 3454.61 5828.14 5876.99 5927.39 6032.53 6057.14 6114.47 6175.21 6192.27 1845 81 S '3694 76 S 3732 46 S 3770 87 S 3B51 O0 S 3869 75 S 3913 50 S 3959 96 S 3973 01 S 1842.88 3704 87 3743 97 378O 18 3859 18 3877 59 392O 88 3966 41 3979 20 COMPUTATION DATE: 14-AUG-91 PAGE ARCO ALASKA, INC. 1L - 17 KUPARUK RIVER NORTH SLOPE, ALASKA DATE OF SURVEY: 19-APR-1991 KELLY BUSHING ELEVATION: 130.00 FT ENGINEER: M.MCBRIDE SURFACE LOCATION = 357' FNL & 143' FEL, SEC31 T11N RIOE MARKER MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTD 7" CASING TD 4627.00 8166.00 8238.00 8312.00 8466.00 8586.00 8675.0C 8700.00 3584 61 5958 14 6006 99 6057 39 6162 53 6244 47 6305 2; 6322 27 3454.61 5828.14 5876.99 5927.39 6032.53 6114.47 6175.2; 6192.27 1845.81 S 3694.76 S 3732.46 S 3770.'87 S 3851.00 S 3913.50 S 3959.96S 3973.01 S 1842.88 3704 87 3741 97 3780 18 3859 18 3920 88 3966 ~ 3979 2O FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 8700.00 6322.27 6192.27 5623.07 5 45 3 W DIRECTIONAL SURVEY COMPANY ARCO ALASKA, INC. FIELD KUPARUK RIVER WEU. 1 L - 17 COUN11:IY U8A RUN ONE DATE LOGGED 19 - APR - 91 DEPTH UNIT FEET REFERKE 74765 WELL: IL-~7 ' (357' FNL, 143' FEL. SEC 31, T11N, R10E. ) HORIZONTAL PROJECTION 1cxx) WELL: (357' FNL, 143' FEL, TllN, R10E, ) VERTICAL PROJECTION -1000 0 0 1000 2000 3000 4000 5000 6000 7000 AOGCC GEOLOGICAL i~ATEfliALS INYENTOi~¥ LiST PEFIMIT ii , d~( , ~ ,,~'~ WELL NAME ~,t~ ~ I L..,--"~"7 cOMPLETION DATE - ~ ~,.~ ,,1'~ CO. CONTACT ~"~ check off or list data ~' i~' i~'?~eiv'~.*list recei~ved date for 407. if not requ'ired Ii'st'as NFl ' 407 l* IOl',~)q'[",dri, ilineh'story v"' s,'U'rveYl I I we. tests' C°r~d intc~als' c?rc analysis ~E. d~ ditch iptcwals , digital data ..... . ........ ~~ ~[+ .... ii i ii ii ii iii i J iiii ii iii L I I I I I II III II III II ' LOG TYPE RUN INTEI::tYALS SCALE NO. {to thc nearest,foot) , (inchll. O0'! II HI I II~ Ii I ,, j ,~ , , ,, , ~ ~ , ..... q, ,, .......... , ,, iq ......................... .J L~IJI I . I I I ]1 III. II IJII I II II 131 i I I Illl I II I Il [llllll III !.!~ i jll . i il i i J . 5 ............ ill Illll I III I I ] I il. ] It I II JllI I I I I II STATE. OF ALASKA 0 AD-,,sKA OIL AND GAS CONSERVATION COMM~,.'XSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing Alter casing Stimulate __ 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 Exploratory Stratigraphic Service 4. Location of well at surface 357' FNL, 143' FEL, Sec. 31, T11N, R10E, UM At top of productive interval 4052' FNL, 3562' FWL, Sec. 32, T11N, R10E, UM At effective depth 4271' FNL, 3778' FWL, Sec. 32, T11N, R10E, UM At total depth 4330' FNL, 3836' FWL, Sec. 32, T11N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical 8700' feet 6322' feet Plugs (measured) 6. Datum elevation (DF or KB) 18o' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 1L-17 feet 9. Permit number/approval number 91-43/91-267 10. APl number 50-029-22151 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 8 5 8 6' true vertical 6 244' feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented +_200 CF 950 Sx Pfrost E & 500 Sx Class G 200 Sx Class G 122' 16" 4613' 9 5/8" 861 0' 7" measured 8342'-8370',8446'-8460' true vertical 5696'-5716',5767'-5777' Tubing (size, grade, and measured depth) 3 1/2" 9.3#, J-55, 8081' Packers and SSSV (type and measured depth) SSSV: Camco TRDP-4A-SSSV, 1791'~ Packer: Baker HB, 8032' 13. Stimulation or cement squeeze summary to water injection. (~l~(~I Convert well Intervals treated (measured) N/A Treatment description including volumes used and final pressure N/A Measured depth 4613' 8610' True vertical depth 122' 3570' 6296' RECEIVED OCT 2 1 1991 Alaska 0il & Gas Cons. C0mm. issi0n Anchorage 14. Reoresentative Daily Average Production or In!ection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 130 260 130 0 - 250 Subsequent to operation - 0 - - 0 - 1800 1000 2200 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector ~( Oil __ Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~ned-~~~~i, ~ Title ~~'~- Form 10-404 Rev 09/12/90 //SUBMIT IN DUPLICATE ARCO Alaska, Inc. Date: September 20, 1991 Transmittal #: 8231 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Open hole items. Please acknowledge receipt and return one signed copy of this transmittal. ~.~,~ L-17 Receipt CDR 9-9-91 5568-10080 CDN 9-9-91 5568-10080 CDN (Replacement)., 4-7-9-91 4 5 6 5-~,7.0,,0,., _ ~.. ~ Acknowledged: ~~Date.~,~ [,. ~ i V ~ L) ~E'P-0-('J 199i Alaska Oil & Gas Cons. Comml~s!o~ DISTRIBUTION: Anchorage D&M Drilling Franzen Vendor Package(Johnston) NSK State of Alaska(+Sepia) !1. Type of Request: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION .,,/,,,.~ APPLICATION FOR SUNDRY APPROVALS , Operation Shutdown_ Re-enter suspended well_ Plugging _ Time extension Stimulate Pull tubing _ Variance _ Perforate _ Other _ 6. Datum elevation (DF or KB) Abandon Suspend Alter casing _ Repair well Change approved program 5. Type of Well: Development Exploratory Stratigraphic Service 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 9951O RKB 130 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1L-17 9. Permit number 91 -43 10. APl number 50-029-22151 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 4. Location of well at surface 357' FNL, 143' FEL, SEC. 31, T11N, R10E, UM At top of productive interval 4052' FNL, 3562' FWL, Sec. 32, T11N, R10E, UM At effective depth 4271' FNL, 3778' FWL, Sec.32, T11N, R10E, UM At total depth 4330' FNL, 3836' FWL, Sec. 32, T11N, R10E, UM 8700' feet Plugs (measured) 6322' feet None 8586' feet Junk (measured) 6 2 4 4' feet None Cemented _+2O0 CF 950 Sx Pfrost E & 500 Sx Class G 200 Sx Class G Top 500' above Kup 180 degree phasing 180 degree phasing Measured depth True vertical depth 115' 115' 4613' 3570' 4613' 3570' 8610' 6296' 5767'-5777' TVD 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Casing Length Size Structural Conductor 8 0' 1 6" Surface 4 61 3' 9 5/8" Intermediate Production 4 61 3' 7" Liner 3 9 9 7' 7" Perforation depth: measured 8342'-8370' 4 SPF 8446'-8460' 4 SPF true vertical 5696'-5716', Tubing (size, grade, and measured depth) 3' 1/2" J-55 set at 8081' Packers and SSSV (type and measured depth) Baker HB @ 8032', Camco TRDP-4A-SSSV @ 1791' 13. Attachments Description summary of proposal _ Detailed operation program _ BOP sketch _ Convert well from oil producer to water injector. (Wellbore schematic attached). 14. Estimated date for commencing operation 15. Status of well classification as: Augur, t, 1~)91 Oil __ Gas __ Suspended _ 16. If ~roposal v~s verbally approved ~" 24 -~ I mame o~ approver (j Date approved Service Water I n!ector 1Si~ned7. I her'e131//'~certif"Y '~at~/~ - /~ ~"O- the foregoing is true and correct~~;;i/~_.to the best of my knowledge. ~~ Title__ ._ - 5 A~Date FOR ~MMISSION USE ~LY Conditions of approval: Notify Commission so representative may witness Plug integrity m BOP Test _ Location clearance ~ Approved Copy Mechanical Integrity Test ~ Subsequent form require 10- - Returned JAppro I,No.,~ App.ro,ved by order of the Commission ORIGINAL SIGNED BY Commissioner Date cj_ L{. CJI Form 10-403 Rev 09/12/90 LONNIE C, SMITH SUBMIT IN~.I~PLICATE RECEIV S P 0 1991 ~1~ I'1il ,~, Gas Cons. Corntll~ss'~o~ W e ! I.'I 'L - 1 7 Spud Date: 4 - 2 - 91 Completion Date: 6 - 2 4 - 91 Maximum Hole Angle: 49.2 Original Rig RKB: 38.0' All depth are RKB MD to top EL 1 4 5,6 ARC._. ALASKA INC. - KUPARUK I: _D APl# 50-029-22151-00 C Sand: NOT PERFED A Sand: OPEN deg. @ 4345' MD of equipment. Well Type: OIL Tree Type: FMC GEN IV Tree Cap Type: Tree Cap Size: Tree Cap O-ring ASN: Last Workover Date: 6 - 2 4 - 91 Jewelry 1 SSSV: CAMCO TRDP-4A-SSSV 2.812" ID @ 1791' 2 PBR: BAKER 3.5" ID @ 8018' 3 PKR: BAKER HB 3.5 ID @ 8032' 4 NOGO: CAMCO 'D' NIPPLE 2.750" ID @ 8048' 5 SHEAR OUT: BAKER @ 8081' 6 TUBING TAIL: @ 8082' Minimum ID:2.750" NOGO Casing and Tubing Size Weight Grade To_~ Bottom Descri_~tion 9.625" 36# J-55 0 4607' CASING 7" 26# J-55 0 8675' CASING 3.5" 9.3# J-55 0 8081' TUBING Gas Lift Depth St 2184' 3458' 4334 5093 5849 6602 7328 7964 Information n# Valve Type Sz, Latch port 1 D/V 1" BK2 2 D/V 1" BK2 3 D/V 1" BK2 4 D/V 1" BK2 5 D/V 1" BK2 6 D/V 1" BK2 7 D/V 1" BK2 8 D/V 1.5" RK S~,, AID# Date Run Perforation Interval 8342-8370 8446-8460 Data SPF Date Phase FT 4 6-21-91 180 28 4 6-21-91 180 14 Zone A A Comments Comments: LAST TAG: 8571' ON 6-25-91 PBTD: 8585' LAST REVISION: 7.15-91 ARCO Alaska, Inc. Date: August 23, 1991 Transmittal #: 8212 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Records Clerk ATO-111 9 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. 1 L- 1 7 Sub-Surface Directional 4- 1 9- 9 1 Survey 1 R-25 Sub-Surface Directional 7- 8 - 9 1 Survey Receipt Acknowledged: / ~' '¢0(~' }i!-JJ:~-~')'l D at e' 'D&M State of Alaska 74795 74792 RECEIVED AUG 2 6 1991 Alaska Oil & Gas Cons. Commission Anchorage TO: THRU: MEMORANluUM Stale of Alaska ALASKA OIL' AND GAS CONSERVATION COMMISSION Lonnie C. smi~-/~~ DATE: June 27, 1991 Commissioner : ~u FILE NO: HH627 - 2 TELEPHONE NO: SUBJECT: RIG/BOPE Inspection AAI KRU DS 1L-17 Permit No. 91-43 Kuparuk Rv Field FROM: Harold R. Hawkins Petroleum Inspector~/~~ ~unda¥ June 23. 1991: I performed a BOPE walk-thru inspection at AAI KRU DS IL-17 on Nordic Rig #1. I found one infraction. The BOPE stack was still not anchored, as I reported taken on my last report 2/13/91. Lance Johnson, the toolpusher, and Don Breeden said the anchors would be installed by next well move. In summary: I found no infractions on AAI KRU DS 1L-17 except the BOPE stack that was not anchored. The AAI company man, Don Breeden and the toolpusher, Lance Johnson, were very cooperative. Attachment. 02-00lA (Rev. 6/89) 20/ll/MEMOi.PM3 OPERATION: Drlg Wkvr AA / Location: Sec :3/ TZZ Orlg contr ~'~.~.D/~ Location (gen'l) ~~ / I N CONPL i ANCE ~ ~es n~ n/a A. DIVERTER STATE OF ALASKA ALASKA OIL AND CAS CONSERVATION COMNI55tON BOPE Walk-Thru Inspection Report UIC / Permit # R/,~'_,~* ~ M~ Rig# Well sign IN COMPLIANCE; yes no n/a 1.() () 2.() () 3.() () 4. ( ) ( ) 5.() () 6.() () 7. ( ) ( ) 1. (X) ( ) 2. (X) ( ) 3. (x') () 4. (%) ( ) s.(yj () 8.(~) () 9. (Z) ( ) lo. (X) ( ) l l. (X.) ( ) 12. (~) ( ) 13. (%) ( ) l~. ~) ( ) is. ()0 ( ) 1. (~,) ( ) 2. (X) ( ) 3. 4. (~') ( ) s. (;() ( ) 6.~x) () 7. (X) ( ) 8.~) () 9. ()~) ( ) lO. (1~) ( ) ('/)' line sz & length (~ line corm & anchored (~) bifurcated & dwn wind (~i 90° targeted turns (/) vlvs: auto & simultaneous ( ~ annular pack-off (~ condition B. BOP STACK ( ) wellhead flg wkg press ( ) stack wkg press ( ) annular preventer ( ) pipe rams ( ) blind rams ( ) stack anchored ( ) chke/kill line sz , ( ) 90° turns targeted (chke & kill In) ( ) HCR vlvs (chke & kill) ( ) manual vlvs (chke &. kill) ( ) connections (flgd, whd,. clmpd) ( ) drl spool ( ) fl ow nipple ( ) flow monitor ( ) control lines fi re protected v" C. CLOSING UNITS · ( ) wkg press ( ) fluid level .. ( ) ( ) oprtg press ( ) press gauges ( ) sufficient vlvs ( ) regulator bypass ( )~ 4-way vlvs (actuators) ( ) blind handle cover ( ) driller control panel ( ,)' remote control panel 12. 13. 1.() 3. ,+. (3<) 6. (¥) 7. ( ) 8. (k) 1. (Z) 2. ~) 3. K) ~..() 5.() 6. Od ?.' U~) 1. () 2. (X) s..oU 6. (X) 7. (~) ( ) ( ) firewall ( ) ( ) nitrogen power source (back-up) ( ) ( ) condition (leaks, hoses, etc) D. MUD SYSTEM ( ) (~) pit level floats installed ( ) ( ) flow rate sensors ( ) ( ) mud gas separator ( ) ( ) degasser ( ) ( ) separator bypass ( ) ( ) gas sensor ( ) (~) chke In conn ( ) ( ) trip tank E. RIG FLOOR ( ) ( ) kelly cocks (upper,lower,IBOP) ( ) ( ) floor vlvs (dart vlv, ball vlv) ( ) ( ) kelly & floor vlv wrenches ( ) O~ driller's console (flow monitor, flow rate indicator, pit level indicators, gauges) ( ) (;'% kill sheet up-to-date ( ) ( ) gas ~etection monitors (H-S & methane) ( ) ( ) hydr rhke panel ( ) ( ) chke manifold F. MISC EQUIPMENT ( ) (~ flare/vent line ( ) ( ) 90° turns targeted (dwn strm choke Ins) ( ) ( ) reserve pit tankage ( ) ( ) personnel protective equip avail ( ) ( ) all drl site suprvs trained 2for procedures ( ) ( ) H S probes ( ) ( ) rig housekeeping RECORDS: ReSulting non-compliance: Non-compliances not corrected & why: . Date corrections will be comploted: Date of last BOP test: / BOP test & results properly entered on daily record? x/:.( Kill sheet ~.rrent~ / ' C.0013 (rev 03/29/91) ARCO Alaska, Inc. Date: May 31, 1991 Transmittal #: 8117 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick 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. 1 L- 1 7 LIS Tape and Listing 4 - 7 - 9 1 4 4 9 0.5 - 87O2.5 Receipt Acknowledged: ~---~-- Date: DISTRIBUTION: Lynn Goettinger State of Alaska RECEIVED Anchorage ARCO Alaska, Inc. Date: April 25, 1991 Transmittal #: 8076 , RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Open hole items. Please acknowledge receipt and return one signed copy of this transmittal. ~'"~ ~ 2 M- 1 6 Dual Induction-SFL 5" Phasor 4- 1 3- 9 1 2 92 8- 6 81 0 "2 M - 1 6 Dual Induction-SFL 2" Phasor 4 - 1 3 - 91 2 9 2 8- 6 81 0 ~ 2 M - 1 6 Litho Density-CNL-GR 2" & 5" 4 - 1 3 - 91 3 0 0 0- 6 7 95 Porosity · 2 M - 1 6 Litho Density-CNL-GR 2" & 5" 4 - 1 3 - 91 3 0 0 0- 6 79 5 Density "2M-1 6 Dipole Sonic Log 2" & 5" 4-1 3-91 2928-6795 . ' Delta Time , ~,!)~J,~''~ ~,'u-- 12 M - 1 6. ', 2 L 7 CoheranceDipole SoniCLogLOg 4-13-91 2928-6795 M-116 Cyberlook 4-13-91 3000-6795 L.- ~ C, - O~ I'-dl.~ Compensated Dual Resistivity 4 - 7 - 9 - 9 1 4 5 6 5 - 8 7 0 0 L..W ~ 1 L- 1 7 Compensated Density Neutron 4 - 7 - 9 - 9 1 4 5 6 5 - 8 70 0 Gamma Ray -- 2 M - 2 3 High Resolution Induction DFL 4 - 3 - 9 1 1 1 4- 3 51 9 2"/100' '"' 2 M - 2 3 High Resolution Induction DFL · 4 - 3 - 9 1 1 1 4 - 3 51 9 5"/100' · .-2 M - 2 3 Spectral Density Dual Spaced 4 - 3 - 9 1 1 4 0 0 - 3 5 2 9 Neutron Raw Data -._ 2 M - 2 3 Spectral Density Dual Spaced 4 - 3 - 9 1 1 4 0 0 - 3 5 85 Neutron High Resolution Pass --- 2 M - 2 3 Spectral Density Dual Spaced 4 - ~] - 9 1 1 4 0 0 - 3 5 85 Neutron Porosity ARCO Alaska, Inc. Date: April 25, 1991 Transmittal #: 8075 RETURN TO: ARCO Alaska, Inc. ATTN: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. signed copy of this transmittal. Receipt Drilling Acknowledge' Please acknowledge receipt and return one Acoustic Cement Bond Log Pulse Echo Cement Evaluation Log Cement Evaluation Log Cement Bond Log Cement Evaluation Log Cement Evaluation Log State of. Alaska 2-1 2-91 6928-7675 2-12-91 1817-7692 4-18-91 5995-7836 4-18-91 5995-7816 4-1 9-91 6795-8554 4-19-91 6795-8534 Dale' NSK TO: THRU: FROM: MEMORANDUM State of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION Lonnie C. Smi~(~ Commissioner DATE: April 12, 1991 FILE NO: LG412 TELEPHONE NO: SUBJECT: Diverter Test Arco KRU 1L.17 Permit No. ~9_1r~43' / Kuparuk Rv Field Drilling Louis R. Grimaldi ~ Petroleum Inspector ~ues~ay~_4~2/91: I witnessed a diverter test on Pool Rig #1 preparing to drill well #lL-17 in CPF #1 Kuparuk River Field. I found the diverter system, rig, and location to be in compliance with the state requirements. There is one area that may have to be addressed in the future. As the pads are being developed and more wells are added, the increased number of flowlines are being centrally located and these are occupying the same area as the diverter line, increasing the possibility of debris exiting the line and cutting a producing well's flow line. I see this as a slight problem now but as more wells are added, the problem compounds itself as is the case on some of the PBU pads. In summary: The Pool Rig %7 is in good shape to drill 1L- 17. Attachment. 02-00lA (Rev. 6/89) 20/ll/MEMO1.PM3 OPERATION: Drlg //~ Wkvr Operator Location: Sec ~p~/ T //~ Drlg contr Location (gen'l) ! N COMPL I ANCE; no n/a 2.~) () () 3.(7Q () () 4. (~ ( ) ( ) 5..~. () () 6.(~? () () 7. ('~) () ( ) 1. ( ) ( ) ( 2.() () ( 3.() () ( 4.() () ( 5.() () ( 6.() () ( 7. ( ) ( ) ( 8.() () ( 9.() () ( ~0.() () ( ~.() () ( ~2.() () ~3.() () ~4.() () ~5.() () 1. ('K) () () ~+.(~ () 5.~) () 6. (~) ( ) 7. () 8. (~ () () lo. hO () UIC Permit # ~/-~ Well sign STATE OF ALASKA ALASKA 0 ! L AND GAS CONSERVAT I ON COMM ISS BOPE Walk-Thru Inspection Report DATE: Representative Representative A. DIVERTER line sz & length line conn& anchored bifurcated & dwn wind 90° targeted turns vlvs: auto & simultaneous annular pack-off condition B. BOP STACK wellhead flg wkg press stack wkg press annular preventer pipe rams blind rams stack anchored chke/kill line sz 90° turns targeted (chke & kill In) HCR vlvs (chke & kill) manual v]vs (chke & kill) connections (flgd, whd, clmpd) drl spool flow nipple flow monitor control lines fire protected C. CLOSING UNITS wkg press fluid level oprtg press press gauges sufficient vlvs regulator bypass 4-way vlvs (actuators) blind handle cover driller control panel remote control panel 11. 12. i N COMPL I ANCE; () 2. 3.(~) /+. ~) 7. ( ) 8. ~') 2.() 3.() 5.() 7. () 8.() 1.() 2.() 3.~) () 4. ?~_j ( ) s.. () 6.() () 7. (~ ( ) firewall nitrogen power source (back-up) condition (leaks, hoses, etc) D. MUD SYSTEM pit level floats installed flow rate sensors mud gas separator degasser separator bypass gas sensor chke In corm trip tank E. RIG FLOOR kelly cocks (upper,lower,IBOP) floor vlvs (dart vlv, ball vlv) kelly & floor vlv wrenches driller's console (flow monitor, flow rate indicator, pit level indicators, gauges) kill sheet up-to-date gas ~etection monitors (H-S & methane) hydr chke panel chke manifold F. MISC EQUIPMENT fl are/vent line 90 ° turns targeted (dwn strm choke lns) reserve pit tankage personnel protective equip avail all drl site suprvs trained 2for procedures H S probes rig housekeeping REMARKS: RECORDS: Date of last BOP inspection: Resulting non-compliance: Non-compliances not corrected & why: Date corrections will be completed: ..... BOP test & results properly entered on daily record? Z~'/~'~ Ki l l sheet current? C.0013 (rev 03/29/91) ALASKA OIL AND GAS CONSERVATION COMMISSION March 20, 1991 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 A. W. McBride Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 re: Kuparuk River Unit 1L-17 ARCO Alaska, Inc. Permit No. 91-43 Sur. Loc. 357'FNL, 143'FEL, Sec. 31, TllN, R10E, UM Btmhole Loc.4279'FNL, 4054'FEL~ Sec. 31, TllN, R10E, UM Dear Mr. McBride: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additiOnal permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The Commission will advise you of those BOPE tests that it wishes to witness. Sincerely, irman David W.~Cha Alaska Oil and Gas Conservation Commission 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 COMMI;::~ION PERMIT TO DRILL 20 AAC 25.005 I la. Type of Work Drill X Redrill -- J lb. Type of Well Exploratory~ Stratigraphic Test _ Development Oil .~. Re-Entry _ Deepen --I Service _ Development Gas ~ Single Zone X Multiple Zone 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc, RKB 130, Pad 88' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25659 ALK 2585 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 357' FNL, 143' FEL, Sec. 31, T11N, R10E, UM Kuparvk River Unit Statewide At top of productive interval (TARGET) 8. Well number Number 4,031' FNL, 3,807' FEL, Sec. 31, T11N, R10E, UM 1L-17 #U630610 At total depth 9. Approximate spud date Amount 4,279' FNL, 4,054' FEL, Sec. 31, T11N, R10E, UM 03-30-91 $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 1L-15 8,610' MD 1,001' @ TD feet 30' at SURFACE feet 2560 6,296' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 300 feet Maximum hole anc~le 47° Maximum surface 2,113 pslg At total depth (TVD) 6,296' 3,110 pslg 18. Casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casing Weight Grade Couplin(~ Length IVD TVD IVD TVD (include stac~e datat 24 16.0" 62.5# H-40 Weld 80' 35' 35' 115' 115' +200 CF i2.25 9.625" 36.0# J-55 BTC 4,613 35' 35' 4,613' 3,570 950 Sx Permafrost E & HF-ERW 500 SX Class G 8.5.. .7" 26.0# J-55 BTCrnod 4r613 35' 35' 4~613' 3,570 200SxClassG 8.5 7" 26.0# J-55 BTC 3997' 4613' 3570 8,610' 6,296 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 Cemenled Measured depth True Vertical depth Structural RECEIVED Intermediate Production L,. r Perforation depth: measured i%J~u~.~.Ojl & Gas Cons. C0.m~iss[0~ true vertical 20. Attachments Filing fee X Property plat __ BOP Sketch ~ Diverter Sketch X Drilling program Drilling fluid program X~ Time vs depth plot ~ Refraction analysis _ Seabed report _ 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /'~,~ ~ Title Area Drillin, Engineer Date ~"/~;;;~/ Commission Use Only Permit Number J AP, number J Approva, date J See cover ,otter ,or ?¢,/- ~-/- ~ 50- 0 ~ c:~ .-. ,~ ~r/,....<- / {") 9, / ? ~ / 9 1 other recluirements Conditions of approval Samples required __Y e s ~ N o Mud Icg r6quired__ Y e s ~ N o Hydrogen sulfide measures__ Yes ~ N o Directional survey required ~.Yes __ N o Required working pressure lor BOPE __2M; z~ 3M' __ SM' __ 10M' __ 15M Other: e~ ' %~ ~~~ ~.1~::~_ by order of Approv __ Commissioner lhe commission ! it in triplicate Structure : Pad 1L Well : 1 Field : Kuparuk River Unit Location : North Slope, Alas o o © o4 400 _ -6 800 - o _ 1200- _ ('-- 1600~ O_ - (~ 2000- r'h _ 2400- 0 - ¢~) 2800- k_ - ~ 3200- >. - (D 3600- 25 - _. 4000- _ 4400- I - V4800- - 5200- ICDreated For: M PRESTRIDGE by jones ate plotted : 17-Jan-91 Plot Reference is 17 Version #5. < - West oordinotes ore in feet reference slot #17. ~ ~ Scale 1 ' 200.00 tc IT' rue Vertical Depths are reference wellhead. / 4000 3600 3200 2800 2400 2000 1600 1200 800 400 0 J I--/~IEASTMAN , I I I I I I I , I I I I I I I I I I I I I - / IZ/Z/JJC H RISTEN S E N Surface Location: 357' FNL, '14-3' FEL / [Sec. 31, TllN, RIOE[ ~ 400 800 TARGET ~ 1200 Tvd=5970 / Trod=8132 / Dep=5189 / 1600 South 3674 ~~ West 3664 ~ 2000 _ 4031' FNL, 3807' FEL/ / Sec. 31, T11 , - - 2800 RKB Elevation: 130' 3200 KOP Tvd=500 Trod=300 Dep=O 3.00 -3600 9.00 - 15.00 Build 5 Deg/lO0 Ft -4000 21.00 TD LocoUon; 27.00 4279' FNL, 4054' FEL 33.00 Sec. ,31, T11N, RIOE 39.00 B/ Permafrost Tvd=1550 Tmd=1656 Dep=449 45.00 EOC Tvd=t697 Tmd=1866 Dep=607 S 44 DEO 55 MIN W 5189' (TO TARGET) T/ Ugnu Snds Tvd=2295 Tmd=2744 Dep=1249 5600- 6000 - 6400 - T/ W Sak Snds Tvd=2885 Tmd=3609 Dep=1881 AVERAGE ANGLE 47 DEG B/ W Sak Snds Tvd=3370 Tmd=4320 Dep=2401 9 5/8" CSG Pt Tvd=3570 Trod=4613 Dep=2616 K-lO Tvd=3800 Trod=4950 Dep=2862 K-5 Tvd=5120 Tmd=6885 Dep=4277 TARGET - T/ Zone C Tvd=5970 Tmd=8132 Dep=5189 T/ Zone A Tvd=6050 Trod=8249 Dep=5275 ~ \ B/ Kup Snds Tvd=6160 Tmd=8410 Dep=5392 ~'~.....~ TD / Logging Pt Tvd=6296 Tmd=8610 Dep=5559 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 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 5600 Scale 1 ' 200.00 Vertical Section on 224.92 azimuth wifh reference 0.00 N, 0.00 E from sial //17 300 ~50 400 _ 450 . 500 550 600 . 650 . 700 . 300 I 250 200 1 50 1 uO' 50 I I , ,I , I I, 0 / / / / / / 4300 500 / / / / I / / / / 2500 / / / 4100 300 ;300 I I / / I / ~ 2;~00 300 / 1700 / / ~00 / / '%1 700 / \ / \ / ! 2100 ~,300 / ~, ~ soo ~ 1700 ~ tgo0 \ \ ',~..LO0 300 250 200 1 50 1 O0 50 _ 300 .350 .400 .450 .500 .550 \ ~~- 600 .650 , ,I 700 0 DRILLING FLUID PROGRAM (1L-17) Spud to 9-5/8" surface casing Density PV YP Viscosity 8.6-10.0 15-35 15-35 50-100' Initial Gel 10 Minute Gel APl Filtrate pH % Solids 5-15 15-40 10-12 9-10 10% _+ Drill out to weight up 8.6-9.3 5-15 5-8 30-40 2-4 4-8 8-10 8.5-9 4-7% Drilling Fluid System: Tandem Brandt Shale Shakers Tandem Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuge, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Weight up to TD 9.5 10-18 8-12 35-50 2-4 4-8 4-5 9.0-9.5 <10-12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ff. This shows that formation breakdown would occur before a surface pressure of 2,113 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3,000 psi. The nearest well to 1L-17 is 1L-15. As designed, the minimum distance between the two wells would be 30' at surface. The wells would diverge from that point. Excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus 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 175 sx of cement followed by arctic pack upon completion of fluid pumping. *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds. · . . · . . , . . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 1L-17 Move in and rig up Pool Rig 7. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (4,613') according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2,000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to logging point (8,610') according to directional plan. Run open hole evaluation logs. Run and cement 7" casing. Pressure test to 3,500 psi. ND BOPE and install temporary production tree. Secure well and release drilling rig. Run cased hole cement evaluation and gyro logs. Move in and rig up Nordic Rig 1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Change over to diesel. Shut in and secure well. Clean location and release rig. Fracture stimulate well. Reperforate and add additional perfs. ~UPARUK RIVER UN,, 20" DIVERTER SCHEMATIC 3 2 DO NOT SHUT IN WELL 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. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16"- 2000 PSI BALL VALVES 4. 20" - 2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20" - 2000 PSI ANNULAR PREVENTER SRE ~6~0 ,, I 7 6 5 4 13 5/8" 5000 ,--SI BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 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 ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. 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. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 6. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3(X)0 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 Bo'FrOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 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" - 3(X)O PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" -5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR SRE 8/22/89 DOYON 14 CHECK LIST FOR NEW WELL PERMITS Company /~/~ ,L--p Lease & ITEM APPROVE DATE YES (1) F.~.e /~ .~//~' 1. Is the permit fee attached .......................................... (2) Loc ,, (2' thru - ' (8) (3) Admin ~/o~ 5~/~/ 9. (9 thru 13) ' 10. (10 and 13) 12. · 13. (4) Casg /~,~'~.~, ~-/$'o9 / (14 thru 22) (23 thru 28) 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Well No. NO 2. Is well to be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4.'Is well located proper distance from other wells .................... __ 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. ~ _ 8. Can permit be approved before fifteen-day wait ...................... Does operator have a bond in force .................................. ~. Is a conservation order needed ....................................... ~ Is administrative approval needed ................................... Is the lease number appropriate ..................................... _~4 ___ Does the well have a unique name and number ......................... Is conductor string provided ........................................ Will surface casing protect~all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate_~_~ Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~~ psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. (29 thr~i 3i)' Aaa: Geology: En~neerin~: Dwa ,art-- LCS rev: 11/30/90 6.011 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. ~ Additional Re~'4rks: INITIAL GEO~ UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE /- ?7o <: 0 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. T° 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. ****************************** COmPAnY NA~E : ARC..., ALASKA, INC, F!EbD N~E : KUPAP!tK ~IVER [,INIT BO~OUG~ : NORTH ST~T~ : ~PI NB~BER : 50-029-22151 REFERENCE NO : 74404 IS Tape Verification L,istin~ ch]umberner AlasKa ComDutin~ Center 2e-~Y-lg91 091~0 D~T~ t ql/05/~a O~!~IN : FLOC R~E~ ~A~E : 74494 CONTINUATION # P~VIOUS ~:~L : CO~E~T : ARCO, 1L-17. K[!PSRUK RIVER OMIT, 50-029-22151 **** TAPE HEADER **** SERVICE MaNE : EDIT DATE : 91/05/29 OPI~!~ : FhIC T~P~ ~A,E : 74494 CONT!NUATIOM # P~EVIOUS TAPE COMmEnT : ARCO, ~L-~7, KUP~ARUK ~IVER UNIT, 50-029-22~51 **** FILE HEADER **** FIL~ HAg~ : EDIT .001 S~gVlCE : FLIC V~RSION : 001A06 D~TE : 91/05/~9 ~X REC SIZE : 1.024 FIL~ TYP~ : LO PAG[: ** SCHLUMBERGER WELL SERVICES ** ** ******************************************************************************* ******************************************************************************* CONPANY NAME: ARCO Ai,.ASKA, INC, WELL:. 1L-i7 FIELD: KUPARUK RIVER !INIT BOROUGH: NORT~ SLOPE ST~T~: ALASKh API NUMBER: 50-029-~215~ bnCaTIOW: 357' F~L & 143' FEL SECTIOn: 31 TOWNSHIP: !IN R~NGE. 10E PERMANENT DATUMS: ~SL ELEVATION: 0 I$ 1'a~e Ver.tf, fcation !,isti~q cblum~-er~erA. 1. aska Co~.putf. no Center 2q-MAY-).gq).. 09:30 MEASURED F~O~ DF 129 ABOVE PERMAN~N~~ DATU~ ET,gVATIOMS K~: 1~9 DF: 1~9 GL: 88 R~N NUMBER: TD DRILLEm: 7-APR THRU 9-APD-91 ~7oo ~700 RTT S!Z~ : 8,5" TYPE FL~TD IN HOLE: DRISPAC DENSITY: 1.0.6 MUD RESISTIVITY~ ].06 FILTRATE RESISTIVITY: 4.38 M~XIMI.]~ TMMP RECORD~3D: 144 LOGGING D~STRICT: LOGGING E~GIMEER: TO0!, NI]~B~RS: 9,6~5" 36 LB M DRILLER DEPTH OF 4565 m 85 PPUDHOE BAY/4210 ~USBAMD/PERRY ~DS014 FiEI, D REMARKS: BIT RUN [~NE: DRILl, ED INTERVAL 4629' TO 8700' GAMMA RAY READING 7~.0' BEHIND BIT RMSISTIV~TY READING 6].0" BEHIND ~IT NEOTRDN READING 138.0' BEgIND DENSITY ~ATRI~: 2.~5 G/CC. FL~6 DENSITY: ~,.0 G/CC_ MA.×I~[TM HOLE ANGLE. 47.: S'TABI[.IZER 0D:8.375"~ HOLE VOLUME 4600' ' . ....... , ..... ~ ~' 6 TO 8700 : 16'70 ET3.. 7" CM~ENT VOLU.~.~,.~= .'09,2 ET3. COMPUTING CENTER ~EM.~RKS: THE DI-ELECTRIC PROCESSING OF ATR AND PSR WAS PERFOrmED AT SCHLUmBErGER ALASKA COMPUTING CENTER, THEREFORE THE CURVES AT~ AND PSR ON THIS TAPE WILL NOT EXACTLY ~ATCH THE CD~ FIELD PPINT, DENSITY/NEUTRON DATA ON THIS LIBRARY TAPE WAS RECOMPUTED AT ....... '~ E X , . 8CNLUMBERGE~ LWD E~:.G!N ERING IN SUGARLAND, T . THEREFORE WII, L NOT MATCH FIELD BLUELIME FIELD LOGS. CON DA..AT HAS ALSO D~PTH-ADJUSTED +3.5' IN ORDER TO B'ETTE~ MATCH THE FIELD CDR LOG, D~TE jOB STARTED: 25-~PR-9I JOB REFERENCE NO: 74524 LDPtAMA: KO}~RI~G PAGE: ****************************************************************************** , * F'Ib~ " EDIT.,OOI IS Tape Verification Llstino ChlUmberqer Alaska ComDtitino Center 2~-~AY-~991 09:30 ARCO ALASKA INC. KUPaR!IK 50-029-22151 DaTA SA~.~P!.,ED EVERY -.5000 FEE-T DATA I~CLUDED - TYP~ USED CDR .LWQ .LWD COMPENSATED DUAl, RESISTIVITY COUPE~SATED DENSITY RAY TABLE TYPE : CONS KUPARUK RIV~R'UNIT API~ 50~029 22~5! FL 357' F~L & 143' FEL SFCT 31 R~NG log, COU~ NORTH SLOP~; ~AT! USA pDAT ~PD FT 0 ADD FT ~9. EWB FT ~9. EOF FT FT TD~ FT 8700° DFT ~R!SP~C DFD G/C3 10.6 DFP~ DFV S DFL F3 ~$ 0~ 3'06 ~T DEaF 85. Company Name Field ~ame Well Name APl Serial Number Field Location Section Township Range Coufit¥ State or Prov~nce Nation Permanent. datum Elevation of Per~, Da Log ~easured From ABOVE PERMANENT D~TiJ~ Elevation of Kelly Bu Elevation of Derr~c~ Elevation of.GrouBd L Total Depth Driller Total Depth . Logaer Drilling Fluid T~O. Drtllln9 Fluid Densit Drilling Flt~td Ph ZONE Drilllne Fluid V~$cos ZONE Drillin~.Fluid Doss ZONE ~esistivit~ o~ ~ud Sa ~ud Sample Temperatur IS TaDe veri. ficati~on bistin~ chlumber~er Alaska Comput!nq Center 29-'~AY-1991. 09:30 PAGE~ 4 T[!~i! VALU DEF! TYPE ~FS OHMS 4.38 Resisttviti. V of mud f MFS? DEGF 54~-~ · ~ud Filtrate Sample T BMT DEGF 1 Bottom Hole Temoeratu TABLE TYPE : ZO~E .DFF! DFPT DeDth Channel Na~e G~ Gamma ~av pFF PhotoeleCtric wactor NCNL Near CNL Detector Counts FCNL Far CNb Detector Counts TNPw Tber~a! Neutron Porosity D~O~ ~ensltV Porosity O,]tput from am APplication Pro~ra~ DP~T Den$itW Porosity R~8~ S$~ RHO Density - LDT RMOB Bulk Den$~tV DRH~ Delta. RHO .... M ~T~ 9GS BHC ATTE~UaTIO~ R...$IST!VITY PSR RGS BRC PHASE SHIFT RESISTIVITY DMR D!KLECTRIC RESISTIVITY FROM RGS DCAL Differential Caliper ROPF RATE OF DRILLinG PENMTRATIOM ** DhTA FORMAT SPECIFICATION PECO~D ** ** SET TYPE - 64EM ** TYPE REPR CODE V~LUE 1 66 0 ~ 66 0 3 73 64 4 66 ~ 5 66 20-MAY-!99! 09:]0 PAGE: mmmmm, mmm,mmmm,~mm, mmmmmmmtmmmmm#mm! 7 65 8 68 0,5 9 65 PT 11 66 16 lP 68 13 66 0 14 65 ~T 15 66 68 16 66 0 66 0 ** SET TYPE - CNaN ** ...........,........,.,.............,,...-.-.-. ......,,....................... NAME SERV NIT SERV C APl aPI A APl FILE NUMB NU . SiZE ~EPR PROCESS ID ORDE~ ~ bOG TYPE CLASS ROD NUMB S~MP EbEM CODE (HEX) ..................... .... D~PT FT 000 0 t 1 I 4 68 . 0000000 O0 000 O0 0 1 1 I 4 68 0000000000 pEP LWD NCNL bWO CPS FCNL LwD CPS TNPH LWD DPO~ LWD PU DPH! LWO PU ~OS2 Lwo G/C3 ~WOB LWD D~HO LWO P8~ 5WO OHM~ DER LWD O~M~ DCAL LW~) O0 000 O0 0 I ! I 4 O0 000 O0 0 I I 1 4 O0 000 O0 0 I )~ 1 4 O0 000 O0 0 ! 1 1 4 O0 000 O0 0 I 1 1 4 O0 000 O0 0 I 1 1 4 O0 000 O0 0 I I 1 4 O0 000 O0 0 1 1, 1 4 O0 000 O0 0 I ! ! 4 O0 000 O0 0 I 1 ! 4 O0 000 O0 0 i ! ! 4 O0 000 O0 0 I I 1 4 O0 000 O0 0 1 1 I 4 O0 000 O0 0 ! ~ I 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 0000000000 68 0000000000 0000000000 68 0000000000 68 0000000000 4 6~ 0000000000 DATA ** OEP? 8702.500 GR,LWD FCNL' ROS~I~WD -999,250 TNPH"LWD LWD -999~50 ~OB,LWO Ps~.LwD -999,250 O~R,LWD DFPT. 8600,000 GR.LWD FCNL,LWD -999,250 TNPH.LWD ROS~,LWD -909,~50 RHOB.LWD PSP,[,WD !,970 DER'LWD -099 250 PEP'bWD -999:250 DPOa,nWO -999,250 DR~F).,hWD -999,~50 DCAL,LWD -999,250 PEF'LWD .-09q250 nPOaibWD -999;250 DRHO,DWD: -999,~60 DCAL.LWD 92,368 PEF,LWD -999,250 DPOR,LWD -090. 250 O~HO. LWD !,979 DCAL,LWD 2999.250 999'250 999:.,50 ROPE.LWD .qg , 'so uc b.bw -99~ ~50 -999] $0 ROPE.LWO -999 ~§0 N~NU,~WD -999~2S0 -999.250 ATRjLWD -999,250 ROPE,LW~ -999:250 -999 ~50 -999 250 -999 250 -999 250 -999 ~50 -999 -999 ~50 -999,=250 -999,250 I'994 40,426 IS Tane verification t, lstino Chlumberqer Alaska Computino Center DEPt. ~500,000 FCNL.t.w~ ~1,100 TNPH,LWD ROS~.LWD 2,461 RHOB,LWD DS~,LWD 2,936 DER,LWD D~PT, 8400,000 G~,LWD FCNL.L~D 2B,47~ TNPH,LWD ~O$~.LWD 2,]84 RHOB,LWD PS~.LWD 5,963 DFP? 8300 000 ~C~L~L~D 20~409 RO$~.LWO 2,355 ~HOB,LWD VS~.LWD 4,353 DFR,LWD v~.~. 82oo.ooo FCNL.LWD ~0.533 TNPN,LWD PSP.hWO 24.143 DER.LWD DEP?. 8100 000 GR,LWD FCNL,L~D 20~240 PS~,LWD 1,975 DER,LND D~DT, 8000,000 GR,LWD FCNL,LW~ ~0,857 TNPH,LWD ~O$~,LND 2*384 PSR,LW~ 2.60I DER,LWD DEPT, 7900,000 GR,LWD FCNL,LWD ~3,6{6 TNP~oLWD PS~]LWD 2,944 DER,hWD DEPT 7800,000 ROS~,LWD ],389 RHOB,LWD PS~.hWD .,,,030 D.!.,~PT 7~700,000 FCNL,LWD ~0,68~ TN~H'LWD ~os~.i~wD 2.:~25 '~S~,LWO 3,41.8 DER'LWD DEPT. 7600,000 GR*Lw9 FCNL,LWD 26,8~] TNPH,LWD RO$~,LWD 2,465 DEPt, 7500,000 GR,LwD FCN[.[,~D ~1,432 TNPg, ~OS~'L~ 2,4o5 Pg~.LwD 3,74! 2g-~AY-1991. 09:30 86.333 PEF,LWD 42 998 DPOR, 2:461 DRHO.LWD ~,904 ~2.457 PEF,LWD 29.427 DPOR, LWD 2,384 D~MO,LWD 6.006 DCAL,LW~ 0 623 PEF.L~_ 0 ~ 559 DPO~, LWD 2,355 DRHO,LWD 4,484 DCAL,LWD 52.o4~ P~ ~w~ 46.239 DPO~:LWD 2.~75 D~.O.bWD 2~ ,546 4~51! DPOR,LWD ! .89~ DCAb. LWD 45: 166 DPOR, 2' 384 DRHO,LWD ~, 529 DCAL, LWD 14~,255 PEF,LWD 3 ,~49 DPOR,LWD 2,366 D~NO, LWD 2'934 DCAL,GWD .. 202 916 PEF, !~WD 30: 965 DP'OR, L, WD 2,~89 DR~O'LWD 2,86~ DCAL, LWD ~.. _. F. h w D 145, .30 BPOe, LWD 25 DRHO,SWD ~'I09, DCaL,LWD. 88,771 PEF,LWD 32, ~60 DPOR, LWD 2,4~5 DRNO,LWD 4.0 ,3 m C A 5. L w D I 1 ~., 276 40,996 DPOR, LWD 2'405 DPHO,LWD 3,55! DCAL,LWD 3.976 lJ .44! 0 3,087 !6.~00 0.003 0.250 3.716 17.884 0.014 0,400 6.~13 16.675 -0.00] 0.984 3,260 18.310 -0 002 3,445 16,~01 0.000 0,4?7 4.,054 17,~36 -0.012 0,~11 3'530 .020 0'36i 3,711 !9,684 0,011 0.260 3,659 !,!83 1o.ooo 0.22~ 3.476 14.874 -0,002 0,:!26 NCNL DPH! ROPE ,LWD ,bWb ,LWO ,LWD NCNL,L~D DPHI,LwD ATR,LWD ROPE,LWD NCNL, DPEI, ROPE. NCNL, DPHI. ROPE, NCNL, DPHI, ATR, ROPE, LWD L wD LwD LWD LWD LwD LwD LWD NCNL,LWD DPHI,LWD ROPE'LWD NCNL,LWD DPH!.LWD ~TR.,LWD ROPE,LND NCNL,LWD DPHI,LWD AT~'LWD ROPE,LWD NCNL'LW~ DPHI,LWD ROPE,hWD NCNS,LWD DPHI LWD ~TR!LWD RGPE L~D NCNL, DPEI, ATR, ROPE' LWD LWD LWD PAGE: 207,272 11.441 2 85~ 51~20. 231,803 16,100 6.111 75,993 235.170 ~7,884 4,829 25,590 2~2,074 ~6,675 98.282 125,484 205,253 18.310 798 208,826 16,~0~ 2~0.024 17,236 2.9!6 165,280 ,802 2,636 1!2,406 207,568 t9,684 3,393 !88,466 11,183 4,065 160,348 205,160 14.874 3,273 1180,527 IS wade verification L~stinq Chltlmberaer A].as~a ComputOne Cemter DEPT. 7400 O00 GR.LWD FCN!-.LWD 22~665 TNPH.LWD RCS2.LWD 2,7]92 RHO~.I~WD ~$~.LWD 3.160 DER.LWD DFPT. 7~00,000 GR.LWD ECNL.LWD ~3.7~0 TNPM.LWD ~CSg.LW~ ~,487 PSg,[,W~ 3,579 DER,LWD D~DT. 7200 000 GR.LWD FCNb. L~D ' ~7~2~2 ROS2.LWD 2,424 RHOB.LWD PS~,LWD 3.983 DEPT. 7100,000 GR.LWD EC~L.LWD ~2,224 TNPM.LWD PSR.I.WD 3,365 DFR,LWD DEPT, 7000,000 GR,LWD , FCNI~ !~%~D ~.9,88~ TMD~,LWQ EOS~.LWD 2,306 RHOB,LWD D$~,LWD t,847 DER.LWD DEPT. 6900,000 GR,LWD FCNt, LWD 22,786 TNPH LWD ~OS~!,WD 2,324 R~Og~ LWD DSR,LWD ~,248 DF~,LWD ..... D~PT. 6800,000 FCNL,LWD 24,027 TNPH,LWD RO$~.[,WD 2,348 RNOB,LWD PSR.LW~ 2,243 D~R,LWD DEPT. 6700,000 ~R,LWD F'CNL.DWD 26,738 TNPH,LWD RO$~,LWD 2'283 RHOB,LWD P$~,LWD 3,636 DER,LWD DMPT 6600,000 FCN[~'LWD ~41~704 TMPH,LW'D ~OS2:":'w . L,,D 2,339 ~HOB,LWD PSP,LWD 2,992 D~R,LWD DEPT, 6500.000 GR,LWD FCNL.LWD 23,374 TNPH2LWD RO$~.LW'D 2,3134 RHOB,LWD DS~,LWD 2,698 DER,LWD DFPT. 6400,000 FCNL,L~D 24,881 TNPH'LWD RO$~.LWD 2,350 R~OB,LWD PS~,LWD 2,565 DER,LWD 29-~A¥-1991 0O:~O 106.227 PEF.LWD 40,840 2.392 DRMO,LWD 2. 940 DCAL, ~07,176 P~F,LWD 35,002 DPOR,LwQ 2,487 D~O,LWD 3.672 DC~L,LWD 96 ~0 PEF,LWD 2 424 DRHO. 4.~40 DCAL,LWD ~83.090 PEF,LWD 37.012 DPO~,LWD 2.402 3,442 DC.[B.LWD 138.496 PEF,LWD 43, ~99 DP~R,LWD 2,306 DRMO,LWD ~,757 DCAL,LWD 89 878 PEF, LWD 39~478 2,324 DR'NO,LWD 2,29~ DC~b,LWD 78,537 ~. E..~ 2,348 DRHO,LWD 2,339 DCaL,bWD: ,~ 3 DR'HO, LWD ~742 DCgL,LWD 9~.409 PEF,LWD 3~'94~ DPOR,Lw=D ' 339 DR. HO,LWD ~,077 DCAL,LWD B0 679 PEF, 3~ 789 2 334 DRHO, LWD 2,734 77,249 PEF, L, WD 3 559 DPOR 350 DR~r3, bW9 ~,7~6 DCA. L.LWD 3.452 15.656 -O.011 0.170 3.!03 871 -~'002 . 0.378 2.952 13.721 -0.002 ~.132 3617 i5~012 0.000 0.245 3.098 20 862 '-0:013 0.245 ~.699 19.775 0.015 0.095 2.,480: 1~'283 0.021 0.36.4 2.585 2J5 0 387 3.!09 I '025 0,030 2.7!8 !9.124 O' 09 2,699 18,!66 o,01~. 0,280 NCNL DPH! DPEX ATR ROPE ,L~D .LWD .LWD .LWD .LWD .LWD ,LTD .LTD NCNL, DPNI, R~PE. NCNL, DPNI. ATR. NC~L. DPR!, ATR, ROPE, NCNL, DPHI, ATR, ROPE° DPHI ATR ROPE NCN5 ROPE DPMI ROPE NCNL OP~{i A TR ROPE NCnb DPHI ROPE LTD bWD LwD LWD hwD LWD LWD LWD LWD LWD LWD [.,WD ,LWD ,LTD 5WD ,LWD ,LWD ,LWD ,LWD ,LWD ..LWD .LTD ,DWD ,LWD ,LTD .LTD ,LWD .LWD '5WD .LWD .LWD 210,200 15.656 2.660 185.391 214.007 9 871 3:887 234,823 227,707 13,72I 4,569 163,640 2n4,588 ~5 012 3~615 107,330 197,849 20,862 1 647 159:191 216.036 19,775 2,373 170,841 22O 513 !8~283 2,547 75,477 8.47 2~,994 203.293 218,829 3,262 165,143 218,:876 19,!24 2'802 237,924 22i,560 18,I66 8,543 Tame Verff~catlon bistlng cblumberqer Alaska Comput~.Q Center [)~:pT. 6100.000 OR.LWD FCNL.bWD 19.676 TNPH.LWD ROS2.SWD 2.331 RHOB.LWD PSR. bWD 2.. ~33 D~.bWD DEPT. 6200 000 GR.LWD FCNL. I.WD ~1 :~55 TNPU.bWD ROS~. bWm 2. ~0~ RNOB. ~S~. I. WD 2, !74 DE~. bWD DFPT. 6100.000 FCNL.L~D ~1.781 TNPM. LWD ~OS~,LwD ~,]01 ~HOB,LWD PSP, LwD 2,344 DER. LWD DFPT. 6000,000 GR.LWD FCNL,LWD 2~.652 TNPH.LwD ~OS~.LWD 2.3!9 RHOB.LWD PSD. LWD ~, 434 DER. LWD DP~PT. 5900. 000 ~R. LWD FCN'L' L~D 21 ' 7 ~OS~. 5WD 2. 229 RHOB. LWD PS~.SWO 2.20t D~R.LWD [-~'p~. 5800 ~oo ~CNI..,.LWD ' 24:~ 1 T~gPM.LWD D~PT. 5700. 000 G~.LWD FCNL.LWD g~'647 TNP~'LWD ROS~. [.,WD 2.272 RHO~.[,WD PSR' LWD 2,531 DER. L~D DEPT. 5600,000 GR. LWD FCNI.. L~D ~ .7~2 TNPH,LWD ROS2,LWD 2.2~3 RHOB,LwD PS~.LWD 4,095 DER.LWD D~P~. 5500 009 GR.LWD FCNL.L~D 20:~gB T~pH'LwD ROS~.LWD 1,983 ~HO.6. LWD PSP.LWD 2..406 DER.LWD DEPT. 5400. 000 GR. LWD FCN!.:. LWD ~2,614 TNPH. LWD ROS~,LWD 2.~45 RHGB LWD PSg' L~4D 2.6~9 t)~R~LWD DPPT. 5300.000 G~.bWD FCN['. bWD ~0. 339 T~PH. LWD POS2 2,2~9 R~OB LWD 29-~AY-~.991 ~'~9: 30 122.~72 44.612 2.331 2.205 73.649 41.734 2,302 2.216 75 928 38:994 2.301 2.383 83 906 37i909 23i9 2.486 80 918 40:!14 2.229 2,249 68,901 35.547 3.148 B2 · 734 ,118 32,272 2.593 8' 20 ~.39 2. 93 4.158 7~.Q73 4 .§5! 2, 6 70.604 36,098 2,245 2,696 8.3,232 42.026 2,239 3.099 PEF.t, wD DRHO.LWD PEF.LWD DPOR.LWD DPHO.bWD DCAL.DWD PEF.Lw9 DDOR.LWD DRHO.LWD DCAb. LWD PEF,LWD DPOR.LWD DRHO,LWD DCAL,~WD PEF LWD DPOR:LwD D~MO.LWD DC~L.bWD PEF.LWD DPOR.LWD D~HO.LWD DCAL.LWD PEF.LWD DPOR.LWD DPHO,LWD DCAL,LWD PEF,LWD DRHO' w DC~L,LWD P~F,SWD DPOR,LWD DC.~b,~WD PEF.bWD DPOR.LWD DRHO.LWD DCAL.LWD PEF.LWD DPO~.SW0 DC~b.LWD 2.875 19.352 -0.013 0.250 2.702 21.111 -0.015 0.105 2.7~9 21.143 -0.014 0.077 2 833 20i046 -0 012 0.040 2 628 2~ ~ 494 0. 227 2.690 .! 908 0.000 22.909 -0'012 0.i54 2 '/64 .009 0. 328 2.559 40. 436 .036 ~;ooo 2.540 24 55'7 -0 008 0 725 2,632 4 8 8 0 2 NCNb. LwD DPUI.LWD aTR.LWD ROPE.LwO ~CNL.LWD DPEI.LWD ATR.LWD ROPE.L~D NCNL.LWD DPHI.LWD ~TR.LWD ROPE.LWD NCNL.LWQ DPHI.SWD ATR.LWD ROPE.LWD NCNL.LWD DPH!.LwD ATR.LWD R~PE.LWD NCNL.SWD DPHI.LND ATR.LWD ROPE.LWD DPHI.LWD ATR.LWD ROPE,DWD ATRibW'D ROPE,L~D NCNL.LWD DPHI*5WD ~TR'bWD NCNL.LWD DPNI.LWD ATR.LWD ROPE.LWD LWD NCr, L, DPNi,LWD ATR,bWD ~NPE.bWD PAGE: 198,201 19,352 2,162 235,679 212,152 21,111 2.295 247.601 207 182 21~143 2 454 210 167 2.589 301.948 208.091 25.494 2 339 2~6 572 21:90~ 3,212 148,939 204.81.3 22,909 2:,717 355.795 20 .341 2~,'606 4~:.302 .'799 0!,677 240,436 2,616 177,~33 205.3!2 24.557 198,684 '21:880 IS Tape verification ListiDq chlumber~er Alaska ComDutl. Dg Cemter D~PT 5200,000 FCN[~LWD 20.656 TNP~.LWD DFPT. 5100.0o0 GR.LWD FCNT.LW~ ~!,269 TNPg. LWD ~QS~.LWD 2.287 RHOB.LWD PS~.LWD 4,506 DFpT. 5000.000 GR.LWD WCNI.,.!.,WD 19.350 TNP!{.LWD RQS~.LWD 2.271 ~HOB.LWD PSP.LWD ].074 DER.LWD D~PT. 4900,000 FCNL.[.WD ~.4~2 ROS2.LWD 2.]~2 RHO~.LWD ~$P.LWD 4,183 D~R.LWD D~PT. 480,) 000 Cg LWD FCNL.LWD ~0:097 TN~H:LWD ROSg. LWD ~ 3~ R!~OB.LWD PS~.LW~ 3:432 D~R.LWD ~OS~.L~D 2.2~1 WHOB,LWD 'PSP*LWD 3.107 D~.LWD DEDT 4600.000 G~,LWD ~C~[~!LWD 13.79! ROS~ LWD 2,309 ~HOS~LW!) PS~,LWD 6,874 DER.[.~WD D~PT. 4500,000 GR.LWD FCNL LWI') 14.24,1 TNPH,LWD PS~,[,WD -999,250 DER,LWD D~PT, ~q90,500 GR,LWD FCNL,LWD 999.250 TNPH.LWD RO~ LWD -999,250 RHOB,LWD PS~:LwD -999,250 D~oLWD END [)F DATA 29-~AY-1991 09:30 73 275 PEW.LWD 72.502 P~F.L~D 41 440 DPOP.LWO 4.558 DC~h. LWD 47[~47 ~.~7~ 3,231 DC~L,LWD 67 665 PEF.LWD 36:397 DPOR,bW~ 2,382 DPNO,LWD 4,O32 DCAL.,SW~ 79 849 P~F.LWD 43:~72 DPOR,LWD 2.322 D~HO.LWD 3.526 DCAL.LWD 89,854 42.0~! DPOR.LWD 2.261 DRMO.SWD 3,185 DCAL.LwD 700 PEF LWD 2'625 * ~]5490. DCAL.LWD 42.743 PEF.LWD 58,949 .099. 5o 999~50 DCAL'SWD -999.250 ~EF,LwWD -999.250 DPOR,5.D :999.,250 DPHO,LWD 999.~50 DCAL,LWD ~.548 2'2.860 -0.018 0.181 2.628 22.017 -0.010 0.~15 2.~1-4 22,952 O.01J 0.327 2.990 16.267 -0.066 0.057 2 828 19:899 O.OO4 0.517 3 006 - 0.0 ! i 0,m05 1 O0 O00 ~0 642 -0 3~9 0 585 ~.999i250 999 ~50 999 ~50 0.0~ ~ -999,25.0 -999,~50 -999 ' ~50 -999,250 DPHI.LWD ATg. LWD ROPE.LWD NCNL,LwD DPNI.LWD AIR.LWD ROPE.LWD NC~L.LWD ~PHT,LWD ATR.LWD RDPE.LWD NCNL.LWD DP~).LWD ATR,LWD NCNL.L~D DDH!,LW~ ATR.LW~ ~OPE.LWD NCN5.LWD DPHI LWD 'ATR[LWD R~PE.LWD ~!C~5.LWD DPHI LWD ATR LWD ROPE DPHI.LWD .~TR,LWD ROPE.LWD NC~L.LWD ATR.LWD ROPE.LWD 200 548 22~860 2.977 215.909 205 288 4.714 198.215 196.805 ~2.952 3 649 135:172 204,359 16.267 3,782 141.139 !98,826 19:899 3i742 293 320 !95.348 23,575 3,353 430,633 !6~.617 .642 26,884 1627.613 171 049 -999 250 -999 -999 250 ~99:9,25 999,25~ -999,~50 IS Tame Verl~lcatlon Listlno chlumberqer Alaska Computtnq Center 29-~AY-199I 09:30 PAGE: 10 **** FIb~ TRAIbE~ **** FILE NAME : EDIT .00! S~R¥ICE ~ WL!C DATE : 91/05/29 ~AX REC SIZ~ : 1024 FTb~ TYPE **** T~PE TRAILE~ **** SERVICE MAME : EDiT D~TF : 91/05/29 COWTIMU~TION # : ~ ~REVIOUS TAP~ CO~EMT ~ aRCO, ~;~-17, KUPARUK ~IVM~ UNIT, 50-0~9-2~5~ **** REEL TEAILE~ **** S~RVICE NAiF : EDIT D~TM t O1/05/29 OPIGIN : FLIC ~EE~, MA~E : 74494 PREVIOUS ~EEb : CO~EWT · ~RCO, ~.I.,-17 KUPARI~K E%¥.~.~,~ UNIT, 50 02g'~2151
