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184-122
Originated: Delivered to:26-Aug-25HalliburtonAlaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun333 West 7th Avenue, Suite 1006900 Arctic Blvd.Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 1L-09 50-029-22025-00 910180917 Kuparuk River Plug Setting Record Field- Final 15-Jul-25 0 12 1R-33 50-029-22529-00 910219407 Kuparuk River Leak Detect Log Field- Final 19-Aug-25 0 13 1R-33 50-029-22529-00 910218799 Kuparuk River Multi Finger Caliper Field & Processed 5-Aug-25 0 14 1Y-06A 50-029-20958-01 910277376 Kuparuk RiverLeak Detect Log with IntelliScopeField & Processed 23-Aug-25 0 15 1Y-06A 50-029-20958-01 910180481 Kuparuk River Leak Detect Log Field- Final 22-Jul-25 0 16 1Y-06A 50-029-20958-01 910180481 Kuparuk River Plug Setting Record Field- Final 22-Jul-25 0 17 2B-02 50-029-21154-00 910151022 Kuparuk River Packer Setting Record Field- Final 3-Jul-25 0 18 2G-17 50-029-23134-00 910157884 Kuparuk River Leak Detect Log Field- Final 14-Aug-25 0 19 2K-23 50-103-20125-00 910180916 Kuparuk River Plug Setting Record Field- Final 12-Jul-25 0 110 2X-12A 50-029-21189-01 910262801 Kuparuk River Plug Setting Record Field- Final 24-Aug-25 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:190-034194-156197-134184-122202-243190-014195-176T40827T40828T40828T40829T40829T40829T40830T40831T40832T408338/27/2025Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.08.27 12:51:45 -08'00'197 134184-122202 24372B-0250-029-21154-00 910151022Kuparuk RiverPackerSetting RecordField- Final3-Jul-2501 TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard drive data drop 2AͲ25 50Ͳ103Ͳ20239Ͳ00 196062_2AͲ25_LDL_15Jul2022 196062_2AͲ25_Patch_12Jun2022 2BͲ01 50Ͳ029Ͳ21147Ͳ00 184115_2BͲ01_PPROF_18Feb2023 2BͲ02A 50Ͳ029Ͳ21154Ͳ00 184122_2BͲ02A_LDL_26Jul2023 2BͲ13 50Ͳ029Ͳ21138Ͳ00 184104_2BͲ13_PPROF_02Jun2023 2DͲ07 50Ͳ029Ͳ21169Ͳ00 184143_2DͲ07_IPROF_10Jun2023 2DͲ08 50Ͳ029Ͳ21158Ͳ00 184127_2DͲ08_PPROF_28May2023 2DͲ13 50Ͳ029Ͳ21070Ͳ00 184012_2DͲ13_PPROF_03Jun2023 2DͲ15 50Ͳ029Ͳ21184Ͳ00 184160_2DͲ15_PPROF_04Jun2023 _2EͲ10 50Ͳ029Ͳ21246Ͳ00 184230_2EͲ10_CBL PostͲBiSN_21Aug2023 184230_2EͲ10_CBL PreͲBiSN_28Jul2023 2FͲ13 50Ͳ029Ͳ21032Ͳ00 183156_2FͲ13_WFL_29Jun2023 2HͲ02 50Ͳ103Ͳ20032Ͳ00 184073_2HͲ02_IPROFͲWFL_13Jun2023 6 of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38362 T38363 T38364 T38365 T38366 T38367 T38368 T38369 T38370 T38371 T387332BͲ02A50Ͳ029Ͳ21154Ͳ00 184122_2BͲ02A_LDL_26Jul2023 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.04.23 11:48:05 -08'00' Originated:Delivered to:3-Dec-20 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #Digital # 1 1Y-27 50-029-22379-00 n/a Kuparuk River Packer Setting Record Field- Final 8-Sep-20 0 1 2 2B-02 50-029-21154-00 906718091 Kuparuk River Packer Setting Record Field- Final 20-Sep-20 0 1 3 2F-05X 50-029-22730-00 906726469 Kuparuk River Packer Setting Record Field- Final 28-Sep-20 0 1 4 2H-09 50-103-20050-00 n/a Kuparuk River Plug Setting Record Field- Final 6-Sep-20 0 1 5 2M-03 50-103-20160-00 906439276 Kuparuk River Packer Setting Record Field- Final 21-Sep-20 0 1 6 2M-24 50-103-20171-00 906726590 Kuparuk River Leak Detect Log Field- Final 23-Sep-20 0 1 7 2M-24 50-103-20171-00 906726590 Kuparuk River Packer Setting Record Field- Final 23-Sep-20 0 1 8 2T-209 50-103-20281-00 906722868 Kuparuk River Water Flow Log Field & Processed 28-Sep-20 0 1 9 3B-03 50-029-21322-00 906711627 Kuparuk River Leak Detect Log Field- Final 15-Sep-20 0 1 10 3B-03 50-029-21322-00 906711627 Kuparuk River Packer Setting Record Field- Final 16-Sep-20 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 12/04/2020 PTD: 1841220 E-Set: 34331 12/07/2020 Abby Bell • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil❑ Gas SPLUG ❑ Other ❑ Abandoned 2 . Suspended El 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development E - Exploratory ❑ GINJ ❑ WINJ ❑ WAG❑ WDSPL❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 10/12/2016 184-122/316-362 ' 3.Address: 7. Date Spudded: 15.API Number: P.O. Box 100360 Anchorage,AK 99510-0360 8/17/1984 50-029-21154-00 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 744'FSL,273'FEL,Sec 19,T11N, R9E, UM 8/22/1984 KRU 2B-02 - Top of Productive Interval: 9. Ref Elevations: KB: 126' 17. Field/Pool(s): 1037'FNL,935'FEL,Sec 30,T11N, R9E, UM GL 92' BF: 92' Kuparuk River Field/Kuparuk Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 1267'FNL, 1010'FEL,Sec 30,T11N, R9E, UM 6851'/6216' ADL 25656• 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 508371 y- 5954890 Zone- 4 6976'/6322' ALK 2582 TPI: x- 507717 y- 5953108 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 507643 y- 5952878 Zone- 4 1891'/1891' 1526'/1526' 5. Directional or Inclination Survey: Yes ❑(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 APR 2 (� , RECEIVED ',,1 APR 6 L,U17 None NOV 2 2 2016 23. CASING, LINER AND CEMENTING RECORD AOGCC WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 35' 110' 35' 110' 24" 119 sx Cold Set II 9-5/8" 36.0# J-55 34' 2727' 34' 2727' 12-1/4" 800 sx Cold Set III&300 sx Cold Set II 7" 26.0# J-55 31' 6934' 31' 6287' 8-1/2" 280 sx Class G&250 sx Cold Set I I 24.Open to production or injection? Yes ❑ No ❑✓ 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" 6616' 6377'/5818' ae.�fiN O o tiJ 00 6600'/6005' -�"rT"'' 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. / Was hydraulic fracturing used during completion? Yes❑ No EIn(/ -'t Per 20 AAC 25.283(i)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 1.1. 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 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 JILL 4/74/1--7" CONTINUED ON PAGE 2 Submit ORIGINIAL only '9I/A4/?-- y� �j RBDMS Uv NOV 2 3 2016 28.CORE DATA Conventional Core(s): Yes ❑ No 0 Sidewall Cores: Yes ❑ No 0 If Yes, list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips, photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No 2 Permafrost-Top Surface Surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 1526' 1526' Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval N/A N/A information, including reports, per 20 AAC 25.071. Formation at total depth: N/A N/A 31. List of Attachments: Daily Operations Summary, Schematics Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey, core analysis, paleontological report,production or well test results, per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Keith Herring @ 263-43- Email: Keith.E.Herring@cop.com Printed Name: G. Elle \\ Title: CTD Team Lead Signature: (Isn Phone: 263-4172 Date: \ Z \ ii tb INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level,and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost.Provide MD and 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 • • 2B-02 DTTMSTAF JOBTYP SUMMARYOPS 10/8/16 DRILLING Move rig from 2M-Pad to 2B pad. Spot modules over 2B-02. RU on well. NU SIDETRACK BOPE and steart state witnessed BOPE test. 10/9/16 DRILLING Finish state witnessed BOPE test. RD testing equipment. Pull BPV. MU and SIDETRACK RIH with milling BHA#1 with 0.9°AKO motor and D331 mill pumping seawater. Tie-in to the K1 for a-3.5 foot correction. Tag TOC at 6593 ft. Mill to midnight depth of 6604 ft with multiple stalls and re-starts. 10/10/16 DRILLING Mill cement pilot hole from 6,604 ft to planned TD of 6,670 ft. PUH for tie-in SIDETRACK wiper to the K1. No correction. RBIH and confirm TD at 6,670 ft. Pump sweeps and POOH. Troubleshoot loose wraps on reel. 10/11/16 DRILLING LD BHA#1. Flush stack. Adjust reel pillow blocks. RU and RIH with HAL SIDETRACK caliper. Log pilot hole. POOH and LD caliper tools. PU/MU BOT Whipstock. RIH and set on depth, TOWS high side at 6,640 ft. POOH and LD WS running tools. PU and RIH with window milling BHA. RIH aqnd take weight at 6607 ft. Can not work past. POOH and LD window milling BHA. 10/12/16 DRILLING PU and RIH with BHA#5 with D331 mill. Tie-in to the K1 for a -6 ft SIDETRACK correction. Dress pilot hole transition area. Dry drift clean. Tag TOWS at 6640 ft. POOH and LD BHA#5. PU and RIH with window milling BHA#6. Clean trip in.K1 tie-in -6.5 ft. Dry tag TOWS at 6640 ft. Mill window per program. Mill rat hole to 6661 ft. Dress window. Dry drift clean. Perform static BHP measurement with 8.8ppg mud, WHP = 0. Well static. 10/13/16 DRILLING POOH with BHA#6. Floats not holding. Flow check, static. LD BHA#6 over SIDETRACK a dead well. MU build BHA#7 with 2.2°AKO motor and RB HCC bit and RIH. Tie in to the K1 for a -3 ft correction. Drill build section to planned section TD of 6800 ft. POOH with build BHA#7 and PUD. PU and PD lateral BHA #8 with 0.8°AKO motor and new HCC bit. RIH, continue drilling the A lateral to midnight depth of 6894 ft. 10/14/16 DRILLING Continue drilling A lateral from 6894 ft to midnight depth of 7876 ft. Wiper SIDETRACK trips at 7210 ft, 7406 ft, and 7763 ft. • . ino n2 �o ob NU II pry °O (0 M m - 2 0 II b 3 m rn co _ U o co—I t0 v V �� co v 0 co 3m ,, LO c_ .6D f� (p mO II a c0 CO 77 d- -�co in 0 O e3 b II = 3 V () _ - H O O m 0 N- V - co 1- 4)W Q ,7)e6 2 N CS) �� Ud Yin Y Nm mM0 Y O Y r- Y U N CC d N_ II N N H -Q C N N �d -o � co c0 mM0 1] m N C R' oCO N N H 77 7 co 2 In_0 (H CO CO H N H -o M co o (U m Ili m m ° Y c �Lo y a) 2 O > EY fid)« fx .° 9-M nn- m c W � tea' rn j E�=/(V np`(, G W co NTo N ma V co 0 m 0ccoo fn0(O N m X 0)r) o� <° nm < 0(0 m(0© c0 b 5� �a �Y _O a �Ym m2 co M w Ev W� E� ��w E.-0 0 E,� N- of O Uco o o E U2 _1mtq U om Qrn p �� E E m �m YYY N E "'a_� 2� c0 N c0 c0 c0 `-- c0 m O (6 c7 ch U0 m ch m m m c'7 U II 3 m a p N o N m o c O No0 NHQ Q y(O N- II V m N 0 Ill l 1' '! A� :.:� -- o cn o ,1 ■ I11 illil 1 ii I )k tc to�.}r �x t s.�.�r.� U .( f..S :y Sr }_ N O m r CO !!! I L 0 fl 0 D N� t 0 oLa DD yr co a� ung �� aT 22 -o_' '� O- �N v 00 W © ICON (COO) V'O 4"© (ON O (q co N c0 \O to In �` _ p n c0 c0 Y Q co r` t 0� o) m (0(0 c13 N CO (O Cy to c0 U (o co 0 0 Operations Summary (with Timelog Depths) 2B-02 Conocaehit!iops Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Time End Time Cur(hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftK6) End Depth(ftKB) 10/8/2016 10/8/2016 3.50 MIRU MOVE RURD P Trucks on location,PJSM,hook up 06:00 09:30 jeeps,secure cellar,perform premove check list,secure pit module, 10/8/2016 10/8/2016 3.50 MIRU MOVE MOB P Spot modules over well 02,release 09:30 13:00 trucks,lower BOPE's,work on post rig move check list. 10/8/2016 10/8/2016 3.00 MIRU MOVE RURD P Start rig up checklist. Hook up steam. 13:00 16:00 berm celler. Hook up PUTZ interconnect.RU flowline. 10/8/2016 10/8/2016 2.00 MIRU MOVE NUND P NU BOPE.Install choke hose and 16:00 18:00 annular hydraulics.Check tree bolts. Grease tree valves and BOP valves. 10/8/2016 10/8/2016 3.50 MIRU WHDBOP RURD P MU test joint.Fluid pack an shell 18:00 21:30 test.Test swabs.Circulate air out of coiled tubing into sump,Test inner reel valve RIG ACCEPT 18:00 10/8/2016 10/9/2016 2.50 MIRU WHDBOP BOPE P Begin testing BOPE to 250/3750 psi. 21:30 00:00 2,500 psi on the annular.State witness by Jeff Jones. 10/9/2016 10/9/2016 6.00 MIRU WHDBOP BOPE P Continue testing BOPE to 250/3750 0.0 0.0 00:00 06:00 psi.2,500 psi on the annular.State witness by Jeff Jones. 10/9/2016 10/9/2016 2.00 MIRU WHDBOP RURD P RD testing equipment,freeze protect 0.0 0.0 06:00 08:00 test pump,store test joint back onto rack in pipe shed.Load out AC unit. 10/9/2016 10/9/2016 1.00 MIRU WHDBOP CTOP P Install checks in Upper Quick,P/T 0.0 0.0 08:00 09:00 tiger tank line and pac-off,send 30 slings out the beaver slide 10/9/2016 10/9/2016 2.50 MIRU WHDBOP MPSP P PJSM,load BPV equipment,PT 0.0 0.0 09:00 11:30 lubricator 2,500 psi,pull BPV, 10/9/2016 10/9/2016 1.50 PROD1 RPEQPT PULD P PJSM,MU milling BHA#1 0.0 62.5 11:30 13:00 10/9/2016 10/9/2016 1.75 PROD1 RPEQPT TRIP P RIH with Milling BHA#1,with a 0.9° 62.5 6,410.0 13:00 14:45 bend motor and D331 mill,pumping SW. 10/9/2016 10/9/2016 0.50 PROD1 RPEQPT DLOG P Logged the K1 correction of minus 3.5 6,410.0 6,593.0 14:45 15:15 ft,PUW 31 k 10/9/2016 10/9/2016 4.50 PROD1 RPEQPT MILL P Tag TOC at 6,593 ft,PUH,bring rate 6,593.0 6,598.0 15:15 19:45 up to 1.5 bpm at 3,050 psi,BHP 2,971,WHP 38, IA 4,OA 0,start milling cement. Held up at 6598 ft. Multiple stalls. Can't get re-started.Vary milling parameters to try and improve milling rate. Added powervis to seawater system to help move material. 10/9/2016 10/9/2016 1.50 PROD1 RPEQPT MILL P Roll toolface to 180°.Contine to mill 6,598.0 6,600.0 19:45 21:15 cement.Multiple stalls. 10/9/2016 10/9/2016 1.25'PROD1 RPEQPT MILL P Roll toolface back to 20°ROHS. 6,600.0 6,603.0 21:15 22:30 Continue milling cement.Multiple stalls and re-starts. 10/9/2016 10/9/2016 1.25 PROD1 RPEQPT MILL P Roll toolface to 180°.Continue milling 6,603.0 6,603.0 22:30 23:45 cement.Multiple stalls and re-starts. 10/9/2016 10/10/2016 0.25 PROD1 RPEQPT MILL P Roll toolface back to 20°ROHS. 6,603.0 6,604.0 23:45 00:00 Continue milling cement.Multiple stalls and re-starts. Page 1/15 Report Printed: 10/31/2016 • 1110 Operations Summary (with Timelog Depths) 2B-02 ConocoPhillips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log rt De Start Time End Time Dur(hr) Phase Op Code Activity Code. Time P-T-X ': Operation (CK8)pth End',Depth(ftKB) 10/10/2016 10/10/2016 1.50 PROD1 RPEQPT MILL P Continue milling cement piStart lot hole. 1.6 6,604.0 6,618.0 00:00 01:30 bpm at 2200 psi,BHP 2,900,WHP 0. Add 0.5%SafeLube to the system to try and improve milling parameters. 10/10/2016 10/10/2016 1.00 PROD1 RPEQPT MILL P Continue milling cement.Multiple 6,618.0 6,619.0 01:30 02:30 stalls and re-starts.Picked up slightly heavy at 38Klbs. 10/10/2016 10/10/2016 0.25 PROD1 RPEQPT WPRT P Wiper trip up to 6565 ft. 6,619.0 6,565.0 02:30 02:45 10/10/2016 10/10/2016 0.25 PROD1 RPEQPT WPRT P RBIH.SOW=13KIbs. 6,565.0 6,619.0 02:45 03:00 10/10/2016 10/10/2016 3.50 PROD1 RPEQPT MILL 'P Continue milling cement pilot hole. 6,619.0 6,627.0 03:00 06:30 10/10/2016 10/10/2016 0.25 PROD1 RPEQPT WPRT P PUH for a tie in PUW 35 k 6,627.0 6,435.0 06:30 06:45 10/10/2016 10/10/2016 0.25 PROD1 RPEQPT DLOG P log the K1 correction of plus 2.0 ft. 6,435.0 6,462.3 06:45 07:00 10/10/2016 10/10/2016 0.25 PROD1 RPEQPT 'WPRT P RBIH,RIW 12 k 6,462.3 6,627.0 07:00 07:15 10/10/2016 10/10/2016 10.00 PROD1 RPEQPT MILL P BOBM 1.3 bpm at 1691 psi, BHP 6,627.0 6,670.0 07:15 17:15 2906,WHP 0, IA 2,OA 0 Multiple stalls and re-starts No tool face changes after 6630 ft, maintaining TF at 20°ROHS.TD pilot hole at 6670 ft. 10/10/2016 10/10/2016 1.50 PROD1 RPEQPT DLOG P PUH and log the K1. No correction. 6,670.0 6,670.0 17:15 18:45 RBIH and confirm TD at 6670 ft. 10/10/2016 10/10/2016 0.75 PROD1 RPEQPT OWFF P PUH.Stop at 6550 ft.Flow check well. 6,670.0 6,550.0 18:45 19:30 Static. 10/10/2016 10/10/2016 1.00 PROD1 RPEQPT CIRC P Pump sweeps,RBIH. 6,550.0 6,670.0 19:30 20:30 10/10/2016 10/10/2016 1.00 PROD1 RPEQPT TRIP P POOH chasing sweeps.Observed 6,670.0 3,000.0 20:30 21:30 loose wraps on the reel. 10/10/2016 10/10/2016 0.50 PROD1 RPEQPT SVRG P Service reel and injector PLC's. 3,000.0 3,000.0 21:30 22:00 Restart electronics. 10/10/2016 10/11/2016 2.00 PROD1 RPEQPT RGRP T Troubleshoot loose wraps on the reel. 3,000.0 3,000.0 22:00 00:00 Suspect ODS pillow block/bearing on reel.Continue troubleshooting. 10/11/2016 10/11/2016 0.50 PROD1 RPEQPT TRIP P POOH with BHA#1,monitoring reel 3,000.0 62.0 00:00 00:30 wraps. 10/11/2016 10/11/2016 0.50 PROD1 RPEQPT OWFF P At surface.Flow check well.Static. 62.0 62.0 00:30 01:00 10/11/2016 10/11/2016 1.25 PROD1 RPEQPT PULD P LD milling BHA#1.Mill was measured 62.0 0.0 01:00 02:15 2.79"no-go. 10/11/2016 10/11/2016 0.75 PROD1 RPEQPT WWWH P MU nozzle.Clean and flush BOP 0.0 0.0 02:15 03:00 stack. 10/11/2016 10/11/2016 0.50 PROD1 RPEQPT SVRG P Service rig,Adjust pillow blocks at the 0.0 0.0 03:00 03:30 reel. 10/11/2016 10/11/2016 1.00 PROD1 RPEQPT PULD P RU HAL.PJSM.PU HAL caliper.Stab 0.0 26.0 03:30 04:30 lubricator. 10/11/2016 10/11/2016 1.75 PROD1 RPEQPT TRIP P RIH with Halliburton caliper.Tie-in to 26.0 6,663.0 04:30 06:15 the K1 for a-1 ft correction. 10/11/2016 10/11/2016 0.75 PROD1 RPEQPT DLOG P Perform two logging passes,pulling 6,663.0 6,200.0 06:15 07:00 up hole at 30 fpm to 6200 ft. 10/11/2016 10/11/2016 1.50 PROD1 RPEQPT TRIP P POOH with HAL caliper. 6,200.0 26.0 07:00 08:30 Page 2/15 Report Printed: 10/31/2016 410 • ex Operations Summary (with Timelog Depths) r 2B-02 ConocoPhilliips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Time i End Time Our(hr) PhaseStart Depth Op Code Activity Code Time P•T-X Operation (ftKEt) End Depth(ftK6) 10/11/2016 10/11/2016 0.25 PROD1 RPEQPT OWFF P Flow check at surface.Static. 26.0 26.0 08:30 08:45 10/11/2016 10/11/2016 0.50 PROD1 RPEQPT PULD P LD HAL Caliper BHA.Caliper data is 26.0 0.0 08:45 09:15 in town for processing. 10/11/2016 10/11/2016 1.00 PROD1 RPEQPT PULD P PJSM. PU and MU whipstock BHA#3 0.0 73.0 09:15 10:15 with open hole anchors. 10/11/2016 10/11/2016 3.00 PROD1 RPEQPT TRIP P RIH with whipstock assembly. Log K1 73.0 6,650.8 10:15 13:15 for a-6 ft correction. No issues RIH. Pilot hole in good condition. 10/11/2016 10/11/2016 0.25 PROD1 RPEQPT WPST P Set WS per Baker rep. 6,650.8 6,650.8 13:15 13:30 10/11/2016 10/11/2016 1.50 PROD1 RPEQPT TRIP P POOH with whipstock running tools. 6,650.8 62.0 13:30 15:00 10/11/2016 10/11/2016 0.25 PROD1 RPEQPT OWFF 'P Flow check at surface.Static. 62.0 62.0 15:00 15:15 10/11/2016 10/11/2016 0.50 PROD1 RPEQPT PULD P PJSM.LD whipstock setting BHA#3. 62.0 0.0 15:15 15:45 10/11/2016 10/11/2016 0.50 PROD1 WHPST PULD P PJSM.PU and MU window milling 0.0 62.0 15:45 16:15 BHA#4 with 0.6°AKO motor and 2.79"string mill and 2.80"window mill. 10/11/2016 10/11/2016 3.00 PROD1 WHPST TRIP P Run in hole with BHA#4.Log K1 fora 62.0 6,607.0 16:15 19:15 -7ft correction.Finish displacing well over to milling fluid.Clean trip in the hole until stacked out at 6611 ft. PUH and try to run back through area with no success.Stack out at 6607 ft. 10/11/2016 10/11/2016 2.00 PROD1 WHPST TRIP T Multiple attempts made to try and 6,607.0 6,607.0 19:15 21:15 work past 6607 ft.Various combinations of toolfaces,pump rates and running speeds were tried with no successs.PUW's between 30KIbs and 35Klbs. PUH and tie-in to the K1 for a+1 ft correction to confirm depth Discuss hole condtions with town. Make 2 more attempts to work past 6607 ft.Made decsion to POOH. 10/11/2016 10/11/2016 1.50 PROD1 WHPST TRIP T POOH with BHA#4.No issues on the 6,607.0 75.0 21:15 22:45 way out of the hole. 10/11/2016 10/11/2016 0.50 PROD1 WHPST OWFF T Flow check at surface.Static. 75.0 75.0 22:45 23:15 10/11/2016 10/12/2016 0.75 PROD1 WHPST PULD T PJSM.LD BHA#4. 75.0 0.0 23:15 00:00 10/12/2016 10/12/2016 0.75 PROD1 RPEQPT PULD T PJSM. MU BHA#5 with 0.9°AKO 0.0 62.0 00:00 00:45 motor and D331 mill with side structure. 10/12/2016 10/12/2016 1.50 PROD1 RPEQPT TRIP T RIH with BHA#5.Tie in to the K1 for a 62.0 6,630.0 00:45 02:15 -6ft correction. RIH at 20fpm and minimum rate.No issues running past 6607 ft.Observed 1 Klb bobble at 6620 ft.Clean run to 6630 ft. 10/12/2016 10/12/2016 1.25 PROD1 RPEQPT TRIP T PUH at 180°TF,pumping 1.5 bpm 6,630.0 6,630.0 02:15 03:30 pulling 1 fpm.Small bobble at 6608 ft. Ream down pumping 1.5 bpm at 5 fpm. Ream up hole at 1 fpm. Page 3/15 Report Printed: 10/31/2016 0 • Operations Summary (with Timelog Depths) , 2B-02 z. GtnaaryPhitltps ; 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 (ftKB) End Depth(ftKB), 10/12/2016 10/12/2016 1.25 PROD1 RPEQPT TRIP T Dry drift pilot hole.Weight bobbles at 6,630.0 6,630.0 03:30 04:45 6621 ft and 6623 ft.Discuss results with town. Made decision to perform 2 more reaming passes. 10/12/2016 10/12/2016 0.25 PROD1 RPEQPT TRIP T Dry drift transition area. Continue to 6,630.0 6,640.0 04:45 05:00 dry drift down and tag TOWS at 6640 ft. 10/12/2016 10/12/2016 1.25 PROD1 RPEQPT TRIP T PUH to 6585.Open EDC.Continue to 6,640.0 62.0 05:00 06:15 POOH with BHA#5. 10/12/2016 10/12/2016 0.50 PROD1 RPEQPT OWFF T Flow check well.Static. 62.0 62.0 06:15 06:45 10/12/2016 10/12/2016 0.75 PROD1 RPEQPT PULD T PJSM.LD BHA#5. 62.0 0.0 06:45 07:30 10/12/2016 10/12/2016 0.50 PROD1 WHPST PULD T PJSM. MU BHA#6 with 0.6°AKO 0.0 74.0 07:30 08:00 motor,string mill,and window mill. 10/12/2016 10/12/2016 2.25 PROD1 WHPST TRIP T RIH with BHA#6.Tie in to the K1 for- 74.0 6,640.0 08:00 10:15 6.5 ft correction.Close EDC.Continue running in the hole and dry tag top of whipstock at 6640 ft. Clean trip through pilot hole. 10/12/2016 10/12/2016 10.00 PROD1 WHPST WPST P Begin milling window per program and 6,640.0 6,649.0 10:15 20:15 Baker rep.Observed sand in samples from BU at 6644 ft. 10/12/2016 10/12/2016 2.00 PROD1 WHPST WPST P Mill rathole to 6661 ft. 6,649.0 6,661.0 20:15 22:15 10/12/2016 10/12/2016 1.25 PROD1 WHPST REAM P PU and dress window in 4 passes. 6,661.0 6,661.0 22:15 23:30 High side,30°ROHS,30°LOHS and 180°.Dry drift window.Clean. 10/12/2016 10/13/2016 0.50 PROD1 WHPST OWFF P PUH to 6590 ft.Close choke,bleed 6,661.0 6,590.0 23:30 00:00 WHP to zero in stages.Well static. Manual MW=8.8 ppg. 10/13/2016 10/13/2016 0.50 PROD1 WHPST MPDA P Open EDC.Bring pump up to drilling 6,590.0 6,590.0 00:00 00:30 rate.Hold 11.8ppgemw at the window. WHP=484 psi.Friction pressure=78 psi/1000ft. 10/13/2016 10/13/2016 1.50 PROD1 WHPST TRIP P POOH with BHA#6.Tag up and 6,590.0 67.0 00:30 02:00 space out. 10/13/2016 10/13/2016 0.50 PROD1 WHPST PULD P PJSM.PUD BHA#6.Floats not 67.0 67.0 02:00 02:30 holding. 10/13/2016 10/13/2016 0.50 PROD1 WHPST OWFF P Flow check well.Static. 67.0 67.0 02:30 03:00 10/13/2016 10/13/2016 1.00 PROD1 WHPST PULD P PJSM,lay down BHA#6 over a dead 67.0 0.0 03:00 04:00 well. 10/13/2016 10/13/2016 1.00 PROD1 DRILL PULD P PJSM.MU build BHA#7 with 2.2° 0.0 72.0 04:00 05:00 AKO motor and RB HCC bit. Surface test. 10/13/2016 10/13/2016 2.00 PROD1 DRILL TRIP P RIH with BHA#7.Tie into the K1 for a 72.0 6,660.0 05:00 07:00 -3 ft correction.Tag bottom of 6660 ft. 10/13/2016 10/13/2016 3.00 PROD1 DRILL DRLG P Drill build section pumping 1.45bpm at 6,660.0 6,717.0 07:00 10:00 4050 psi.BHP=3750 ft.WOB= 1.7Klbs CTW=10.0 Klbs. 10/13/2016 10/13/2016 0.50 PROD1 DRILL WPRT P Wiper trip.Tie in to K1 for a+2.5 ft 6,717.0 6,717.0 10:00 10:30 correction.RBIH,log the RA for no correction. 10/13/2016 10/13/2016 3.00 PROD1 DRILL DRLG P Continue drilling the build section to 6,717.0 6,800.0 10:30 13:30 planned section TD.Pump sweeps. 10/13/2016 10/13/2016 2.25 PROD1 DRILL TRIP P POOH with BHA#7. Tag up and 6,800.0 72.0 13:30 15:45 space out. Page 4/15 Report Printed: 10/31/2016 Operations Summary (with Timelog Depths) A 2B-02 Cor►oc+:Phithps Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(he) Phase Op Code Activity Code Time P-T-X Operation (MO) End,.Depth(ftK8)'. 10/13/2016 10/13/2016 2.00 PROD1 DRILL PULD P PJSM.PUD build BHA#7. 72.0 0.0 15:45 17:45 10/13/2016 10/13/2016 1.25 PROD1 DRILL PULD P PJSM.PU lateral BHA#8 with 0.8° 0.0 72.0 17:45 19:00 AKO motor and new HCC bit.Tag up and rest depth. 10/13/2016 10/13/2016 2.50 PROD1 DRILL TRIP P RIH with BHA#8.Tie in to K1 for a- 72.0 6,800.0 19:00 21:30 5.5ft correction.Clean pass through window and open hole. 10/13/2016 10/14/2016 2.50 PROD1 DRILL DRLG P Continue drilling A lateral.Pump 1.5 6,800.0 6,894.0 21:30 00:00 bpm at 3940 psi.BHP=3750 psi.WOB= 1.5Klbs.CTW 10 Klbs. Mud swap. New mud at the bit at 6820 ft. 10/14/2016 10/14/2016 6.50 PROD1 DRILL DRLG P Continue drilling A lateral. Pumping 6,894.0 7,210.0 00:00 06:30 1.53 bpm at 4126 psi.BHP=3770 psi.WOB=1.5Klbs.CTW 9 Klbs. ROP 30-50 fph. 10/14/2016 10/14/2016 0.25 PROD1 DRILL WPRT P Wiper trip.PUW 36 Klbs 7,210.0 6,660.0 06:30 06:45 10/14/2016 10/14/2016 0.25 PROD1 DRILL WPRT P RBIH.SOW=13KLbs.Clean trip in and 6,660.0 7,210.0 06:45 07:00 out of the hole. 10/14/2016 10/14/2016 4.25 PROD1 DRILL DRLG P BOBD.Puming 1.55 bpm at 4150 psi. 7,210.0 7,406.0 07:00 11:15 BHP 3780 psi.WHP 380 psi.WOB 1.2 -1.9KIbs.CTW=9 Klbs.ROP 30-60 fph. 10/14/2016 10/14/2016 0.25 PROD1 DRILL WPRT P PUH for BHA wiper.PUW 37KIbs. 7,406.0 7,406.0 11:15 11:30 SOW 9Klbs. 10/14/2016 10/14/2016 4.25 PROD1 DRILL DRLG P BOBD.Puming 1.54 bpm at 4130 psi. 7,406.0 7,610.0 11:30 15:45 BHP 3785 psi.WHP 390 psi.WOB 2.1 Klbs.CTW=5 Klbs. ROP 30-60 fph. 10/14/2016 10/14/2016 0.25 PROD1 DRILL WPRT P Wiper trip.PUW=37 Klbs. 7,610.0 6,759.0 15:45 16:00 10/14/2016 10/14/2016 0.25 PROD1 DRILL WPRT P RBIH.SOW 9Klbs 6,759.0 7,610.0 16:00 16:15 10/14/2016 10/14/2016 3.75 PROD1 DRILL DRLG P BOBD.Puming 1.54 bpm at 4130 psi. 7,610.0 7,763.0 16:15 20:00 BHP 3785 psi.WHP 390 psi.WOB 2.1 Klbs.CTW=5 Klbs.ROP 30-60 fph. 10/14/2016 10/14/2016 0.75 PROD1 DRILL WPRT P Geo wiper.PUH.PUW=36 Klbs.Tie in 7,763.0 6,665.0 20:00 20:45 to the RA for a+5.5ft correction. 10/14/2016 10/14/2016 0.50 PROD1 DRILL WPRT P RBIH.SOW 9Klbs. 6,665.0 7,763.0 20:45 21:15 10/14/2016 10/15/2016 2.75 PROD1 DRILL DRLG P BOBD.Pumping 1.50 bpm at 4160 7,763.0 7,876.0 21:15 00:00 psi.BHP 3812 psi.WHP 380 psi. WOB 2.2 Klbs.CTW=4 Klbs.Start cross cut down. 10/15/2016 10/15/2016 4.75 PROD1 DRILL DRLG P Continue drilling ahead. Pumping 7,876.0 8,070.0 00:00 04:45 1.50 bpm at 4400 psi. BHP 3860 psi. WHP 420 psi.WOB 2.2 Klbs.CTW= 4 Klbs.Continue cross cut down. 10/15/2016 10/15/2016 2.25 PROD1 DRILL TRIP T Pump sweeps.POOH.Tag up.Space 8,070.0 72.0 04:45 07:00 out. 10/15/2016 10/15/2016 2.00 PROD1 DRILL PULD T PJSM.PUD BHA#8. 72.0 0.0 07:00 09:00 10/15/2016 10/15/2016 2.00 PROD1 STK PULD T PJSM.PU BOT Anchored billet 0.0 7,286.0 09:00 11:00 assembly. Load PDL.PD Anchored billet BHA#9. Page 5/15 Report Printed: 10/31/2016 0 • Operations Summary (with Timelog Depths) �A0 2B-02 Cortoc+o�Pttittips 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)f 10/15/2016 10/15/2016 3.25 PROD1 STK TRIP T RIH.Log K1 for a-3.5 ft correction. 7,286.0 7,590.0 11:00 14:15 Close EDC.Wt check 6475 ft=29 Klbs. Saw weight bobble at 7231 ft. Position billet assembly on depth. 10/15/2016 10/15/2016 0.25 PROD1 STK WPST T Bring up pump.Set anchors.Top of 7,590.0 7,590.0 14:15 14:30 billet at 7580 ft.Set down 5KIbs to confirm set. 10/15/2016 10/15/2016 2.00 PROD1 STK TRIP T POOH.Tag up and space out. 7,590.0 70.0 14:30 16:30 10/15/2016 10/15/2016 2.50 PROD1 STK PULD T PJSM.PUD anchored billet running 70.0 0.0 16:30 19:00 tools BHA#9. Bled off riser. LEL alarm at shaker went off briefly due to gas cap in riser. Non-essential personnel relocated to the shop as a precaution. Crew change,then continued to PUD. 10/15/2016 10/15/2016 0.50 PROD1 STK BOPE P Function test BOP 0.0 0.0 19:00 19:30 10/15/2016 10/15/2016 1.50 PROD1 STK CTOP P Change out,rehead BOT UQC. 0.0 0.0 19:30 21:00 Houred out. 10/15/2016 10/15/2016 1.00 PROD1 STK PULD T PJSM.PD lateral drilling BHA#10 with 0.0 72.0 21:00 22:00 0.8°AKO motor and RR HCC bit. 10/15/2016 10/16/2016 2.00 PROD1 STK TRIP T Run in hole with BHA#10 72.0 5,079.0 22:00 00:00 10/16/2016 10/16/2016 1.50 PROD1 STK TRIP T Continue RIH.While running in hole, 5,079.0 7,580.0 00:00 01:30 observed decrease in MW out.Sent returns to the tiger tank. Brought mud back inside after 70 bbls. Dry tag billet at 7580 ft. 10/16/2016 10/16/2016 4.25 PROD1 STK KOST T Time mill off of billet.Aluminum 7,580.0 7,625.0 01:30 05:45 observed over the shaker at BU.One stall.Blow down choke.Continue milling. Dry drift billet area.Clean. 10/16/2016 10/16/2016 4.25 PROD1 DRILL DRLG T Continue drilling ahead. Pumping 7,625.0 7,980.0 05:45 10:00 1.50 bpm at 4330 psi. BHP 3840 psi. WOB 0.9 Klbs.CTW=9 Klbs.ROP 70 -110 fph. Start mud swap. New mud at the bit at 7980 ft. 10/16/2016 10/16/2016 0.75 PROD1 DRILL WPRT T Wiper trip.PUW=33KIbs. 7,980.0 7,100.0 10:00 10:45 10/16/2016 10/16/2016 0.75 PROD1 DRILL WPRT T RBIH.SOW=10 Klbs 7,100.0 7,980.0 10:45 11:30 10/16/2016 10/16/2016 1.25 PROD1 DRILL DRLG T Continue drilling ahead. Pumping 7,980.0 8,070.0 11:30 12:45 1.50 bpm at 4245 psi.BHP 3910 psi. WOB 1.3 Klbs.CTW=4-6 Klbs.ROP 70 fph. 10/16/2016 10/16/2016 5.25 PROD1 DRILL DRLG P Continue drilling ahead. Pumping 8,070.0 8,380.0 12:45 18:00 1.50 bpm at 4245 psi.BHP 3910 psi. WOB 1.3 Klbs.CTW=4-6 Klbs.ROP 50-70 fph. 10/16/2016 10/16/2016 0.50 PROD1 DRILL WPRT P Wiper trip.PUW=36 Klbs 8,380.0 7,180.0 18:00 18:30 10/16/2016 10/16/2016 0.50 PROD1 DRILL WPRT P RBIH.SOW=8KIbs 7,180.0 8,380.0 18:30 19:00 Page 6/15 Report Printed: 10/31/2016 Operations Summary (with Timelog Depths) 2B-02 Conoc Phitlhps _ r.trkza 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)' 10/16/2016 10/17/2016 5.00 PROD1 DRILL DRLG P Continue drilling ahead. Pumping 8,380.0 8,659.0 19:00 00:00 1.53 bpm at 4200 psi.BHP 3970 psi. WOB 1.0 Klbs.CTW=-3 to-7 Klbs. ROP 40-140 fph. 10/17/2016 10/17/2016 2.25 PROD1 DRILL DRLG P Continue drilling ahead. Pumping 8,659.0 8,767.0 00:00 02:15 1.53 bpm at 4200 psi.BHP 3970 psi. WOB 1.0 Klbs.CTW=-3 to-7 Klbs. ROP 40-140 fph. 10/17/2016 10/17/2016 1.00 PROD1 DRILL WPRT P Pull up hole for tie-in wiper.PUW=36 8,767.0 6,650.0 02:15 03:15 Klbs. Tie-into the RA for a+5.5 ft correction. 10/17/2016 10/17/2016 1.00 PROD1 DRILL WPRT P RBIH.SOW=9 Klbs. No significant 6,650.0 8,767.0 03:15 04:15 increase in material over the shaker with sweep at surface. 10/17/2016 10/17/2016 10.50 PROD1 DRILL DRLG P BOBD. Pumping 1.52 bpm at 4100 8,767.0 9,170.0 04:15 14:45 psi.BHP 3930 psi.WOB 1.2 Klbs. CTW=0 to-3 Klbs.ROP 30-60 fph. BHA wipers at 8955 ft,9023 ft and 9155 ft. 10/17/2016 10/17/2016 0.25 PROD1 DRILL WPRT P PUH for wiper trip.PUW=37 Klbs 9,170.0 8,180.0 14:45 15:00 10/17/2016 10/17/2016 0.50 PROD1 DRILL WPRT P RBIH.SOW=7 Klbs. 8,180.0 9,170.0 15:00 15:30 10/17/2016 10/17/2016 8.25 PROD1 DRILL DRLG P BOBD. Pumping 1.52 bpm at 4100 9,170.0 9,570.0 15:30 23:45 psi.BHP 3930 psi.WOB 1.2 Klbs. CTW=0 to-3 Klbs.ROP 30-60 fph. 10/17/2016 10/18/2016 0.25 PROD1 DRILL WPRT P PUH for wiper trip.PUW=37 Klbs 9,570.0 9,150.0 23:45 00:00 10/18/2016 10/18/2016 1.00 PROD1 DRILL WPRT P Continue POOH. 9,150.0 6,600.0 00:00 01:00 10/18/2016 10/18/2016 1.00 PROD1 DRILL SIPB P PUH to 6600 ft MD.6005 ft TVDrkb for 6,600.0 6,600.0 01:00 02:00 SBHP test.Shut choke with annular pressure of 3750 psi.WHP 900 psi. No change in pressure. Bleed WHP down to 700 psi.Build back up to 900 psi.Annular pressure=3747 psi. EMW=12.0 ppg. 10/18/2016 10/18/2016 1.50 PROD1 DRILL WPRT P Continue wiper trip to the swab valve. 6,600.0 95.0 02:00 03:30 10/18/2016 10/18/2016 4.00 PROD1 DRILL WPRT P RBIH,to tie in depth. 95.0 6,647.0 03:30 07:30 10/18/2016 10/18/2016 0.25 PROD1 DRILL DLOG P 6647 ft,log RA marker for+18.5 ft 6,647.0 6,679.0 07:30 07:45 correction. 10/18/2016 10/18/2016 2.00 PROD1 DRILL CIRC T PUH and wait on fluids. RIH and log 6,679.0 6,679.0 07:45 09:45 RA marker again for-.5 correction 10/18/2016 10/18/2016 2.00 PROD1 DRILL WPRT P RIH to confirm TD,start stacking wt at 6,679.0 9,500.0 09:45 11:45 9543 ft,RIH 10 FPM. Unable to get past 9543 ft. 10/18/2016 10/18/2016 0.75 PROD1 DRILL CIRC P PUH to 9500 ft.Start circulating 9,500.0 9,540.0 11:45 12:30 beaded liner pill to bottom,5 bbls pumped,slow to min rate.3 BPM. 10/18/2016 10/18/2016 1.00 PROD1 DRILL WPRT P RBIH to confirm TD,25 FPM,stack 9,540.0 9,570.0 12:30 13:30 39K. Confirm TD at 9570 ft. 10/18/2016 10/18/2016 4.00 PROD1 DRILL TRIP P POOH laying in beaded liner running 9,570.0 72.2 13:30 17:30 pill to surface and completion fluid, 12.2 PPG completion fluid,50 FPM, 33K PU WT. Paint flags at 8372 ft and 5472 ft.Continue POOH. Page 7/15 Report Printed: 10/31/2016 i 41, l'i ' Operations Summary (with Timelog Depths) eil 2B-02 Co ocoPhiitips 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) 10/18/2016 10/18/2016 0.50 PROD1 DRILL OWFF P Perform 30 min flow check. 72.2 72.2 17:30 18:00 10/18/2016 10/18/2016 0.50 PROD1 DRILL PULD P PJSM, LD drilling BHA#10 72.2 0.0 18:00 18:30 10/18/2016 10/18/2016 0.50 COMPZ1 CASING PUTB P PJSM, Prep rig floor for MU A lateral 0.0 0.0 18:30 19:00 liner assembly. 10/18/2016 10/18/2016 1.50 COMPZ1 CASING PUTB P MU 36 jts of slotted liner with 10.08' 0.0 1,105.0 19:00 20:30 pup joint. 10/18/2016 10/18/2016 1.00 COMPZ1 CASING PULD P PJSM,MU Coiltrak tools 1,105.0 1,150.0 20:30 21:30 10/18/2016 10/18/2016 2.00 COMPZ1 CASING RUNL P RIH,(open EDC)with A lateral liner 1,150.0 6,576.9 21:30 23:30 assembly with open hole anchored billet 10/18/2016 10/18/2016 0.25 COMPZ1 CASING RUNL P Minus 11.38'correction at the 5,400' 6,579.9 7,530.0 23:30 23:45 EOP flag 10/18/2016 10/19/2016 0.25 COMPZ1 CASING DLOG P 7530',tie into the K1 correction of plus 7,530.0 7,563.0 23:45 00:00 4.5' 10/19/2016 10/19/2016 0.75 COMPZ1 CASING RUNL P Continue RIH with A liner assembly 7,563.0 9,570.0 00:00 00:45 10/19/2016 10/19/2016 0.25 COMPZ1 CASING RUNL P PUW 36 k,RIH,bring pump up to 9,570.0 8,465.4 00:45 01:00 4,650 psi,release liner on bottom 9,570',TOL 8,465.45',remove liner length from counters 10/19/2016 10/19/2016 1.75 COMPZ1 CASING TRIP P POOH,with setting tools 8,465.4 60.7 01:00 02:45 10/19/2016 10/19/2016 0.50 COMPZ1 CASING OWFF P PJSM,checked well for flow 60.7 60.7 02:45 03:15 10/19/2016 10/19/2016 0.50 COMPZ1 CASING PULD P LD liner setting tools 60.7 0.0 03:15 03:45 10/19/2016 10/19/2016 1.00 PROD2 DRILL PULD P PJSM,PU/MU AL1 lateral 0.0 72.2 03:45 04:45 kickoff/drilling BHA#12,changeout pac-off elements. 10/19/2016 10/19/2016 4.00 PROD2 DRILL TRIP P RIH w/AL1 lateral drilling BHA#12 72.2 8,444.0 04:45 08:45 and displace 12.2 completion fluid to 8.9 FloPro(System 2). 10/19/2016 10/19/2016 3.00 PROD2 DRILL KOST P RIH and dry tag TOB at 8466'. PU 8,444.0 8,495.0 08:45 11:45 and start pumping. RBIH and start time milling(Dig trough,2 FPH for 1', 3 FPH 1', 10 FPH for 5',20 FPH for 2'). DHWOB 1.2k 10/19/2016 10/19/2016 1.00 PROD2 DRILL DRLG P Drill ahead to 8510. 8,495.0 8,510.0 11:45 12:45 10/19/2016 10/19/2016 0.25 PROD2 DRILL DRLG P PUH and dry drift from 8440'to 8510'. 8,510.0 8,440.0 12:45 13:00 No issues. 10/19/2016 10/19/2016 3.50 PROD2 DRILL DRLG P Drill ahead to 8562'and perform BHA 8,440.0 8,606.0 13:00 16:30 wiper, PU WT 35K. Pump 5x5 sweep. Continue drilling ahead,rotate TF to 50 degrees ROHS,DHWOB 1.5K, ROP 50. 10/19/2016 10/19/2016 4.00 PROD2 DRILL DRLG P New mud at the bit 8,606',continue 8,606.0 8,698.0 16:30 20:30 drilling ahead 10/19/2016 10/19/2016 0.25 PROD2 DRILL WPRT P BHA wiper up hole to 8,600',PUW 39 8,698.0 8,698.0 20:30 20:45 k 10/19/2016 10/19/2016 0.75 PROD2 DRILL DRLG P BOBD 1.57 bpm at 3,580 psi off 8,698.0 8,715.0 20:45 21:30 bottom,BHP 3938,WHP 556,IA 10, OA 11,CTSW=minus 2.0 k, DHWOB=1.4 k. 10/19/2016 10/19/2016 0.25 PROD2 DRILL WPRT P BHA wiper up hole to 8,628',PUW 38 8,715.0 8,715.0 21:30 21:45 k Page 8/15 Report Printed: 10/31/2016 • 4 Operations Summary (with Timelog Depths) - - ,,-0 if ` 2B-02 hiiiips 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 (h KB) End Depth(5KB). 10/19/2016 10/20/2016 2.25 PROD2 DRILL DRLG P BOBD 1.58 bpm at 3850 psi off 8,715.0 8,811.0 21:45 00:00 bottom,BHP 3965,WHP 564, IA 10, OA 11,CTSW=minus 7.0 k, DHWOB=1.3 k. 10/20/2016 10/20/2016 1.50 PROD2 DRILL DRLG P OBD 1.56 bpm at 4245 psi,BHP 8,811.0 8,860.0 00:00 01:30 3951,WHP 562, IA 10,OA 11, CTSW=minus 7 k,DHWOB=1.3 k 10/20/2016 10/20/2016 0.50 PROD2 DRILL WPRT P Wiper up hole,PUW 37 k 8,860.0 7,660.0 01:30 02:00 10/20/2016 10/20/2016 0.50 PROD2 DRILL WPRT P Wiper back in hole,RIW 7 k 7,660.0 8,860.0 02:00 02:30 10/20/2016 10/20/2016 4.50 PROD2 DRILL DRLG P BOBD 1.57 bpm at 3580 psi off 8,860.0 8,983.0 02:30 07:00 bottom,BHP 3,963,WHP 530,IA 15, OA 13 10/20/2016 10/20/2016 0.50 PROD2 DRILL WPRT P Wiper up hole, PUW 37K 8,983.0 8,000.0 07:00 07:30 10/20/2016 10/20/2016 0.50 PROD2 DRILL WPRT P Wiper back in hole, RIW 7K 8,000.0 8,983.0 07:30 08:00 10/20/2016 10/20/2016 2.00 PROD2 DRILL DRLG P BOBD 1.47 BPM at 4309 psi off 8,983.0 9,030.0 08:00 10:00 bottom,BHP 4338 psi 10/20/2016 10/20/2016 4.00 PROD2 DRILL DRLG P Pump 25BBL beaded pill&25BBL 9,030.0 9,220.0 10:00 14:00 FloPro sweeps and continue drilling. ROP up to 50 fUhr. 10/20/2016 10/20/2016 0.25 PROD2 DRILL WPRT P Wiper up hole,PUW 44K 9,220.0 9,050.0 14:00 14:15 10/20/2016 10/20/2016 0.25 PROD2 DRILL WPRT P Wiper back in hole,RIW 6K 9,050.0 9,220.0 14:15 14:30 10/20/2016 10/20/2016 1.00 PROD2 DRILL DRLG P BOBD 1.43 BPM at 4269 psi off 9,220.0 9,260.0 14:30 15:30 bottom,BHP 4418 psi. Continue with beaded pill sweeps 10/20/2016 10/20/2016 0.50 PROD2 DRILL WPRT P Wiper up hole,PUW 38K 9,260.0 8,200.0 15:30 16:00 10/20/2016 10/20/2016 0.50 PROD2 DRILL WPRT P Wiper back in hole,RIW 6K. 8,200.0 9,260.0 16:00 16:30 10/20/2016 10/20/2016 2.00 PROD2 DRILL TRIP P POOH 9,260,0 72.2 16:30 18:30 10/20/2016 10/20/2016 0.25 PROD2 DRILL PULD P PJSM,PUD/LD drilling BHA#12 72.2 72.2 18:30 18:45 10/20/2016 10/20/2016 2.25 PROD2 DRILL PULD T Check well for flow,checks aren't 72.2 72.2 18:45 21:00 holding,swap to undeploying with closed EDC,function closed EDC, EDC is holding, looks like the upper checks aren't holding,strip up and close double ball valves,bleed pressure from coil,DBV holding,go back to manage pressure on well bore, 10/20/2016 10/20/2016 1.50 PROD2 DRILL PULD P Continue PUD as per standard 72.2 0.0 21:00 22:30 procedure. 10/20/2016 10/21/2016 1.50 PROD2 DRILL PULD P PU/MU/PD Drilling BHA#13,inspect 0.0 78.3 22:30 00:00 pac-off element 10/21/2016 10/21/2016 0.75 PROD2 DRILL PULD P Continue PD BHA#13 78.3 78.3 00:00 00:45 10/21/2016 10/21/2016 1.25 PROD2 DRILL TRIP P RIH with BHA#13 with agitator and 78.3 6,445.0 00:45 02:00 0.8 bend motor and RR bi-center bit. . 10/21/2016 10/21/2016 0.25 PROD2 DRILL DLOG P Log K1 marker correction of minus 6,445.0 6,469.0 02:00 02:15 5.0',PUW 10/21/2016 10/21/2016 1.25 PROD2 DRILL TRIP P Continue RIHTB 6,469.0 9,260.0 02:15 03:30 Page 9/15 Report Printed: 10/31/2016 • • ;.: r 0" . ,). Operations Summary (with Timelog Depths) tit .,. 2B-02 ConocoPhiiiips .fxska 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 (ftKB) End Depth(ftKB) 10/21/2016 10/21/2016 2.00 PROD2 DRILL DRLG P OBD 1.4 bpm at 4400 psi, BHP 4008, 9,260.0 9,354.0 03:30 05:30 WHP 463, IA 12,OA 9 10/21/2016 10/21/2016 0.25 PROD2 DRILL WPRT P 'Wiper up hole,PUW 39K 9,354.0 9,254.0 05:30 05:45 10/21/2016 10/21/2016 0.25 PROD2 DRILL WPRT P Wiper back in hole,RIW 5K 9,254.0 9,354.0 05:45 06:00 10/21/2016 10/21/2016 2.00 PROD2 DRILL DRLG P BOBD 1.4 bpm at 4400 psi, BHP 3985 9,354.0 9,418.0 06:00 08:00 10/21/2016 10/21/2016 0.25 PROD2 DRILL WPRT P Wiper up hole, PUW 40K 9,454.0 9,254.0 08:00 08:15 10/21/2016 10/21/2016 0.25 PROD2 DRILL WPRT P Wiper back in hole,RIW 4K 9,254.0 9,454.0 08:15 08:30 10/21/2016 10/21/2016 2.50 PROD2 DRILL DRLG P BOBD 1.4 bpm at 4400 psi,BHP 3977 9,454.0 9,521.0 08:30 11:00 10/21/2016 10/21/2016 0.25 PROD2 DRILL WPRT P Wiper up hole,PUW 45K,pump 5 bbl 9,521.0 9,302.0 11:00 11:15 to-vis sweep 10/21/2016 10/21/2016 0.25 PROD2 DRILL WPRT P Wiper back in hole,RIW 2K,pump 5 9,302.0 9,521.0 11:15 11:30 bbl hi-vis sweep 10/21/2016 10/21/2016 0.50 PROD2 DRILL WPRT P BOBD 1.44 bpm at 4400 psi,BHP 9,521.0 9,530.0 11:30 12:00 3977,DWOB 1.5K,ROP 20 ft/hr, pump 5x5 sweep 10/21/2016 10/21/2016 0.50 PROD2 DRILL WPRT P Wiper up hole(1000'),PUW 43K. 9,530.0 8,530.0 12:00 12:30 Pump 10bb1 hi-vis sweep 10/21/2016 10/21/2016 0.50 PROD2 DRILL WPRT P Wiper back in hole,RIW 5K. Pump 8,530.0 9,530.0 12:30 13:00 10bbl lo-vis sweep 10/21/2016 10/21/2016 2.00 PROD2 DRILL DRLG P BOBD 1.4 bpm at 4400 psi,BHP 4000 9,530.0 9,622.0 13:00 15:00 psi, DHWOB 1K 10/21/2016 10/21/2016 0.25 PROD2 DRILL WPRT P Wiper up hole,PUW 43K 9,622.0 9,522.0 15:00 15:15 10/21/2016 10/21/2016 0.25 PROD2 DRILL WPRT P Wiper back in hole,RIW 4K 9,522.0 9,622.0 15:15 15:30 10/21/2016 10/21/2016 2.00 PROD2 DRILL DRLG P BOBD, 1.4 bpm,ROP 33ft/hr, 9,622.0 9,697.0 15:30 17:30 DHWOB.9K 10/21/2016 10/21/2016 3.25 PROD2 DRILL DRLG P OBD 1.4 bpm at 4549 psi, BHP 4038, 9,697.0 9,778.0 17:30 20:45 WHP 450, IA 7,OA 11 10/21/2016 10/21/2016 1.25 PROD2 DRILL WPRT P Wiper up hole to 6,650',PUW 45 k. 9,778.0 6,650.0 20:45 22:00 10/21/2016 10/21/2016 0.25 PROD2 DRILL DLOG P Log the RA correction of plus 7.0', 6,650.0 6,676.0 22:00 22:15 10/21/2016 10/21/2016 1.25 PROD2 DRILL WPRT P Wiper back in hole,RIW 10 k 6,676.0 9,778.0 22:15 23:30 10/21/2016 10/22/2016 0.50 PROD2 DRILL DRLG P BOBD 1.4 bpm at 4500 psi,BHP 9,778.0 9,792.0 23:30 00:00 4050,WHP 426, IA 8,OA 12 10/22/2016 10/22/2016 4.50 PROD2 DRILL DRLG P OBD 1.4 bpm at 4,700 psi,BHP 4040, 9,792.0 9,905.0 00:00 04:30 WHP 437,IA 8,OA 11 10/22/2016 10/22/2016 0.25 PROD2 DRILL DRLG P Start pumping bead pills. 9,905.0 9,905.0 04:30 04:45 10/22/2016 10/22/2016 5.00 PROD2 DRILL DRLG P Continue drilling ahead, 1.37 bpm at 9,905.0 9,976.0 04:45 09:45 4617 psi, BHP 4054,WHP 416,IA 14, OA 12 10/22/2016 10/22/2016 0.75 PROD2 DRILL WPRT P Wiper up hole,PUW 45K 9,976.0 9,776.0 09:45 10:30 10/22/2016 10/22/2016 0.75 PROD2 DRILL WPRT P Wiper back in hole,RIH 6.5K 9,776.0 9,976.0 10:30 11:15 10/22/2016 10/22/2016 5.00 PROD2 DRILL DRLG P BOBD 1.35 bpm at 4750 psi,BHP 9,976.0 10,083.0 11:15 16:15 4054,WHP 390, IA 7,OA 11,ROP 20 fUhr,DHWOB 1K Page 10/15 Report Printed: 10/31/2016 • 0 x0 ,.. Operations Summary (with Timelog Depths) 2B-02 Conoo3Phiiiips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Start Time End Time Our(hrM ) Phase. Op Code ACtivity Code Time P-T-X Operation S)Depth (ftK6) End Depth(ftKF3)' 10/22/2016 10/22/2016 0.25 PROD2 DRILL WPRT P 200'wiper up hole,PUW 45 k 10,083.0 9,883.0 16:15 16:30 10/22/2016 10/22/2016 0.25 PROD2 DRILL WPRT P Wiper back in hole,RIW-2.0k 9,883.0 10,083.0 16:30 16:45 10/22/2016 10/22/2016 3.25 PROD2 DRILL DRLG P BOBD 1.35 k at 4,100'psi,BHP 4057, 10,083.0 10,150.0 16:45 20:00 WHP 352, IA 6,OA 11 10/22/2016 10/22/2016 0.50 PROD2 DRILL WPRT P Geo wiper up hole 10,133',PUW 42 k 10,150.0 10,150.0 20:00 20:30 10/22/2016 10/23/2016 3.50 PROD2 DRILL DRLG P BOBD 1.37 bpm at 4,460 psi,WHP 10,150.0 10,203.0 20:30 00:00 4,046, IA 6,OA 11,blow pop off on pump,swap out pop off,and restart drilling. 10/23/2016 10/23/2016 2.00 PROD2 DRILL DRLG P OBD 1.37 bpm at 4642 psi,BHP 10,203.0 10,227.0 00:00 02:00 4058,WHP 357,IA 7,OA 11 10/23/2016 10/23/2016 4.00 PROD2 DRILL WPRT P PUH,PUW 36 k,TD AL1 lateral, 10,227.0 6,694.0 02:00 06:00 pump 10x10 bbls sweep,clean hole 9,850'-9,530'.Continue POOH. 10/23/2016 10/23/2016 0.25 PROD2 DRILL WPRT P Perform choke calibration at 6,694'. 6,694.0 6,694.0 06:00 06:15 Full rate 12 ECD,Ann Pres 3756 psi, WH 307 psi,DI 8.97 ppg,DO 8.87 ppg,Pump Pres 4320 psi,choke 300, EDC 12.18 10/23/2016 10/23/2016 1.00 PROD2 DRILL WPRT P Continue PUH for swab wiper 6,694.0 78.0 06:15 07:15 10/23/2016 10/23/2016 1.00 PROD2 DRILL WPRT P RBIH,to tie in depth. 78.0 6,400.0 07:15 08:15 10/23/2016 10/23/2016 0.25 PROD2 DRILL DLOG P Log K1 marker for+22 ft correction. 6,400.0 6,469.0 08:15 08:30 10/23/2016 10/23/2016 0.50 PROD2 DRILL DLOG P RIH and perform static BHP at 6,594'. 6,469.0 6,678.0 08:30 09:00 RIH and log RA marker for-.5 correction. 10/23/2016 10/23/2016 2.00 PROD2 DRILL WPRT P Continue RIH. Stack down XX'. 6,678.0 10,230.0 09:00 11:00 Confirm TD at 10,230'. 10/23/2016 10/23/2016 3.50 PROD2 DRILL DISP P POOH laying in beaded liner pill and 10,230.0 78.0 11:00 14:30 12.2 ppf completion fluid. Paint flags at 8,778 and 5,178. Continue POOH 10/23/2016 10/23/2016 0.50 PROD2 DRILL OWFF P Conduct 30 min flow check 78.0 78.0 14:30 15:00 10/23/2016 10/23/2016 0.50 PROD2 DRILL PULD P PJSM, Lay down BHA#13 78.0 0.0 15:00 15:30 10/23/2016 10/23/2016 3.00 PROD2 WHDBOP RURD P Clean and clear rig floor in preparation 0.0 0.0 15:30 18:30 for BOP test. 10/23/2016 10/23/2016 1.50 PROD2 WHDBOP RURD P MU Nozzle,flush stack and surface 0.0 0.0 18:30 20:00 lines while displacing coil to fresh water,Valve crew on location greasing tree valves. 10/23/2016 10/24/2016 4.00 PROD2 WHDBOP BOPE P Perform bi-weekly BOP test,witness 0.0 0.0 20:00 00:00 waived by state tester Brian Bixby, Test pressure 3,750 psi high/250 psi low/2,500 psi annular. 10/24/2016 10/24/2016 4.00 PROD2 WHDBOP BOPE P Continue bi-weekly BOP test,witness 0.0 0.0 00:00 04:00 waived by state tester Brian Bixby, Test pressure 3,750 psi high/250 psi low/2,500 psi annular. Test complete,no failures. 10/24/2016 10/24/2016 4.50 PROD2 WHDBOP BOPE P Calibrate In and Out MicroMotion. 0.0 0.0 04:00 08:30 Test inner real valve,replace packoffs. Displace coil back to completion fluid. Page 11/15 Report Printed: 10/31/2016 0 0 0~` ,, Operations Summary (with Timelog Depths) 2B-02 ConocoPhitios 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 (ftKE) End Depth(RKB) 10/24/2016 10/24/2016 0.50 PROD2 CASING PUTB P PJSM, Prep rig floor for MU A lateral 0.0 0.0 08:30 09:00 liner assembly. 10/24/2016 10/24/2016 1.50 PROD2 CASING PUTB P MU 34 jts of slotted liner with 8.09'pup 0.0 0.0 09:00 10:30 joint.Perform BOP drill 10/24/2016 10/24/2016 1.50 PROD2 CASING PUTB P PJSM,MU Coiltrak tools(BHA#15), 0.0 1,102.0 10:30 12:00 test tools and QTC 10/24/2016 10/24/2016 1.50 PROD2 CASING RUNL P RIH,with lower AL1 lateral liner 1,102.0 6,202.0 12:00 13:30 assembly to EOP flag 10/24/2016 10/24/2016 0.25 PROD2 CASING RUNL P Minus 11.5'correction at the EOP flag 6,202.0 6,202.0 13:30 13:45 10/24/2016 10/24/2016 0.50 PROD2 CASING DLOG P WT CK 36K at 7470. Shut down 6,202.0 7,492.0 13:45 14:15 pumps. Log the K1 marker for a correction of+5.5'. 10/24/2016 10/24/2016 1.00 PROD2 CASING RUNL P RIH to TD at 10,230', PUW 40K. 7,492.0 10,230.0 14:15 15:15 Bring pump online to 4,650 psi, 1.4 bpm, IA 12,OA 4,WH O. Release liner on bottom 10,230',TOL at 9,172', remove liner length from counters. 10/24/2016 10/24/2016 3.00 PROD2 CASING TRIP P POOH,with setting tools and paint 10,230.0 61.0 15:15 18:15 EOP flags 10/24/2016 10/24/2016 0.50 PROD2 CASING OWFF P At surface,perform flow test 61.0 61.0 18:15 18:45 10/24/2016 10/24/2016 1.75 PROD2 CASING PUTB P PU/MU 11 joints slotted liner,OH 61.0 0.0 18:45 20:30 anchored billet,and liner running assembly BHA#15. Perform BOP drill 10/24/2016 10/24/2016 1.50 PROD2 CASING PUTB P PJSM,MU Coiltrak tools(BHA#15) 0.0 0.0 20:30 22:00 10/24/2016 10/24/2016 1.00 PROD2 CASING RUNL P RIH,with upper AL1 lateral liner 0.0 6,514.0 22:00 23:00 assembly to EOP flag at 6144' 10/24/2016 10/24/2016 0.50 PROD2 CASING RUNL P Minus 10'correction at the EOP flag. 6,514.0 6,514.0 23:00 23:30 WT CK=32K at 6,514'. Pumps offline,EDC closed. 10/24/2016 10/25/2016 0.50 PROD2 CASING RUNL P RIH to K1 marker 6,514.0 6,790.0 23:30 00:00 10/25/2016 10/25/2016 0.50 PROD2 CASING DLOG P Log the K1 marker fora correction of 6,790.0 6,824.0 00:00 00:30 plus 4.5' 10/25/2016 10/25/2016 0.50 PROD2 CASING TRIP P Continue RIH to bottom 6,824.0 9,168.0' 00:30 01:00 10/25/2016 10/25/2016 0.25 PROD2 CASING TRIP P Tag bottom, PUW 36 k,bring pump up 9,168.0 9,168.0 01:00 01:15 to shear at 4,300 psi 10/25/2016 10/25/2016 0.60 PROD2 CASING TRIP P POOH,pumping with closed EDC 9,168.0 6,585.0 01:15 01:51 10/25/2016 10/25/2016 1.25 PROD2 CASING OWFF P trace of crude to surface,transfer 6,585.0 6,585.0 01:51 03:06 additional 12.2 ppg completion fluid to active pit,circulate bottoms up,check well for flow,well is dead. 10/25/2016 10/25/2016 1.50 PROD2 CASING PULD P Continue POOH,pumping pipe 6,585.0 60.8 03:06 04:36 displacement 10/25/2016 10/25/2016 0.50 PROD2 CASING OWFF P OOH,check well for flow,PJSM 60.8 60.8 04:36 05:06 10/25/2016 10/25/2016 1.25 PROD2 CASING PULD P LD AL1 liner setting tools on a dead 60.8 0.0 05:06 06:21 well. 10/25/2016 10/25/2016 0.50 PROD3 DRILL SFTY P Crew change,valve check list, PJSM 0.0 0.0 06:21 06:51 10/25/2016 10/25/2016 1.25 PROD3 DRILL PULD P PJSM, make up BHA#16 on a dead 0.0 78.4 06:51 08:06 well. Page 12/15 Report Printed: 10/31/2016 0 0 Operations Summary (with Timelog Depths) f 2B-02 iiiiips . Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time.: and Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/25/2016 10/25/2016 1.50 PROD3 DRILL TRIP P RIH wtih AL1-01 drilling BHA#16, 78.4 6,440.0 08:06 09:36 agitator and RR bi-center bit. 10/25/2016 10/25/2016 0.25 PROD3 DRILL DLOG P Log K1 marker correction of minus 6,440.0 6,472.0 09:36 09:51 7.0'. 10/25/2016 10/25/2016 1.00 PROD3 DRILL TRIP P Continue RIH to billet 6,472.0 8,810.0 09:51 10:51 10/25/2016 10/25/2016 1.00 PROD3 DRILL DISP P Tag TOB,8,810',PUH and displace 8,810.0 8,810.0 10:51 11:51 well to drilling fluid. 10/25/2016 10/25/2016 0.50 PROD3 DRILL TRIP P PUH 8,810.0 6,650.0 11:51 12:21 10/25/2016 10/25/2016 0.50 PROD3 DRILL DLOG P Log the RA correction of plus 1.5' 6,650.0 6,684.0 12:21 12:51 10/25/2016 10/25/2016 0.60 PROD3 DRILL TRIP P RBIH to confirm TOB 6,684.0 8,810.0 12:51 13:27 10/25/2016 10/25/2016 1.00 PROD3 DRILL KOST P Tag top of billet,PUH,bring pump up 8,810.0 8,853.0 13:27 14:27 to 1.3 bpm at 4450 psi,trough above billet,kickoff of billet as per procedure. 10/25/2016 10/25/2016 0.25 PROD3 DRILL WPRT P PUH, PUW 36 k,drift billet area,clean 8,853.0 8,791.0 14:27 14:42 RBIHTB 10/25/2016 10/25/2016 2.15 PROD3 DRILL DRLG P BOBD, 1.3 bpm at 4460 psi FS,BHP 8,791.0 8,870.0 14:42 16:51 3952,WHP 212, IA 10,OA 7 10/25/2016 10/25/2016 4.35 PROD3 DRILL DRLG P OBD, 1.3 bpm at 4521 psi,BHP 3943, 8,870.0 9,080.0 16:51 21:12 WHP 217,IA 10,OA 7,PUW at 9,080 ft 38k. Note:New mud out bit at 9,037 ft. 10/25/2016 10/26/2016 2.80 PROD3 DRILL DRLG P BOBD 1.42 bpm at 4,402 psi FS, BHP 9,080.0 9,200.0 21:12 00:00 4,003 psi,WHP 542, IA 10,OA 7 10/26/2016 10/26/2016 0.35 PROD3 DRILL DRLG P OBD 1.42 bpm at 4,450 psi FS,BHP 9,200.0 9,210.0 00:00 00:21 3,975 psi,WHP 556, IA 11,OA 8. pump 5x5 sweep 10/26/2016 10/26/2016 0.50 PROD3 DRILL WPRT P 9,210 ft. Wiper up hole 1,000 ft,PUW 9,210.0 8,210.0 00:21 00:51 38k,pull 6k over at 9,071 ft and 8,659 ft. 10/26/2016 10/26/2016 0.55 PROD3 DRILL WPRT P 8,210 ft Wiper back in hole,RIW 9.0k 8,210.0 9,210.0 00:51 01:24 10/26/2016 10/26/2016 4.50 PROD3 DRILL DRLG P BOBD 1.40 bpm at 4,429 psi, BHP 9,210.0 9,405.0 01:24 05:54 4,008,WHP 561,IA 11,OA 8 10/26/2016 10/26/2016 1.00 PROD3 DRILL WPRT P PU off bottom for a geo wiper,PUW 9,405.0 6,650.0 05:54 06:54 36 k,discuss plan forward,continue pulling up hole for a tie in. 10/26/2016 10/26/2016 0.25 PROD3 DRILL DLOG P Log the RA marker correction of plus 6,650.0 6,650.0 06:54 07:09 5.0' 10/26/2016 10/26/2016 0.75 PROD3 DRILL WPRT P Wiper back in hole,RIW 8 k 6,650.0 9,405.0 07:09 07:54 10/26/2016 10/26/2016 3.00 PROD3 DRILL DRLG P BOBD 1.4 bpm at 4,330 psi, BHP 9,405.0 9,446.0 07:54 10:54 4024,WHP 464,IA 10,OA 9 10/26/2016 10/26/2016 0.25 PROD3 DRILL WPRT P Short 100'wiper up hole 9,446.0 9,446.0 10:54 11:09 10/26/2016 10/26/2016 10.00 PROD3 DRILL DRLG P BOBD 1.4 bpm at 3600 psi FS,BHP 9,446.0 9,750.0 11:09 21:09 4075,WHP 618, IA 10,OA 11,couple of PU's for restarts,PUW(s)44k& 46k,pump 10x10 sweeps. 10/26/2016 10/27/2016 2.85 PROD3 DRILL WPRT P 9,750 ft. Called TD.Wiper to swab. 9,750.0 675.0 21:09 00:00 PUW 46k,Jog at EOB,Jog at 600 ft from surface. Page 13/15 Report Printed: 10/31/2016 • • :0.:,,,:,,,-„,,,, Operations Summary (with Timelog Depths) _ 4_ C: ' 2B-02 ConocoPhillips 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) 10/27/2016 10/27/2016 0.25 PROD3 DRILL WPRT P Continue wiper to swab,tag up,restet 675.0 78.4 00:00 00:15 counters. 10/27/2016 10/27/2016 1.25 PROD3 DRILL TRIP P RBIH to confirm TD 78.4 6,430.0 00:15 01:30 10/27/2016 10/27/2016 0.20 PROD3 DRILL DLOG P Tie in to K1 for minus 1 ft correction 6,430.0 6,470.0 01:30 01:42 10/27/2016 10/27/2016 1.45 PROD3 DRILL TRIP P Continue RIH,stop at window for 6,470.0 9,754.0 01:42 03:09 SBHP at 6,641 ft(Bit at 6,690 ft at 01:49)BHP 3,797 psi,5 minutes 3,798 psi=12.1 ppg EMW at window, bring pumps back on and continue RIH,clean past billets at 7,580 ft, 8,465 ft and 8,808 ft,stacked 1k at 9,412 ft,clean to corrected TD at 9,754 ft,CWT 6k. 10/27/2016 10/27/2016 0.85 PROD3 DRILL DISP P 9,754 ft.Tag corrected TD,PUW 40k, 9,754.0 9,754.0 03:09 04:00 pump 12.2 ppg beaded liner pill. 10/27/2016 10/27/2016 3.00 PROD3 DRILL DISP T Lost prime on pump at 20 bbls away, 9,754.0 9,754.0 04:00 07:00 noticed 10.8 ppg fluid at the in MM, Diagnose problem and found that the suction valve was still cracked open, contaminating the liner pill,circulate contaminated flud out of hole 10/27/2016 10/27/2016 3.00 PROD3 DRILL TRIP P POOH,laying in liner running pill with 9,754.0 78.6 07:00 10:00 alpine beads up to the window painting EOP flags, 10/27/2016 10/27/2016 0.50 PROD3 DRILL OWFF P Check well for flow,PJSM 78.6 78.6 10:00 10:30 10/27/2016 10/27/2016 0.50 PROD3 DRILL PULD P LD drilling BHA#16 78.6 0.0 10:30 11:00 10/27/2016 10/27/2016 0.50 COMPZ3 CASING PUTB P PJSM,prep rig floor for MU AL1-01 0.0 0.0 11:00 11:30 liner assembly 10/27/2016 10/27/2016 4.50 COMPZ3 CASING PUTB P MU AL1-01 liner assembly wtih 102 jts 0.0 3,152.3 11:30 16:00 of slotted liner with 2 pups. 10/27/2016 10/27/2016 1.25 COMPZ3 CASING PULD P PU/MU Surface test Coiltrak tools 3,152.3 3,196.5 16:00 17:15 10/27/2016 10/27/2016 3.50 COMPZ3 CASING RUNL P RIH,w/Liner BHA#17 102 jts of 3,196.5 9,750.0 17:15 20:45 slotted liner and shorty deployment sleeve.Minus 12.0 ft correction at flag, PUW 49k, RBIH,started stacking at 8,040 ft,work liner,plus 2 ft at bottom flag,work to 9,750 ft. 10/27/2016 10/27/2016 0.30 COMPZ3 CASING RUNL P 9,750 ft.On depth,PUW 56k,on line 9,750.0 6,598.0 20:45 21:03 1.3 bpm to release off liner, PUW 28k, reset counters,TOP of liner at 6,598 ft. 10/27/2016 10/27/2016 1.30 COMPZ3 CASING DISP P 6,598 ft. Displace well to seawater, 6,598.0 6,598.0 21:03 22:21 LRS on site,PJSM with LRS 10/27/2016 10/27/2016 0.75 COMPZ3 CASING TRIP P POOH pumping seawater to 2,500 ft. 6,598.0 2,500.0 22:21 23:06 LRS P/T lines and equipment. 10/27/2016 10/28/2016 0.90 COMPZ3 CASING FRZP P 2,500 ft.LRS pump 30 bbls diesel, 2,500.0 2,500.0 23:06 00:00 RDMO LRS. 10/28/2016 10/28/2016 1.00 COMPZ3 CASING TRIP P POOH pumping diesel. PJSM-PUD 2,500.0 44.2 00:00 01:00 BHA 10/28/2016 10/28/2016 1.75 COMPZ3 CASING PULD P PUD/LD running tool BHA#17. 44.2 0.0 01:00 02:45 Page 14/15 Report Printed: 10/31/2016 0 11 Operations Summary (with Timelog Depths) 0 2B-02 Conocc*Ihillips Akssk� 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(fCK8) 10/28/2016 10/28/2016 2.00 DEMOB WHDBOP MPSP P PJSM-Bring in BPV equipment, MU 0.0 0.0 02:45 04:45 and lubricate in 3"GRAY BPV, Final TBG 1,230 psi,close master half way, bleed above BPV to 450 psi,holding good,bleed to zero,close master, RDMO BPV equipment and crew. 10/28/2016 10/28/2016 1.25 DEMOB WHDBOP RURD P PJSM-Skid cart, MU nozzle,flush 0.0 0.0 04:45 06:00 coil,jet BOP stack and surface lines 10/28/2016 10/28/2016 6.00 DEMOB WHDBOP RURD P Start Rig move check list,blow down 0.0 0.0 06:00 12:00 steam lines,blow down coiled tubing reel,disconnect PUTZ,nipple down BOPE,etc....Trucks on location PJSM for moving subs off of well. .""Rig Released 12:00 noon Page 15/15 Report Printed: 10/31/2016 d Ln ,n _ a, Uv O V CU -0 1 1 $' Y > N O Q c Y N p"�C O .a w v w M aJ L t c `0 0 0". 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D) D) O) M D) O O O O E t 0 N N N CO N N N N N Vf L 01 O O O O O O O O C O D- V O O O O O O O O O u OV U) l() U) If) U) l() U) l() U) Y O L' d1 76 a v ° o �' E iv c u b.0 al Ca w Y z ^ E E 2 & Q ri r O r M N O O N i0 a) c0 m l ▪ IL pa, c O N O N O ... i i " = C H 2 h CO CO Q y o th th > a (0 0 J . 2 ...... 0.. .... ,,,,,, — M M M M M M N 4) Z w O O `7 y c••1 ^ as _C y E E !/a a 3 do it a a t° F°- • ti0FTit • AO' I v7,� THE STATE Alaska Oil and Gas of \ LAC I A Conservation Commission 333 West Seventh Avenue ' ' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Jason Burke CTD Coordinator WANED FEB 0 2.0` ' ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2B-02 Permit to Drill Number: 184-122 Sundry Number: 316-362 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, Cathy . Foerster Chair DATED this aficky of July, 2016. RBDMS '--- JUL 2 2 2016 • • RECEIVED STATE OF ALASKA JUL 3 Z��6 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 6/ (� 1`'�SIZA fL6 20 AAC 25.280 tV ti.�1 GC 1.Type of Request: Abandon 0 Plug Perforations El Fracture Stimulate❑ Repair Well ❑ Operations shutdown 0 Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing Li Change Approved Program❑ Plug for Redrill D. Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. ConocoPhillips Alaska Inc Exploratory ❑ Development Q • 184-122 3.Address: Stratigraphic 0 Service ❑ 6.API Number: ], PO Box 100360,Anchorage AK 99510 50-029-21154•t0-04v 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No D/ KRU 2B-02 • 9.Property Designation(Lease Number): ixib 10.Field/Pool(s): ADL 25656 AN42682 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): 6976' 6286' 6851' - 6216', 3372 psi t/ N/A 6685'/Fish Casing Length Size MD TVD Burst Collapse Structural N/A N/A N/A N/A N/A N/A Conductor 110' 16"62.5# 110' 110' 1640 psi 630 psi Surface 2727' 9-5/8"36# 2727' 2727' 3520 psi 2020 psi Intermediate N/A N/A N/A N/A N/A N/A Production 6933' 7"26# 6933' 6287' 4980 psi 4320 psi Liner N/A N/A N/A N/A N/A N/A Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6526'-6710'/ 5942'-6098' 3-1/2"9.3# J-55 6018' Packers and SSSV Type: SSSV:OTIS FMX Locked Out Packers and SSSV MD(ft)and TVD(ft): • SSSV:1891'MD&1891'TVD Packer:CAMCO HRP-1-SP Retrievable&Baker 'Packer. 6377'MD&5818'TVD,6599'MD&6005' FB-1 Permanent TVD 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program Q BOP Sketch 0 Exploratory 0 Stratigraphic❑ Development 0 • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 7/14/2016 OIL ❑ WINJ ❑ WDSPL ❑ Suspended 0• 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR 0 SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned Li 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact �t f7 Email `Ct`xy��� (,�/� �L^y/�� Printed Name k4""•-''�� Title t%1it 602.6`/rte' t"'� J "'Y Signature Phone ate COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test1±r- Mechanical Integrity Test ❑ Location Clearance 0 Other 0 /25') dl� f1 � � it-vi vy vl 4 t- P rG JL ' 11 fry,r oL'pp�/' 4 p r--,' .2 v /14-e 2 5-- / / �l �-��r��a tc � y �l��� Post Initial Injection MIT Req'd? Yes ❑ No L " Spacing Exception Required? Yes ❑ No Er Subsequent Form Required: ? !CJo--4.1)APPROVED BY Approved by: 4 COMMISSIONER THE COMMISSION Date:7� .../A3��/1e//l'd��6 wo,)is. 4,4 ?O37/ Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate ORIGINAL R.BDMSLL- JUL 222016 3 KUP • 2B-02 ConocoPhillips 0iD Well Attributes Max Angle&MD TD A)BSka,IT1C Wellbore APIS/WI Field Name Well Status Incl I') MD(ftKB) Act Btm(ftKB) ca o�vramps 500292115400 KUPARUK RIVER UNIT PROD 39.17 4,200.00 6,976.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date "' SSSV:LOCKED OUT 100 12/162012 Last WO: 38.40 8/23/1984 Well Confq:-213-02.6/18/2013102626 AM Schematic-Actual Annotation (ftKB)DeP ftKB) End Date Annotation Last Mod...End Date Last Tag:SLM C 6,683.0 5/19/2011 Rev Reason:H2S,DRILLING DEPTHS/DATES I osborl I 6/18/2013 Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt..String...String Top Thrd HANGER.30 ' "' CONDUCTOR 16 15.062 35.0 110.0 110.0 62.50 H-40 WELDED Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt..String...String Top Thrd SURFACE 95/8 8.921 34.1 2,727 2,726.8 36.00 J-55 BTC Casing Description String 0... String ID...Top(ftKB) Set Depth2(1`...Set Depth(ND)...String Wt...String_.String Top Thrd PRODUCTION 7 6.276 312 6,933.6 6,286.8 26.00 J-55 BTC Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt..String... String Top Thrd TUBING 'String I 2.992 I 30.5 6,615.6 I 6,018.5 I 9.30 I J-55 I EUE8RD Completion Details Top Depth (ND) Top mel Nomi... CONDUCTOR, Top(ftKB) (ftKB) (') Item Description Comment ID(in) 35110 30.5 30.5 0.01 HANGER GRAY TUBING HANGER 3.500 SAFETY VLV, 1,891.4 1,891.3 0.73 SAFETY VLV OTIS FMX SAFETY VALVE,LOCKED OUT 4/18/98 2.813 1,891 { 6,359.5 5,803.4 33.71 SBR CAMCO OEJ-10 SBR 2.973 6,377.3 5,818.1 33.59 PACKER CAMCO HRP-1-SP RETRIEVABLE PACKER 2.867 GAS LIFT, 1.929 6,489.4 5,911.9 32.73 BLAST RINGS BLAST RINGS(3) 2.992 6,598.7 6,004.1 32.26 SEAL ASSY LOCATOR SEAL ASSEMBLY 3.000 6,599.5 6,004.9 32.25 PACKER BAKER FB-1 PERMANENT PACKER 4.000 6,602.0 6,007.1 32.49 SBE BAKER SEAL BORE EXTENSION 3.000 6,611.4 6,015.0 32.49 NIPPLE CAMCO D NIPPLE NO GO 2.750 SURFACE,_ 6,614.7 6,017.8 32.49 WLEG CAMCO SHEAR OUT SUB,ELMD TTL @ 6608'ON SWS PPROF 2,937 3°'2.72 DATED 1/5/07 GAs;e - Other In Hole ireline retrievable plugs,valves,pumps,fish,etc.) Top Depth (ND) Top Incl Perforations&Slots GAS UFT, Top(ftKB) (ftKB) C) Description Comment Run Date ID(in) 4,637 _ 6,685.0 6,077.1 32.48 FISH 3"OK-1 Ann ASSY Lost Downhole on 9/12/96 9/12/1996 0.000 GAS LIFT, _ `- Shot 5,864 Top(TVD) Btm(TVD) Dens Top(ftKB)Btm(ftKB) (ftKB) (ftKB) Zone Date (sh.- Type Comment GAS LIFT, 6,526.0 6,568.0 5,942.8 5,978.2 C-4,2B-02 10/9/1984 12.0(PERF 120 deg.ph;5"DA Csg Guns 6,325 6,586.0 6,588.0 5,993.4 5,995.1 UNIT B,2B-02 10/10/1984 4.0 IPERF Squeeze Perfs;4"DA Csg Gun SBR.6.369 6,620.0 6,710.0 6,022.2 6,098.2 A-3,A-4,A-5, 10/9/1984 4.0 IPERF 120 deg.ph;4"JJ Csg Gun H-, 2B-02 PACKER.6.377 Stimulations&Treatments Bottom 71 Min Top Max Btm Top Depth Depth Depth Depth (TVD) (ND) PRODUCTION, _._i. 4 (ftKB) (ftKB) (ftKB) (ftKB) Type Date Comment 6,815 6,526.0 6,568.0 5,942.8 5,978.2 C-SAND FRAC 11/2/2006 Pump C sand fracture treatment at 20 bpm using 50# X-linked gel.Pump total of 138,341#of 1620 PRODUCTION, ceramic proppant,placing 126,640#prop behind pipe 6.483 with 10 ppa on perfs.Screened out while on flush, recovered all tree saver rubber. Cement Squeezes IPERF. Top Depth Btm Depth 6,526-6,566 (TVD) (TVD) CSAND FRAC,\ Top MKS) Btm(ftKB) (ftKB) (ftKB) Description Start Date Comment 6•526 6,586.0 6,588.0 5,993.4 5,995.1 Cement Squeeze 10/10/1984 Squeeze Perfs Notes:General&Safety End Date Annotation 9/16/2010 NOTE:View Schematic w/Alaska Schematic9.0 PRODUCTION, 5/19/2011 NOTE:MANDREL 3-SLIGHTLY BENT LATCH 6.582'PERE, 6.586-6,588 6.586-6,588 Cement,6,586 = --- SEAL ASSY 1 _4t 1 6,599 C PACKER.8.600 AIMMIMO SBE,6,602 --- 6 NIPPLE,6,611 - WLEG,6.615 ------ Mandrel Details Top Depth Top Port lit5-„ (TVD) Incl OD Valve Latch Size TRO Run N...Top IftKB) (ftKB) (`) Make Model (In) Sery Type Type (in) (psi) Run Date Corn... 1' 1,929.0 1,928.9 0.73 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,244.0 11/7/2006 IPERF, 2 3,478.3 3,458.1 20.84 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,245.0 11/7/2006 6,6206,710 3 4,837.0 4,574.3 36.06 CAMCO KBUG 1 GAS LIFT GLV BK 0.188 1,274.0 11/7/2006 Note FISH,6,685 4 5,863.9 5,396.9 35.53 CAMCO KBUG 1 GAS LIFT GLV BK 0.188 1,266.0 11/7/2006 5 6,324.7 5,774.5 33.92 CAMCO KBUG 1 GAS UFT OV BK 0.250 0.0 11/6/2006 6 6,414.7 5,849.4 33.05 CAMCO KBUG 1 PROD HFCV BEK 0.000 0.0 5202011 7 6,482.9 5,906.5 32.75 CAMCO KBUG 1 PROD HFCV BEK 0.000 0.0 5/20/2011 8' 6,582.1 5,990.1 32.33 CAMCO KBUG 1 PROD HFCV BEK 0.000 0.0 5/20/2011 PRODUCTION. 316,934 A . TD,6,976 • • Proposed 2B-02 CTD Schematic Modified by JAB 6/14/16 3-1/2"9.3#L-80 EUE 8rd Tubing to surface 3-1/2"Otis FMX SSSV at 1812'RKB(locked out 4/98) Camco OEJ-10 SBR @ 6,359'RKB(2.973"min ID) 16"62#H-40 — Camco HRP-1 SP Retrievable Packer @ 6,377'RKB shoe @ 110' MD Blast Rings @ 6,489'RKB 3-1/2"Camco gas lift mandrels @ 1,929',3,478',4,837',5,864', 6,325'RKB 9-5/8"40#J-55 shoe @ 2727' hmiffil Baker Locator Assembly @ 6,599'RKB MD Baker FB-1 packer @ 6,599'RKB(4.0"ID) Baker SBE @ 6,602'RKB 3-1/2"Camco production mandrels @ 6,415',6,483',6,582'RKB C-sand perfs 6,526' _ 3-1/2"Camco DS nipple @ 6,611'MD(2.75"min ID No-Go) -6,568'MD - — Camco SOS @ 6,615'RKB • Perfs( nz'd) -= Tubinc Tai!Perf(g7 6613'RK,B 6,586'MD-6,588' 3-1/2"tubing tail @ 6616'RKB MD A-sand perfs( ) 6,620'-6,710'MD Fish @ 6,685'RKB -- -3"OK-1 Arm ' ' Assembly 7"26#J-55 shoe @ 6934'MD • • RECEIVED ConocoPhillips JUL 13 2016 Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 July 13, 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 5 laterals out of the Kuparuk Well 2B-02 using the coiled tubing drilling rig, Nabors CDR2-AC or CDR3-AC. To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being limited to 500'from the original point. A sundry application is attached to plug the KRU 2B-02 (184-122) 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 2B-02. Attached to this application are the following documents: — 10-403 Sundry Application to Abandon KRU 2B-02 (184-122) — Operations Summary in support of the 10-403 sundry application — 10-401 Applications for 2B-02A, 2B-02AL1, 2B-02AL1-01, 2B-02AL1-02, and 2B-02AL2 — Detailed Summary of Operations — Directional Plans for 2B-02A, 2B-02AL1, 2B-02AL1-01, 2B-02AL1-02, and 2B-02AL2 — Proposed CTD Schematic If you have any questions or require additional information, please contact me at 907-263-4180. Sincerely, Mike Callahan ConocoPhillips Alaska Coiled Tubing Drilling Engineer • • KRU 2B-02 CTD Summary for Plugging Sundry (10-403) Summary of Operations: KRU well 2B-02 is a Kuparuk NC-sand producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize three laterals to target the A3/A4 sand to the southwest and northwest of 2B-02. The laterals will access stranded resources in 2-3 fault blocks. Prior to CTD operations the nipple at 6611' RKB will be milled out and the existing A-sand and C-sand perforations will be squeezed with cement and the 3-1/2" tubing tail will be punched and cemented in place to provide a means to kick out of the 7" casing. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1) to plug the A-sand and C-sand perforations in this manner. Following the cement squeeze Nabors CDR2-AC will drill a pilot hole to 6680' MD and set a mechanical whip-stock in the 2.80" pilot hole to kick off at 6640' MD. All the laterals will be completed with 2-3/8" slotted liner from TD with the last lateral liner top located inside the 3- 1/2" tubing tail. Using the maximum formation pressure in the area of 3973 psi in 2B-08, the maximum potential surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 3372 psi. CTD Drill and Complete 2B-02 Laterals: September 2016 Pre-CTD Work 1. RU Slickline: Dummy off gas lift mandrels, pull production mandrels. 2. RU E-line: Run caliper, punch tubing at 6613' MD, set composite bridge plug and obtain SBHP. 3. RU Pumping: Swap hole over to diesel and perform injectivity test 4. RU Service Coil: Cement squeeze the C-sand perforations, wait 3 days. Pressure test squeeze, mill cement and composite bridge plug. Mill out nipple set at 6611' MD, and lay in cement plug and squeeze off the A-sand perforations. 5. RU Slick-line: Tag top of cement and pressure test cement. 6. Prep site for Nabors CDR2-AC and set BPV. Rig Work 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 2B-02A Sidetrack (A4 sand - Southwest) a. Drill 2.80" high-side pilot hole through cement to 8225' MD b. Caliper pilot hole c. Set top of whip-stock at 6640' MD d. Mill 2.80" window at 6640' MD. e. Drill 3" bi-center lateral to TD of 9900' MD. f. Run 2%" slotted liner with an aluminum billet from TD up to 8385' MD. 3. 2B-02AL1 Lateral (A4 sand - Northwest) a. Kick off of the aluminum billet at 8385' MD. b. Drill 3" bi-center lateral to TD of 10425' MD. / j; ion cat% Gesref4 w','// 1P 604,fier'r/ 1^"i7 *I%/7`6' e'" Page 1 of 2 !ACk /'4 to e,, 't: 'j +tiilllk)Pe 0 , 0. 41i( Ib (�tii&e de ve(% 6!14/2016 4.e euisnn/ re/cr./a f rodAt°4 . ic cviren- . 'OM • c. Run 23 slotted liner with an aluminum billet from TD up to 8500' MD. 4. 2B-02AL1-01 Lateral (A3 sand - Northwest) a. Kick off of the aluminum billet at 8500' MD. b. Drill 3" bi-center lateral to TD of 9800' MD. c. Run 2%" slotted liner with an aluminum billet from TD up to 6610' MD. 5. Freeze protect, set BPV, ND BOPE, and RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV 2. Obtain SBHP 3. Install gas lift design 4. Return to production Page 2 of 2 6/14/2016 • • toepp, Victoria T (DOA) From: Callahan, Mike S <Mike.Callahan@conocophillips.com> Sent: Monday,July 18, 2016 9:05 AM To: Loepp,Victoria T(DOA) Subject: 2B-02 Plugging Sundry(10-403) BOP Test Pressure Victoria,the BOP test pressure for the plugging operation on 2B-02 will be 3750 psi, based on the maximum potential surface pressure of 3372 psi. This will be the same test pressure that we will go to with Nabors CDR-2 when we rig up for the CTD sidetrack. Please let me know if this answers your question or if you would like any more information. Thanks, Mike Callahan CTD Engineer ConocoPhillips Alaska ATO 660 Office: (907) 263-4180 Cell: (907)231-2176 1 • • Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re- drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box Geologist in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Geologist work) the initial reviewer will cross out that erroneous entry and initial then it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended" box and initial that change. Drilling Engineer The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill" box, she will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, she will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, she will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding"user query in RBDMS to ensure that all of the Plug for Redrill wells have been Geologist handled properly. At this same time, they will also review the list of suspended wells for accuracy. •° • (I T. w c1 cc leinr, 4 Or 11 _ire, bD > I--• Y N ca 3 o r- o v Q , - a, vo a) -c c co 1- ca tn > _ o_ N C A Q C O p -g W.. Q;: fa 4-• CO f0 Q Q pcD co CO cao O N E L m J r t V 4 Cr 0 C C C " aJ C aC �, N F- O 7 7 3 E -C C C (p Na N N N 0 N Q N Z 0 O -p s- p T �- 0 0 0 0 +' u t r 6 W. J J J J C C LI L L >- W _W W_ W_ 40 C CO 2 O r...11 - LL LL LL LL F ',.7) N E pp a Q J J J J +' N p c N 0 Cr) O Z Z Z Z (I) V, -0 LL LL LL LL v L wv v Q co N C O J (1) Q1 O Q a1 +-' -p 1...1 o N 0 c O -0 C a7 = 0 F- f0 Q, (1) a-, G O Q. H >• r>a C w CO • v d u_ < a) .c L > V Q a a U U U > U ria J W ou 0 o jig 0� xi aao - � Z_ I I I I I w Ix 03 co N. W o r� cc x v a zRME i,;,, y, Z 4.--.011-)'-'11 ► o, Z5 w W W W Yn VW W > > > > z Y Y Y Y DDDD E ® 13 W Q Q Q Q �` cu In CL a a a \� 0 0 > > O Y Y Y Y ILI LO ® q etaC 0' v , N X n 0 W C) V7 N 0 Q a V V7 O cc O O O CO Mille 1l, OO 0 0 O O O O •� U U U D E co0 0 0 U Si Per > C7 C7 C7 -0 w 0 0 0 0 v ro C Cr cD p o c O f6 u 0 0 0 o v( N V 4I' r-1, (n O (D N N r N N N vl 0 IN N N N N L V n m e rn da p ! 0 NNNN i V O O O O aJ O O O O •L N V1 � N 3 4) L CM ee ti c -LO Fa" c al w ov'i E u Y 8 W' C CO W ' Q 2. Q C ^l N 1n O Q a a, 7 d 1 e LL Alir m Z O N N ate+ E n 1 Q N J N D r' r co .. f— rci _ a W u al ,, iP C u 0 3 C - cv'o �`v, C/�.7Q1 a, �o a a Q 2-Cot CA WELL LOG TRANSMITTAL D A 4/2073 LOGGED /1 M.K.BENDER To: Alaska Oil and Gas Conservation Comm. r July 23, 2015 Attn.: Makana Bender Elm 333 West 7th Avenue, Suite 100 t{U!', / 3 ;". Anchorage, Alaska 99501 RE: Production Profile: 2B-02 Run Date: 7/7/2015 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 2B-02 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-21154-00 SCANNED Production Profile Log 1 Color Log 50-029-21154-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: Metvg-44-0?-4) 6.0,40,2t I`riage Project Well History File Ccr Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. - ~ ~,~ Well History File Identifier Organizing ~dDnel ^ Two-Sided III IIIIIIIIIII VIII RESCAN DIGITAL DATA ^ Color items: ^ Diskettes, No. ^ Grayscale items: ^ Other, No/Type ^ Poor Quality Originals: ^ Other: NOTES: BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELI_ ^ Rescan Needed III IIIIIIIIII VI III OVERSIZED (Scannable) ^ Maps: ^ Other items scannable by large scanner OVERSIZEp (Non-Scannable) ^ Logs of various kinds ^ Other DATE: /S/ P,o s nuiioiiuuiA BY: BEVERLY BREN VINCENT SHERYL MARIA LOWEL!_ DATE: /S/ Scanning Preparation ~ x 30 = ~~ '~' = TOTAL PAGES BY: BEVERLY BREN VINCENT LOWELL DATE: ~ 11 ~ ~° Production Scanning Stage 7 PAGE COUNT FROM SCANNED FILE: __ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: YES '- NO BY. BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE:~~ 1`7`~~/S/ Stage 2 IF NO IN STAGE 1, PAGE(S~ DISCREPANCIES WERE FOUND: YES NO BY. BEVERLY BREN VINCENT HERYL MARIA LOW ELL DATE:`I/~~0~/ (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN WDNIOUAL PAGE BASIS II I II I I II-I I III ~ I ~~I DUE TO QUALITY, GRAYSCAI.E OR COLOR IMAGES) i?eScanned (individual page (special attention) scanniny completed) III II I I II IIII III III RESCANNED BY. BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S/ General Notes or Comments about this file: Quality Checked (dGne) IIIIIIIIIIIIIIIIIII 10/25l02Rev3NOTScan n ed.wpd -~ ~; WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken . , „ 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 ~~~ D~~ ~ ~ 2009 RE: Production Profile: 2B-02 Run Date: 8/1/2009 October 14, 2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2B-02 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-21154-00 Injection Profile Log I Color Log 50-029-21154-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating ELI ~ I~ a Attn: Rafael Barreto t 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barreto@halliburton.com Date: ~~~s~3 ~~ ~, Signed: ~,~a~-~~-° ~" Thanks Perry From: NSK Well Integrity Proj [mailto:N1878@conocophillips.com] Sent: Wednesday, May 21, 2008 4:00 PM To: Maunder, Thomas E (DOA) Subject: RE: OOA Cementing ~~~~ ~ ~ ~. Tom, Yes the only change was to 28-02. I double checked the others before resending though. Typically we are long on volume pumped. I believe we are hitting ledges when getting top of cement readings. There is typically a small discrepancy, which I believe is cased by channels that may go deeper then where our string hangs up while strapping TOC. The error with 28-02 was simply a transposition of the decimal point, possibly a mistype. I've attached the modified form with gallons of inhibitor reported to the tenth of a gallon and cement reported to the 100th of a bbl. Let me know if you have any questions. ~~® MAY 2 1 200$ Perry From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, May 21, 2008 3:19 PM To: NSK Well Integrity Proj Subject: RE: OOA Cementing Perry, To confirm, the only change was for 26-02;' correct? From: NSK Well Integrity Proj [mailto:N1878@conocophillips.com] Sent: Wednesday, May 21, 2008 3:16 PM To: Maunder, Thomas E (DOA) Subject: RE: OOA Cementing Tom, I've attached a corrected sheet. This works for me. I've corrected and updated all the records on our end. I'm sorry for the inconvenience Perry ~'. From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, May 20, 2008 3:16 PM To: NSK Well Integrity Proj Cc: NSK Well Integrity Field Supv Subject: RE: OOA Cementing Perry, Can you email me the corrected sheet? If that works, that may be fastest. Tom From: NSK Well Integrity Proj [mailto:N1878@conocophillips.com] Sent: Tuesday, May 20, 2008 1:57 PM To: Maunder, Thomas E (DOA) Cc: NSK Well Integrity Field Supv Subject: FW: OOA Cementing Tom, You are correct, the cement volume should read 5.0 bbls not 0.5 bbls as is indicated in the 10- 404 table. I assume the easiest path forward would be for us to resubmit a corrected 10-404. Please advise. Perry From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, May 20, 2008 11:40 AM To: NSK Problem Well Supv Subject: OOA Cementing Perry, Just got your letter regarding filling the OOAs at 2B. Have a look at 2B-02. The cement volume looks a little low given the tag depth. Tom ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations X10-404) Date Kuparuk Field 5/14/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2B-01 184-115 25' 5" 3.25 23" 4/3/2008 1.7 4/20/2008 ' 26-02 184-122 30' S" 5.00 20" 4/3!2008 4.3 4/20/2008 2B-03A 203-009 4' 0.50 33" 4/3!2008 10.2 4/20/2008 2B-04 184-120 30' 4.00 28" 4/3/2008 6.4 4/20/2008 2B-06 184-022 26' 5.00 19" 4/3/2008 8.5 4/20/2008 26-09 184-027 74' 10.50 32" 4/3/2008 11.1 4/20/2008 26-10 184-029 74' 10.50 33" 4/3/2008 17.0 4/20/2008 2B-11 184-035 50' 7.50 29" 4/3/2008 6.0 4/20/2008 2B-12 184-038 6' 1.00 29" 4/3/2008 6.0 4/20/2008 2H-01 184-077 SF n/a SF n/a 2.5 4/30/2008 2H-02 184-073 SF n/a SF n/a 2.0 4/30/2008 2H-03 184-070 SF n/a SF n/a 4.0 4/30/2008 2H-04 184-055 SF n/a SF n/a 2.0 4/30/2008 2H-08 185-171 2' 6" n/a 2' 6" n/a 25.0 4/30/2008 2H-10 185-260 SF n/a SF n/a 2.0 4/30/2008 2H-11 185-261 SF n/a SF n/a 2.5 4/30/2008 2H-12 185-262 SF n/a SF n/a 2.5 4/30/2008 2H-13 184-096 2" n/a 2" n/a 2.0 4/30/2008 2H-14 184-095 SF n/a SF n/a 2.0 4/30/2008 Scblumbel'gel' \) 1. t}t)1 sC~,,~t> jj).~ ~ 01/24/07 NO. 4121 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ,\I\N 2. 9 Z001 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 n t'A, ^Q¡:1\Q\¡'Jn~ 17l-{- 18d Field: Kuparuk Well Color CD Job# Log Description Date BL 1 C-111 11415647 RST WFL 10/29/06 1 2B-01 11536780 PROD PROFILE 01/04/07 1 2H-11 11539477 PROD PROFILE 01/04/07 1 2B-02 11538781 PROD PROFILE 01/05/07 1 3N-19 11538782 PROD PROFILE 01/06/07 1 2W-06 11538784 PROD PROFILE 01/08/07 1 1C-28 L 1 N/A GLS 01/16/07 1 2M-06 11628958 INJECTION PROFILE 01/20/07 1 1C-117 11628954 INJECTION PROFILE 01/18/07 1 2K-16 11638814 PRODUCTION PROFILE 01/22/07 1 1Y -22 11638815 PRODUCTION PROFILE 01/23/07 1 2N-337 A N/A SBHP SURVEY 01/21/07 1 2M-26 N/A SBHP SURVEY 01/21/07 1 2M-03 N/A INJECTION PROFILE 01/22/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . . STATE OF ALASKA . ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon D Repair Well D Plug Perforations D Stimulate 0 Other D Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension D Change Approved Program D Operat. ShutdownD Perforate D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory D 184-1221 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21154-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 126' 2B-02 8. Property Designation: 10. Field/Pool(s): ADL 25656, ALK 2582 Kuparuk River Field 1 Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 6976' feet true vertical 6323' feet Plugs (measured) Effective Depth measured 6670' feet Junk (measured) 6685' true vertical 6064' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 110' 16" 110' 110' SUR. CASING 2601' 9-5/8" 2727' 2727' PROD. CASING 6807' 7" 6933' 6286' Perforation depth: Measured depth: 65~6'-6568', 6586'-6588', 6620'-6710' ';;-1(' t!\~\~lj (? I' ':;':?> "'4I1~ ~' .~) 1'1' --- true vertical depth: 5943'-5978',5993'-5995',6022'-6098' Tubing (size, grade, and measured depth) 3-1/2" , J-55, 6609' MD. Packers & SSSV (type & measured depth) pkr= CAMCO 'HRP-1-SP'; BAKER 'FB-1' pkr= 6386'; 6594' Otis 'FMX' SSSV= 1899' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 6526'-6568' Treatment descriptions including volumes used and final pressure: pump total 138341# of 16/20 ceramic proppant 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl CasinQ Pressure TubinQ Pressure Prior to well operation 119 750 414 -- 167 Subsequent to operation 329 1263 899 -- 165 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development 0 Service D Daily Report of Well Operations _X 16. Well Status after proposed work: Oil0 GasD WAGD GINJD WINJD WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: Contact Guy Schwartz @ 265-6958 p,;"ted Name. Guy SChwatq- Title Wells Group Engineer s~"'t"'" C~ s:-c-t Phone Date ,j,1_/ {, _ 0 (., PreDa bv Sharon AI/suo-Drake 263-4612 ') 2006 Form 10-404 Revised 04/2004 ORIGlNAL Submit Original Only 11/16/2006 . 2B-02 Well Events Summary . DATE Summary 9/7/06 TIFL PASSED (PRE-FRAC) 10/19/06 TAGGED @ 6670' RKB, EST. 40' FILL. PULLED CV @ 6589' RKB, REPLACED WITH DV. IN PROGRESS. 10/20/06 SET 2.75" SV @ 6605' RKB. PULLED GLV @ 5870', CVs @ 6421' & 6489' RKB. SET DV @ 6489'. IN PROGRESS. 10/21/06 PULLED GLVs @ 1935', 3485' & 4843'. SET DVs @ 1935', 3485',4843',5870' & 6421'. PULLED 2.75" SV @ 6605' RKB. IN PROGRESS. 10/22/06 BRUSHED TBG TO 6605' RKB. SET 2.75" SV @ 6605'. ATTEMPTED TEST TBG, FAILED. TROUBLESHOOT CSM @ 6589'. IN PROGRESS. 10/23/06 PULLED & REPLACED DV @6589'. PULLED DV @6331'. LOADED TBG & IA WITH 156 BBL SW & 70 BBL DSL. SET DV @6331'. MIT TBG & IA 3500 PSI, PASS. ATTEMPTED PULL 2.75" SV. IN PROGRESS. 10/24/06 PULLED 2.75" SV @6605' RKB. JOB COMPLETE. 10/28/06 Lay in 1500# of 20/40 sand, for pre-frac plug to a ICoil corrected tag depth of 6597' (12' above TTL). Freeze protected tubing w/diesel from 6000' to surface. 10/29/06 TAGGED SAND PLUG @6580' RKB. PULLED 1" DMY FROM STA# 7 @6489' RKB (OPEN POCKET), PULLED 1" DMY FROM STA # 6 @ 6421' RKB (OPEN POCKET). SET FMX FRAC SLEEVE (OAL = 104", MIN ID = 2.31") @ 1899' RKB. JOB COMPLETE. 11/2/06 Pump C sand fracture treatment at 20 bpm using 50# X-linked gel. Pump total of 138,341# of 16/20 ceramic proppant, placing 126,640# prop behind pipe with 10 ppa on perfs. Screened out while on flush, recovered all tree saver rubber. 11/5/06 Performed a FCO to 6,829.3' RKB. Mandrels washed in route to surface. Well freeze protected to 6,829.3' RKB. 11/6/06 PULLED FRAC SLEEVE FROM SAFTY VALVE, TAG BOTTOM @ 6780' RKB, PULL DMY'S @6331', 5870' & 4843' RKB, SET OV @6331' RKB. IN PROGRESS. 11/7/06 PULLED DVs @ 3485',1935' RKB. SET GLVs @ 5870', 4843',3485',1935' RKB. PULLED CATCHER @6605' RKB. UNABLE BLEED PRESSURE OFF IA. ATTEMPTED T/S WITH D&D TEST TOOL. IN PROGRESS. 11/8/06 SET TEST TOOL @ 6380' WL. TESTED TBG/GLVs, GOOD. COMBO MIT, GOOD. SET CATCHER @ 6605' RKB. PULLED DV @ 6589' RKB. SET HFCV @ 6489'. IN PROGRESS. 11/9/06 SET HFCVs @6589', 6421' RKB. PULLED CATCHER. . . . ConoeoPhillips Alaska. Inc. KRU 28-02 2B-02 API: 500292115400 Well Type: PROD Angle @ TS: 33 deg @ 6525 SSSV SSSV Type: LOCKED OUT Orig Completion: 8/23/1984 Angle @ TD: 32 deg @ 6976 (1899-1900, Annular Fluid: Last W/O: Rev Reason: GLV C/O OD:3.500) Reference Log: Ref Log Date: Last Update: 11/14/2006 Last Tag: 6670 TD: 6976 ftKB Last Tag Date: 10/20/2006 Max Hole Angle: 39 deg @ 4200 Gas Lift Casing string - ALL STRINGS MandreVVa~ Description Size Top Bottom TVD Wt Grade Thread 1 (1935-1936, CONDUCTOR 16.000 0 110 110 62.50 H-40 OD:5.313) SUR. CASING 9.625 0 2727 2727 36.00 J-55 PROD. CASING 7.000 0 6933 6286 26.00 J-55 Gas Lift Tubing String - TUBING (Note: Tbg Tall off One Joint) MandreVVa~ Size I Top Bottom TVD I Wt Grade I Thread 2 (3485-3486, 3.500 0 6609 6013 9.30 J-55 8RD EUE OD:5.313) Perforations Summary Gas Lift Interval TVD Zone Status Ft SPF Date Type Comment MandreVVa~ 6526 - 6568 5943 - 5978 C-4 42 12 10/9/1984 IPERF 120 deg. ph; 5" DA Csg Guns 6586 - 6588 5993 - 5995 UNIT B 2 0 10/10/1984 3 (4843-4844, 6620 - 6710 6022 - 6098 A-5,A-4,A-3 90 4 10/9/1984 IPERF 120 deg. ph: 4" JJ Csg Gun OD:5.313) Stimulations & Treatments Gas Lift Interval Date Type Comment MandreVVa~ 6586 - 6588 10/10/1984 Cement Squeeze Perfs 4 (5870-5871, 0-0 8/14/1990 Scale Inhibitor 26 BBL DSL +SI, 30 BBL SW + 3 BBL S-289, 380 BBLS OD:5.313) 0-0 1/16/1992 Scale Inhibitor 26 BBL DSL + 1 Drum SS-8603, 50 BBL SW + 5 Drums S 6526 - 6568 11/2/2006 C-SAND FRAC Pump C sand fracture treatment at 20 bpm using 50# X-linked gel. Gas Lift Pump total of 138,341# of 16/20 ceramic proppant, placing 126,640# MandreWa~ prop behind pipe with 10 ppa on perfs. Screened out while on flush, 5 (6331-6332, recovered all tree saver rubber. OD:5.313) Gas Lift MandrelsNalves St MD TVD Man Man Type VMfr V Type VOD Latch Port TRO Date Run Vlv S8R Mfr Cmnt (6377-6378, 1 1935 1935 Cameo KBUG GLV 1.0 BK 0.156 1244 11nl2006 OD:3.500) 2 3485 3464 Cameo KBUG GLV 1.0 BK 0.156 1245 11/7/2006 3 4843 4579 Cameo KBUG GLV 1.0 BK 0.188 1274 11n/2006 (1) 4 5870 5402 Cameo KBUG GLV 1.0 BK 0.188 1266 11/7/2006 PKR 5 6331 5780 Cameo KBUG OV 1.0 BK 0.250 0 11/6/2006 (6386-6387, 1. Slightly bent latch OD:6.156) Production MandrelsNalves St MD TVD Man Man Type VMfr V Type VOD Latch Port TRO Date Run Vlv Mfr Cmnt Production 6 6421 5855 Cameo KBUG MACCO OPEN 1.0 BK 0.000 0 10/29/2006 MandreVVa~ 7 6489 5912 Cameo KBUG MACCO HFCV 1.0 BK 0.000 0 11/9/2006 6 (6421-6422, 8 6589 5996 Cameo KBUG MACCO HFCV 1.0 BK 0.000 0 11/9/2006 OD:5.313) Other "plugs. equip., etc.) - JEWELRY Production Depth TVD Type Description ID MandreVVa~ 1899 1899 SSSV Otis 'FMX'. SSSV LOCKED OUT 4/18/98. 2.813 7 (6489-6490, 1 6377 5818 SBR Cameo 'OEJ-10' 2.969 OD:5.313) 6386 5825 PKR Cameo 'HRP-1-SP' 2.859 ~:: :: -.2- 6594 6000 PKR Baker 'FB-1' 4.000 -~ 6605 6009 NIP Cameo 'D' Nipple NO GO 2.750 5=:: ::~ 6608 6012 SOS Cameo 'PE-500' 2.984 -"-- - ~ 6609 6013 TTL 2.984 Cement £= =:I Fish - FISH (6586-6588) '" Depth I Description I Lost Downhole on 9/12/96 Comment tt 6685 3" OK-1 Arm ASSY Production MandreVVa~ 8 (6589-6590, OD:5.313) PKR ,.. ',:'-' (6594-6595, OD:6.156) U ¡ NIP (6605-6606, Xi-';.,,: OD:3.500) TUBING ~ (0-6609, OD:3.500, __"":"n~_,, ''':''''''>''__ ID:2.992) Perf (6620-6710) -- . Schlumberger Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Well Job # 18-;:-C4/ 2U-12 ß:j., /22. 2B-02 /;1'3 -67730-07 ¡<:{i-tJ]2-- 2V-15 2oi-f ~ðc;' I 1 E-112 ., ,',' fJ d 2P-427 ¿...ú 1.. oJ , 1 D 10942844 10922542 10922549 10922543 10922552 10922545 SIGNED: PROD PROFILE/DEFT PROD PROFILE/DEFT INJECTION PROFILE PROD PROFILE/DEFT INJECTION PROFILE SCMT ¿/ý& f? 5- Log Description SCAr~U~E[\ Þ.PR 1 5 2005 Date 02/15/05 02/26105 03/05/05 02/27/05 03/08/05 03/01/05 /gÝ-!27- 03/15/05 NO. 3365 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk ~ BL Color CD 1 1 1 1 1 1 .~- / ./ (;-:;1íd~ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic 91vd, Suite 300 Anchorage, AK 99503-5711 ATTN- Beth NO. 2926 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 0 7/31/0 3 Field: Kuparuk Well Job # Log Description Date BL Color CD 19-10 iR)' I ;'"~,, ~".~ SBHP 07/21/03 1 1C-27 ! c~-~..~'~ TEMP/PRESS SURVEY 07/22/03 1 1D-140 ~,"- ~ % L~ SBHP 07/22/03 1 1J-10 ?~(~) ~, -~.7-~ (SBHP 07/21/03 1 29-01 ]~ .~1 '~-\.,~ PRODUCTION PROFILE .07/19/03 1 29-02 I~)-.~- t:~. ~-,~PRODUCTION PROFILE 07120/03 1 29-14 1~' ~I \ ~PRODUCTION PROFILE 07/23/03 1 29-11 ~ ~.Li_-~,~.'~/.~ iPRODUCTION PROFILE 07/18/03 1 3F-13A 1~( ~'"~. :~i'~-' LDL 07/17/03 1 3K-08 \ ~,. (.0 ' I.~ LDL 07/25/03 1 3M-03 i~'~'J I L~ LDL 07/24/03 3S-19 ~'~._'_~-(~_5! PERF/JEWELRY/& INITIAL SBHPS 07/11/03 1 , , DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ! STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing Alter casing Stimulate X Plugging Perforate __ Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 744' FSL, 273' FEL, Sec. 19, T11N, R9E, UM At top of productive interval 1037' FNL, 935' FEL, Sec. 30, T11N, R9E, UM At effective depth 1203' FNL, 989' FEL, Sec. 30, T11N, R9E, UM At total depth 1267' FNL, 1010' FEL, Sec. 30, T11N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 6976 6322 feet feet 6. Datum elevation (DF or KB) RKB 126 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2B-02 9. Permit number/approval number 84-122 10. APl number 50-029-211 54-00 11. Field/Pool Kuparuk River Field/Oil Pool Plugs (measured) None Effective depth: measured 68 51 true vertical 621 6 feet feet Junk (measured) None Casing Length Structural Conductor 8 0' Surface 2 6 9 3' Intermediate Production 6902' Liner Perforation depth: measured 6526'-6568', true vertical 5942'-5978', Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., J-55 @ 6608' Packers and SSSV (type and measured depth) Pkr's: Size Cemented 1 6" 119 Sx CS II 9-5/8" 800SXCS III& 300 Sx CS II 7" 280 Sx Class G & 250 Sx CS I Measured depth True vertical depth 6620'-6710' 6023'-6097' 103' 103' 2725' 2725' 6933' :t '~ !.' 4&*/ra.o/l.4r:_ /."~ 1,9~? Camco HRP-1SP ~ 6372' & Baker FB-1 ~ 6592'; SSSV: Otis FMX ~ 1899' 13. Stimulation or cement squeeze summary Refracture "A" sands on 7/31/96 ORIGINAL Intervals treated (measured) 6620'-6710' Treatment description including volumes used and final pressure Pumped 153.1 M lbs 20/40, 12/18, & 10/14 ceramic proppant into formation, fp was 1937 psi. 14. Representative Daily Average Production or In!ection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 5 3 3 336 93 820 162 Subsequent to operation 5 7 6 252 133 826 171 15. Attachments Copies Of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~lned 1~5-~- Form /88 Title Wells Superintendent Date 4-9-97 SUBMIT IN DUPLICATE ARCO Alaska, inc. f' ~ ,,,,i'i (UPARUK RIVER UNIT WELL SERVICE REPORT ~ K1(2B-02(W4-6)) . WELL JOB SCOPE JOB NUMBER 2B-02 FRAC, FRAC SUPPORT 0727961652.4 DATE DAILY WORK UNIT NUMBER 07/31/96 'A' SAND REFRAC ,.. .. DAY OPERATION COMPLETE J SUCCESSFUL KEY PERSON SUPERVISOr' ~'j I (~ Yes O NoI (~ Yes (~) No DS-YOAKUM PENF~/"/",,/ ESTIMATE KM1373 230DS28BL $1 1 1,657 $1 16,433~,.-'~'~ ~U-. ~ Initial Tba Press Final Tb.a Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I"Final Outer Ann 1 9 PSI 1600 PSI 375 PSI 500 PSII 0 PSI! 0 PSI DAILY SUMMARY FRAC'D 'A' SAND AS DESIGNED. PLACED 153,147 LBS SAND BEHIND PIPE, LEFT 700 LBS IN WELLBORE. TOP 5,600' OF TBG IS DIESEL-FILLED. USED 14,000 LBS 20/40, 131,000 LBS 12/18 AND 8,847 LBS 10/14 PROPPANT. TIME LOG ENTRY 06:00 MIRU DOWELL PUMPING EQUIP AND LRS & APC SUPPORT EQUIP. 08:00 HOLD PRE-JOB SAFETY MEETING, WORK UP AND QC FLUIDS, PRIME UP PUMPING EQUIP. PRESSURE TEST TO 8,000 PSI. SET TREE SAVER. 08:50 BEGIN PUMPING BREAKDOWN/CONDITIONING STAGE. 09:10 FINISH PUMPING BREAKDOWN/CONDITIONING STAGE, S/D. FFP -2,820 PSI, ISIP = 1,511 PSI. CONDUCT PULSE TESTING AND MONITOR WHP. 10:00 FINISH MONITORING WHP, START PUMPING DATAFRAC. 10:20 FINISH PUMPING DATAFRAC, S/D. FFP = 2,802 PSI, ISIP = 1,543 PSI. MONITOR WHP AND CALCULATE PAD. 11:25 START PUMPING PAD: 58 BBLS XL GEL H20 @ 5 BPM. 11:35 INCREASE RATE TO 20 BPM, PuMP 72 ADD'L BBLS OF PAD. 11:40 START ADDING 2 PPA 20/40 PROPPANT, PUMP 100 BBLS @ 20 BPM. 11:45 SWITCH TO 12/18 PROPPANT, PUMP 449 BBLS @ 20 BPM WHILE RAMPING PROP CONC FROM 2 PPA TO 8 PPA. 12:05 PUMP ADD'L 200 BBLS @ 20 BPM W/FLAT PROP CONC OF 8 PPA. 12:17 PUMP ADD'L 25 BBLS @ 20 BPM WHILE RAMPING PROP CONC FROM 8 PPA TO 10 PPA. 12:19 SWITCH TO 10/14 PROPPANT @ 10 PPA AND PUMP 40 BBLS @ 20 BPM. 12:20 CUT PROPPANT, SWITCH TO DIESEL FLUSH AND PUMP 55 BBLS @ 20 BPM. 12:23 S/D. FFP = 4,042 PSI, ISIP - 2,184 PSI. MONITOR WHP. 12:38 FINISH MONITORING WHP. FSIP = 1,937 PSI. RDMO DOWELL, LRS AND APC. 14:15 WELL SECURE AND EVERYBODY OFF LOCATION. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $660.00 APC $1,200.00 $2,400.00.. ARCO $~.4~..00 $444.00 DOWELL $107,973.00 $107,973.00 HALLIBURTON $0.00 $2,916.00 LIT-FLE RED $2,040.00 $2~040.00 TOTAL FIELD ESTIMATE $111,657.00 $116,433.00 1. Type of Request: Operation Shutdown Stimulate X Plugging Perforate _ Pull tubing Alter casing Repair well Pull tubing Other 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development X ARCO Alaska. Inc. Exploratory _ RKB 127 feet 3. Address Stratigraphic _ 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service _ Kuparuk River Unit 4. Location of well at surface 8. Well number 744' FSL, 273' FEL, Sec. 19, T11N, R9E, UM 2B-02 At top of productive interval 1037' FNL, 935' FEL, Sec. 30, T11N, R9E, UM 84-122/ ! At effective depth 10. APl number 1203' FNL, 988' FEL, Sec. 30, T11N, R9E, UM 50-029-21 154 At total depth 11. Field/Pool Kuparuk River Field 1267' FNL, 1010' FEL, Sec. 30, T11N, R9E, UM Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured 6976' feet Plugs (measured) true vertical 6 3 2 2' feet Effective depth: measured 685 1 ' feet Junk (measured) true vertical 6 21 6' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 1 0 4' 1 6" 119 Sx CS II 1 0 4' 1 0 4' Surface 2725' 9 5/8" 800 Sx CS III & 2725' 2725' Intermediate 300 Sx CS II Production 6 9 3 3' 7" 280 Sx Class G & 6 9 3 3' 6 2 8 6' Liner 250 Sx CS I Perforation depth: measured 6526'-6568' (C Sand), 6622'-6710' (A Sand) MD true vertical 5943'-5978', 6024'-6098' TVD Tubing (size, grade, and measured depth 3 1/2" J-55 EUE, 9.3 Ib/ft, set @ 6608' Packers and SSSV (type and measured depth) Packers' CAMCO HRP-1SP 6370', BAKER FB-1 6592', OTIS FMX SSSV @ 1884' ~1111 1 0 13. Stimulation or cement squeeze summary ,~, 0- Intervals treated (measured) ~1~ .0~ & GaS C011S, ,, N~ckora~ 6622'-6710' (A Sand) Treatment description including volumes used and final pressure 1500 bbls gelled water, 27,100 lbs of 16/20 Carbo-Lite, final pressure 3990 psi. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 8 4 0 9 2 5 0 1 2 7 5 1 4 8 Subsequent to operation 1 2 2 0 1 7 2 0 0 2 2 0 0 1 1 7 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations X Oil X Gas Suspended Service 17. I here~z,y,~certify that the foregoing is true and correct to the best of my knowledge. STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIOh Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ARCO Alaska, Inc,-.,') Subsidiary of Atlantic Rict~held Compan: WELL SERVICE REPORT WELL 'PBDT REMARKS OPERATION AT REPORT TIME ~o r-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ed~ ' ARCO Alaska, Inc.: Post Office !~^ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 22, 1989 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Attached in triplicate are multiple Applications for Sundry Approvals on the following Kuparuk wells. Well Action Anticipated Start Date 2 B- 0 2 Re-fracture October, 1989 2 B- 03 Re-fracture October, 1989 3 B- 0 6 Add Perfs October, 1 989 If you have any questions, please call me at 265-6840. Sincerely, Smallwood Senior Operations Engineer G BS/J M E :tc Attachments J. Gruber ATe- 1478 J. R. Brandstetter ATe- 11 20 L. L. Perini ATO-1130 KeEl .4-9 w/o attachments RECEIVED s P281989 ,~]aska OJJ & Gas Cons. Commissio . Anchorage ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany "-'-'" STATE Of 0 R 1 6 ! N A L AL~oKA OIL AND GAS CONSERVATION COMM,.....,,ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program_ Operation Shutdown _ Re-enter suspended well_ _ Plugging _ Time extension _ Stimulate ~ Pull tubing _ Variance _ Perforate _ 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 744' FSL, 273' FEL, Sec. 19, T11N, R9E, UM At top of productive interval 1037' FNL, 935' FEL, Sec. 30, T11N, R9E, UM At effective depth 1203' FNL, 988' FEL, Sec. 30, T11N, R9E, UM At total depth 1267' FNL, 1010' FEL, Sec. 30, T11N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 6976' feet Plugs (measured) 6322' feet 6. Datum elevation (DF or KB) RKB 127 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2B-02 9. Permit number 84-12~ 10. APl number 5o-029-21154 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured true vertical Casing Length Structural Conductor 1 0 4' Surface 2 7 2 5' Intermediate Production 6 9 3 3' Liner Perforation depth: measured 6851 ' feet Junk (measured) 621 6' feet Size Cemented 1 6" 119 Sx CS II 9 5/8" 800 Sx CS III & 300 Sx CS II 7" 280 Sx Class G & 250 Sx CS I Measured depth True vertical depth 104' 104' 2725' 2725' 6933' 6286' 6526'-6568' (C Sand), 6622'-6710' (A Sand) MD true vertical 5943'-5978', 6024'-6098' TVD RECEIVED s _P281989 Tubing (size, grade, and measured depth 3 1/2" J-55 EUE, 9.3 Ib/ft, set @ 6608' At ska0il&GasC0ns. C0m...-ssic2 Packers and SSSV (type and measured depth) Anchorage Packers: CAMCO HRP-1SP 6370', BAKER FB-1 6592', OTIS FMX SSSV ~ 1884' 13. Attachments Description summary of proposal _ Detailed operation program X BOP sketch Refrac A Sand with 27,930 lbs of 16/20 mesh carbolite. (Procedure and Wellbore schematic attached). 14. Estimated date for commencing operation I 15. Status of well classification as: October, 1989 J Oil X Gas __ Suspended _ 16. If proposal was verbally approved Name of approver Date approved S e r vi c e Signed17' I he~~)~~t t~~g is true and correct to the best of my knowledge.~TLF[ ~.bc~'%. ~,,, 3'"m~'///~.'.'~ '~itle ~r. operations Engineer Date ~/2~--/~ ~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test_ Subsequent form require ORIGINAL SIGNED BY LONNIE C. SM!TH Approved b~/the order of the Commission Form 10-403 Rev 5/03/89 10- ,xj- C.¢ Commissioner jJAppr°val No.¢~/~,~.... Approved Copy Returned SUBMIT IN TRIPLICATE Messrs S~loan and Ja(~'--'---" Sbptember 7, 1989 Page 4 Kuparuk Well 2B-02 'A' Sand Re-Fracture Procedure Cost Tracking AFE #K80615 1. MIRU Slickline unit. Tag bottom. . Pull CV's at 6407', 6475', and 6575'. Run DV's at 6407', 6475', and 6575'. RDMO slickline unit. If less than 50 feet of rathole is discovered during the pre-frac wireline operations, a CTU cleanout may be required. Consult with Operations Engineering to determine if the CTU is necessary. 3. Perform A Sand only production test followed by an Automatic Echometer PBU. 4. MIRU Slickline unit. . Pull GLV's at 1921', 3471', 4829, and 6317'. Run DV's at 1921', 3471', and 4829'. Circulate 3 1/2" tubing and 7" annulus with diesel. Set DV in GLM at 6317'. Note that a DV is set in GLM at 5856'. 6. Set standing valve in Camco 'D' nipple at 6604' MD-RKB. Pressure test lhe tubing. Pull standing valve. RDMO Slickline unit. 7. RU fracture equipment. Install "Tree Saver". Pressure up 7" annulus to 3500 psi. . Carry out all fluid quality control procedures (Onsite Operations Engineer). Obtain a sample of the proppant and of the gelled diesel with breaker. Check the proppant for fines. Record proppant weight prior to pumping. After the fracture stimulation, verify and record weight of remaining proppant. Obtain samples from pad and slurry stages while pumping. . Pump the 100 Bbl pre-pad at 18 BPM. Shut down and determine the ISIP. The A Sand was perforated with 360 shots, 4 spf, at 120 degree phasing with a DA 4" Jumbo Jet. . Pump fracture treatment per the attached schedule. Record the 2, 5, 10, and 15 minute pressures following the ISIP. Expected wellhead treating pressure: WHTPE = 3425 psig Fracture Gradient = 0.73 psi/ft (6059' TVD) Frac Fluid Gradient = 0.35 psi/ft Tubing Friction = 170 psi/1000 ft @ 18 BPM (6608' MD) * If excessive treating pressures are experienced, try reducing the rate in small increments adjusting additive rates as appropriate. If treating pressure exceeds 6000 psi, begin flush stage. The maximum recommended treating pressure is 6500 psi based on analysis of tubing strength and PBR type. . Rig down fracture stimulation equipment. Follow attached~l;;)~l~ll~~ s P281989 ~. ~.,,.,,., nil ~.,.~r,~.,, & Gas Cons. Anchorage KUPARUK WELL 2B-02 A SAND FRACTURE PUMP SCHEDULE 9/11/89 STAGE FLUID CLEAN VOLUME PUMP RATE PROP. CONC. PROPPANT PROPPANT WT DIRTY VOLUME HIT PERFS DESCRIPTION BBLS BPM PPG DESCRIPTION LBS STG/CUM BBLS 1 GD PRE-PAD 100.0 1 8 0 - - 0 1 00 / 100 58 ............................................. SHUT DOWN FOR ISIP, FLOW METER CALIBRATION ................................................ 2 GDPAD 170.0 18 0 - - 0 170 / 270 158 3 GD w/2 PPG 4.6 18 2 16/20 M CARBO-LITE 386 5 / 275 328 4 GD w/4 PPG 8.5 1 8 4 16/20 M CARBO-LITE 1428 1 0 / 285 333 5 GD w/6 PPG 11.9 1 8 6 16/20 M CARBO-LITE 2989 1 5 / 300 343 6 GD w/7 PPG 15.3 1 8 7 16/20 M CARBO-LITE 4494 20 / 320 358 7 GD w/8 PPG 18.5 1 8 8 16/20 M CARBO-LITE 6210 25 / 345 378 8 GD w/10 PPG 13.9 18 1 0 16/20 M CARBO-LITE 5830 20 / 365 403 9 GD w/12 PPG 13.1 18 1 2 16/20 M CARBO-LITE 6593 20 / 385 423 10 GELLED DIESEL FLUSH 56.0 +SV 1 8 0 - - TOTAL GELLED DIESEL= 411.7 BBLS 27,931 LBS NOTES: The table above represents total job volume. Stages 1 and 2 are Gelled Diesel with 40 lbs/1000 gal silica flour and enough breaker for an 8 hour break. Stages 3 through 9 are Gelled Diesel with enough breaker for an 8 hour break and WITHOUT silica flour. Stage 10 should include a volume adjustment for surface equipment between the wellhead and the densitometer and an 8 hour breaker. Stages 3 through 10 are scheduled to pump at 18 BPM. However, an increase in treating pressure may warrent a decrease in rate or early flush. ~ The job is intentionally underflushed by 2 Bbl. The blender tub should be bypassed at flush. ~ All fluids should be maintained at 70 to 90 degrees F on the surface. ~i The A Sand was perforated with approximately 360 shots (4 jspf). KUPARUK WELL 2B-02 APl #: 500'292115400 SPUD DATE: 08/17/'84 ADL LEASE: 25656 COMPLETION DATE: 10/10/84 PERMIT #: WORKOVER DATE: SURFACE tOCATION: 744'FSL,273'F EL,SEC19,T11N,RgE TOP OF KUPARUK: 1037'FNL,935'FEL,SEC30,T11N,RgE TD LOCATION: 1267,FNL,1010'FEL, SEC30,T11 N,R9E NI depths are MO-I:~B to top of equipment unless otherwise noted ORIGINAL RKB: 127 CASING and TUBING DETAILS SIZE WEIGHT GRADE DEPTH 16" 62.5# H-40 104 9.625" 36# J-55 2725 7' 26# J-55 6933 3.5' 9.38 J-55 6608 TUBING SPOOL: WELLTYPE: PRODUCER LINER DETAILS SIZE WEIGHT GRADE TOP BTM TUBING JEWELRY ITEM TYPE ID DEPTH SSSV OTIS FMX 2.813' 1884 SBR CAMCO OEJ-10 2.973' 6352 PKR CAMCO HRP-lSP 6370 PKR BAKER FB-1 6592 NOGO CAMCO 'D' NIPPLE 2.75' 6604 SHROUT CAMCO 6607 L PAD ELEVATION: 92 STN 1 2 3 4 5 6 7 8 INTERVAL 6526-6568 662~6710 84-122 GAS UFT and FLOW INFORMATION VALVE DEPTH MANDREL SIZE 1921 1.0' 3471 1.0' 4829 1.0' 5856 1.0' 6317 1.0' 6407 1.0' 6475 1.0' 6575 1.0' PERFORATION DATA ZONE FT SPF PHASE C 42 12 120 A 9O 4 120 PORT SIZE · 1875 · 1875 .250 DV .250 FO FO FO COMMENTS DA 5' JUMBO JET DA 4' JUMBO JET MISC, DATA DESCRIPTION KICK OFF POINT: MAX HOLE ANGLE: 39 HOLE ANGLE THRU KUP: 32 LAST TAG DATE: 04/28/87 RATHOLE: ~'"~ I FISH/OBSTRUCTION: PBTD: PBTDSS: DEPTH 6851 6O89 Gas Cons. Anchorage REVISION DATE: 04/28/87 REASON: TAG FILL SUNDRY NOTICE - WELL 2B-02 NO BOP'S WILL BE UTILIZED DURING THIS PROCEDURE. BOTTOM HOLE PRESSURE (6200' SS) = 3000 PSI NO WORKOVER FLUID WILL BE USED DURING THIS PROCESS. RECEIVED SEP2819 9 ~aSl'~. _0it & Gas GODS. Go~ Anchol'age ARCO Alaska, Inc. Post Oflice Box 100360 Anchorage. Alaska 99510-0360 ~0, 276 1215 Telephone o -, DATE' 05-2 9-85 TRAN SM - mm ~, T ~'~n~ NO: 5203 RETURN TO: ARCO ALASKA, INC. KUPARUK OPE RATIONS RECORDS CLERK ATO-11!5B P.O. BOX 100360 Ai~HORAGE, AK 99510 ENGINEERING TRANSMITTED }IERE¥,~IT}[ ARE TIIE FOLLOWING ITEMS. RECEIPT AND RETURiq ONE SIGNED COPY OF THIS TF~AI'SMITTAL. SEQUENCE OF EVENTS PRESSURE DATA · ~2A-3 PBU- ~2A-5 SBHP -2B-i PBU 2B'2 PBU 2B-15 PBU- - 2B-16 PBU 2F-7 PBU- '~' SAND POST FRAC STATE ~_F ~%~9~w-'P B U- STATE 26-!2 PBU- 'A' SAND 2H-15 ISBHP 2W-13 PBU- 'C' SAND 2X-13 PBU POST FRAC 03-16-85 11-21-84 04-01-85 04-02-85 04-09-85 04-10-85 04-14-85 04-20-85 04-13-85 04-11-85 03-23-85 04-10-85 04-21-85 03-30-85 BAKER/ LYNES PRESSURE REPORTS (ONE COPY OF EACH) SET DEPTH lA-1 PBU 04-23-85 7187 ' lA-2 PBU 04-23-85 7476 ' lA-2 PBU 04-23-85 7476 ' lA-5 BUILD-UP 04-23-85 6957 ' lA-6 PBU 04-23-85 8300 ' lA-6 BUiLD-UP 04-23-S5 8300 ' lA-10 BUiLD-UP 04-23-85 8415 ' lA-10 BUILD-UP 04-23-85 8415 ' PLEASE A~,r,~.. OWLEDGE TOOL NO. 1722 1302 1512 1734 1719 2062 1508 1299' .,RECEIPT ACKNOWLEDGED: PAE * CURRIER* M* DRILLING L. 00IINSTON ' MOBIL* NSK CLERK DISTRIBUTION: W. PASHER EXXON PHILLIPS OIL* J. RATHMELL* Dk~a u~, & ~.s Cor,s. Commissio~ Anchorage STATE OF ALASKA* SOHIO* UNION* K.TUL!N/VAULT ARCO Alaska, Inc.,----'-. Post Offi(' x 100360 AnchOrage, Alaska 99510-0360 .... Telephone 907 276 1215 i~:tETURN TO: 'f' !:;..' A N $ fi I ]'TED F.'.:ECE I PT AND .!;'l_-E qlJ EN C E OF ARCO A[.AXI<A, !NC, ATTN' RECORDS CLEF.:I< A'FO-I i t .T.B F',[!,. BOX t00~60 ANCHORA6E, Al< 995t¢ DATE: AF:RIL t9, t98D TRA-NSHITTAI_ h!O' ..,~t-':~'7 F:' A [; !;"',.:.*' .OF 2 · I.IEREWITI-I ARE THE F.OLI_.rJt.,JlN6 ITEM?., PI_EASE.' ACI(NOWLE:DGE RETURN ONE ST. GNED COF'Y OF THI£ TRANSHITTAI.., EVENTS' · FLUID ID F'L!HF' GELLED WATER F'BU FLUID ID STATIC BHF' F'B[J ,=,~ ;1._ 3URVEY FLOWING 'BI'-IP BATCH FRAC 4/2/85 4/f4/85 416-7185 4/6185 4/6185 4/~-5/85 4/5185 4/2/85 :;:ECEIPT ACKNOWLEDGED- ?., CURR:r. ER ';:I--IEVROi',! " DI~-TRzBUTION' DRILLING W., PASHE-R L,. JOHN3TON EXXON MOBIL F'HII_!_ IP~ OIL NSK CLERK J,. RATHHELL ARCO Alaska, Inc. is a Subsidiary of AtlantlcRichfieldCompany RECEIVED APR 2 5 .~985 Al~ka Oil & Gas Cons. Commission ])ATE' __ Anchora~2 ~,r]/1 ATE [! F"' SOH l 0 U N ]: 0 N K. 'rtfL Z i,~,/VAUL T . ARCO Alaska, Inc/-~. Post Offic' x 100360 Anchorage, ,~laska 99510-0360 Telephone 907 276 1215 D A T E ' A'::' I:,.' ]' L. i o T F,~ ;-':', N,ff H ]~ 'i" T A I... NO' ;~!F: ARC;:O fil..A,i'.-.'Kfi., .T.,~: .... AT-i"N: REr_)oRD,.? C.L. ER!( ~-.":', 'F 0 ..- i 'i t .~_,'- [-..' F' Fi 1',, Fi y i ;:~,~-z 6 0 A N F' ..... H Fi I.-.-.: A G E, A t( 9 '"'.;.._.,':'- i 9 E V E". N 'F$ · A C 1( N 0 !,./I... IZ I> G E Ill ' -..,.""- T e T A r":_:_::/.iq 0,4 I_ E D G E I) · 2 U ..r._: ,r.:.: ]; !-'-- "'-' F! N H r; ! ,'.'~' T R '[ RI 1T I F.'.N ' .:.: ...... ! .,. T ! D F,' .,. j.. !....~ i"-! ~ [4 ,--' ' ', .... I ~r",,-, ;'-, ~'rOi, J ?!OEIL F'H ]; !._I_ T. P:? 0 ]21.. , ?- -t' IM.. f'.!Y[< CLE[:,'.I( ,J, F,',-.:, I",I ,.F.I_,_ ARC:O Alaska, Inc. i~a Subsidiary of Allantic~ichfieldCompany !)Ai"E ' ' l ,;'-J ]] FIk.' L.i; ..... l-( ,. 'r [dL. I N .--' '"7 A U I... 1" ARCO Alaska, Inc Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 23, 1985 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Well Completion Reports Dear Mr. Chatterton- Enclosed are Well Completion Reports for the following wells' 2B-1 2B-2 2B-3 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU6/L39 Enclosures RECEIVED APR 2 5 1985 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA --- ALASKA .__ AND GAS CONSERVATION C(, /IISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL E~x GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-122 '31'Address 8. APl Number P, 0. Box 100360, Anchorage, AK 99510 50- 029-21154 . .... 4. Location of well at surface 9. Unit or Lease Name 744' FSL, 273' FEL, Sec.19, T11N, RgE, UM KuParuk River Unit At Top Producing Interval 10. Well Number 1037' FNL, 935' FEL, Sec.30, T11N, R9E, UM 2B-2. . At Total Depth 11. Field and Pool 1267' FNL, 1010' FEL, Sec.30, TllN, RgE, UM Kuparuk River Field ,. 5'. Eievation in feet (inc~icate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 126' RKB[ ADL 25656 ALK 2582 ' , 12. Date spudded ' 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 08/17/84 08/22/84 10/10/84 N/A feet MSL 1 . 17. T°talD'epth(~D+TVD) 18.PlugBackDepth(MD+TVD) 19. Directional Survey i 20.'6epthwhereSSSV-set 121. Thickness of Permafr0st 6976'MD,6322'TVD 6851'MD,6216'TVD YES (~ NO [] 1891 feet MD 1450' (Approx) :22. Type Electric or Other Logs Run DI L/SFL/GR/SP~ Cal/FDC/CN..L, Gyr0, CBL/VDL/GR/CCL/JB, CCL/Temp: Log. .. _._ 23. CASING, LINER AND CEMENTING RECORD · , SETTING DEPTH MD CASING SIZE!WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNTPU. LLED .. 16" 62.5# H-40 Surf 103' .. 24", 119 sx Cold Set II ... , , 9.-5/8" 36.0# J-55 S. urf 2725' 12-1/4" ~00 sx Cold Set III & ~.00 sx Cold Set II 7" 26.0# J-55 Surf 6933' 8-1/2" 2~0 sx Class G & 250 s~ Cold Set I · · ,, 24. Perforations open to Production (MD+TgD of ToP and Bottom and 25. TUBING R. ECOR .1~ interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 6622' - 6710' w/ 4 spf, 120° phasing 3-1/2" .. 6608' 6592' & ~77' 6526, - 6568, w/12 spf, 120° phasing _ 26. 'ACID, FRA'CTURE, CEMENT SQUEEZE, ETC. , DEPTH INTERVAL (MD) 'AM~)UNT& KINDOF MATEI~IALUSED· , . 6586' - 6588' 42 bbls Class G ...... 27. N/A PRODUCTION TEST _ , - Date First Production 1 Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested' pRoDuCTION FOR el L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~ Flew'Tubing casing Pre~sure 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. NONE ..... Form 10-407 GRUS/WC45 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate ., ':- -" -:[ .:::. :i! ~EOL'O'Gi'~'I~ARKEi~' !':~'~;':'' ";~-'" '~ ' ': i i";:" ;"-t i:: '-' "" '' ': :" :: : i'.' '.'-" "" "'v :', · ..- .. FO. Ri~ATiON TESTS -. , NAME Include interval tested, pressure data, all fluids recovered and graviiy, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. ,.. To'p Upper Sand 6525' 5941' N/A Base Upper Sand 6569' 5978' Top Lower Sand .-6610' 6013' Base Lower Sand 6774' 6151' - .. : 31. LIST OF ATTACHMENTS A_ddend,_,m_ ' : . ., ;32. I hereby cer~'!fy.that the.foregoing is true and correct to the best of my knowledge Signed & ~ ~)~JJ/)~._.Jt~' Title Ass°ciate Engineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in A!aska. 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 2~ 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 ~nterval 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- lng 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". I:: n rrn I ADDENDUM WELL: 2B-2 8/27/84 9/18/84 3/12/85 Arcitc Pak w/250 sx CS I, followed by 53 bbls Arctic Pak. Rn CBL/VDL/GR/CCL/JB f/6836'-5486'. Rn gyro f/6851'-surf. Frac in 8 stages w/333 bbls gelled diesel, 1000# 100 mesh & 14,600# 12/40 mesh. Log well w/CCL & temp ti f/6750'-6500'. Driliing ~Superintendent R ECE~ FrL-"_ D Alaska Oil & Gas Cons, Commission At}cboraoe ARC° Oil and Gas Company Well History - Initial Report - Dally Pmp~ and submit the "Initial Rel~erl" on the first Wednesday after a well is spudded or workover operations are at~rted. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field Kuparuk River Auth. or W.O, no. AFE 104949 ]~un~, ~ri~ or ~rough North Slope Borough ILeaseorUnit ADL 25656 JTItle Drl, Complete & Perforate IState Alaska JWell no. DS 2B-2 NABORS 26-E AP1 50-029-21154 Operator ARCO Alaska, Inc. IARCO W I. 56 .24% IPrior status if a W.O. Spudded or W.O. begun IDate Spudded Date and depth as of 8:00 a.m. 8/16/84 8/17/84 8/18/84 thru 8/20/84 8/21/84 Complete record for each day reported I Hour 8/17/84 0001 Hrs. 16" @ 103' Moving rig. 16" @ 103' 990', (880'), Drlg Wt. 8.8, PV 100, YP 32, PH 10.5, WL N/A, Sol 7 Accept rig @ 1800 hrs, 8/16/84. NU diverter sys. 8/17/84. Drl 12¼" hole to 990'. Spud well @ 0001 hrs, 9-5/8" @ 2727' 5650', (4660'), Navi-Drl Wt. 9.3, PV 14, YP 12, PH 10.0, WL 10.1, Sol 6 Drl 12¼" hole to 2740', 13 std short trip, POH. RU & rn 68 jts, 9-5/8", 36#, J-55 HF-ERW w/FC @ 2644', FS @ 2725'. Cmt w/800 sx CS III, followed by 300 sx CS II. Displ using rig pmp, bump plug. CIP @ 0035 hrs 8/18/84. ND diverter, NU &tst BOPE. RIH w/8½" BHA to 26~4', tst csg to 1500 psi. DO cmt, FC, FS + 10' new formation. Conduct leak-off tst to 13.5 ppg EMW. 2915' 3260' 3668' 4110' 4735' 5425' Drl & surv 8½" hole to 5650'. , 4.6°, S8E, 2914.57 TVD, 10.12, 13.17S, 4.54E , 17.3°, S1W, 3252.32 TVD, 72.36, 81.02S, 3.39E , 24-1/4°, S29W, 3630.02 TVD, 223.57, 223.63S, 48.25W , 39-1/4°, S28W, 4003.14 TVD, 457.17, 428.10S, 162.94W , 37.5°, S28W, 4485.52 TVD, 852.84, 773.11S, 360.16W , 39.25°, S12W, 5036.70 TVD, 1266.24, 1158.84S, 510.64W 9-5/8" @ 2727' 6690', (1040'), Drlg w/Bit #4 Wt. 10, PV 12, YP 6, PH 10.5, WL 6.0, Sol 12 Navi-Drl & surv to 6690'. 5676'MD 38-1/4° S12W 5232'TVD 1420'VS 6083'MD 35-3/4° S20W 5557'TVD 1662'VS 6456'MD 33-1/2° S18W 5864'TVD 1873'VS S1313' 543'W S1548' 611'W S1748' 680'W RECEIVED DEC 0 Alaska Oil & 6as Cons. Commission Anchorage The above la correct Signature Date I Title 9/05/84 Drilling Superintendent -. ARCO Oiland Gas Company ~, Daily Well History--Interim Instrucll~nl: This form I$ used during drilling or workover, operatlons. If testlng, coring, or perforating, Ihow formation name in describing work performed. Number all drill stem teats sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lntlrlet" sheell IJntll final completion. Report official or representative test on "Finli" form. 1) Submit -Interim" sheete when filled out but not les~ Irequently than every 30 deye, or (2) on Wednelday of the week In which oil string I$ eel Submit weekly for workoverl and following setting of oil strln§ until completion. District ICounty or Parish I Slate m.,d Alaska IL.ase or U, it North Slope Borough I Complete record for each day while drilling or workover in progress Date and deptl~ as of 8:00 a.m. 8/22/84 8/23/84 9-5/8" @ 2727' 6941' ' , (251), TIH Wt. 10, PV 16, YP 10, PH 10.0, WL 6.0, Sol 12 Drl 8½" hole to 6941', 30 std short trip, C&C mud to rn logs, POOH. RU Schl, log DIL/SFL/GR/CAL/FDC/CNL, unable to wk tool thru tight hole @ 4094'. POOH & add rollers to tool, RIH, unable to work thru tight spot @ 4094, POOH, RD Schl. TIH to 9-5/8" shoe @ 2727'. 6881', 32°, S21°W, 6222' TVD, 2102 VS, 1965S, 757W 9-5/8" @ 2727' 6976', (35'), Rng 7" Csg Wt. 10, PV 16, YP 10, PH 11.0, WL 6.0, Sol 14 Fin TIH & wsh to btm @ 6941', C&C mud f/logs, POOH. RU Schl, log DIL/SFL/SP/GR f/6926'-2729' & CAL/FDC/CNL f/6900'-5500', RD Schl. TIH, drl f/6941'-6976', C&C mud to rn 7" csg, POH. RU to rn 7" csg. The above ia correct For torm ~moaration anOt~diatribution see Procedures Manual ~ction 10, Drilling, Pagee 86 and 87 JDale ITitle 9105184 Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report I~tlln~clio~e: Prepare and submit the "Final R~rt" on the first Wednesday after allowable has been assigned or well ia Plugged, Abandoned, or Sold. "Flail Rel~e~t" should be submitted also when operatione are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative felt data in blocks provided. The "Final Rel~ert" form may be used for reporting the entire operation if space is available. Accounting cost center code ICounty or Parish North Slope Borough Lease or Unit ADL 25656 Title Drl, Complete & Perforate District Alaska Field Kuparuk River Auth. or W.O. no. AFE 104949 NABORS 26-E Operator I A.R.Co. ARCO Alaska, Inc. Spudded or W.O. begun I Date I Spudded Date and depth as of 8:00 a.m. 2000 Hrs. Old TD Released rig API 50-029-21154 State Alaska Well no. DS 2B-2 8/24/84 Classifications (oil. gas, etc.) Oil Complete record for each day reported W.I. 56.24% 8/17/84 Iotal number of wells (active or inactive) on this i est center prior to plugging and ~ bandonment of this well I our I Prior status If a W.O. I 0001 Hrs. 7" @ 6933' 6851' PBTD, RR Wt. 10 NaC1 br Rn 175 its + 4 pups 7", 26#, J-55 ERW BTC csg w/top marker @ 6503', btm @ 6621', FC @ 6851', FS @ 6933'. M&P 280 sx Class G cmt w/3% KCL, .7% D-19, .7% D-31 & 1% D-6. Displ w/252 bbls, 10.1NaC1/NaBr brine, bump plug. CIP @ 1220 hrs. ND BOPE, instl pack-off & tbg spool. Tst 7" pkoff & I1" flange to 3000 psi. RR @ 2000 hrs, 8/23/84. Operations suspended - wait on completion rig. RECEIVED 0 ^laska 0ii & ~as Cons. Commission Anchorage INew TD I PB Depth 6976' (8/22/84) IKindOfrig 6851' IDate 8/23/84 Rotary IType completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands Producing method Flowing Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature For form preparation d distribution, aM I~r~.AdurA~ Manual. Section 10. IDate j TItle 9/05/84 Drilling Superintendent ADDENDUM WELL: 2B-2 8/27/84 9/18/84 Arctic Pak w/250 sx CS I, followed by 53 bbls Arctic Pak. Rn CBL/VDL/GR/CCL/JB f/6836'-5486'. Rn gyro f/6851'-surf. Drilling Superintendent Date AtlanticRichflel~ny ~ Dally Well History-Initial Report Prepare and submit the ~J~ on the IIiTI Wedneldly Iftar I well il spudded or wortcover operellOnl Ire itirted. Dally wow prior to Ipudd~ll ~ bt ~ummarlzed on the form giving inClulive datal only. District Field County or Perll~ Islate Alaska Alaska North Slope Borough Lease or Unit IWell no. Kuparuk River ADL 25656 2B-2 Auth. or W.O. no. ITitle AFE 104949 I Completion Roll'N t/4 API 50-029-21154 Operator I A.R.Co's W.I. ARCO Alaska, Inc. I 56.24% s,udde, or w.o. ~,gun IDa,. I.our [,,or,tatu, i', W.O. Complete 10/03/84 1800 hrs Date end depth as of 8:00 a.m. lO/Ol/84 10/02/84 10/03/84 10104184 10/05/84 10/06/84 thru 10/08/84 Complete record for each day repo~ted 7" @ 6933' 6851' PBTD 10.1 ppg NaCl/NaBr Standby w/crews - wait on weather. 7" @ 6933' 6851' PBTD 10.1 ppg NaC1/NaBr Standby w/crews - wait on weather. 7" @ 6933' 6851' PBTD 10.! ppg NaC1/NaBr Standby w/crews - wait on weather to move to 2B-3. 7" @ 6933' 6851' PBTD, POOH 10.1 ppg NaC1/NaBr Accept ri~ @ 1800 hrs, 10/3/84. ND tree, NU & tst BOPE to 3000 psi. RU DA, tst lub, RIH w/4" perf gun, perf 6588'-6586' @ 4 SPF. 120° phasing. TIH w/cmt retnr & set @ 6440', POH. 7" @ 6933' 6831' PBTD, TIH 10.1 ppg NaC1/NaBr TIH w/stinger, rev circ cmt debris out of DP, tag up @ 6433'. Att to stab into retnr w/o success, TOH. PU drlg BHA, TIH to DO cmt debris & retnr. 7" @ 6933' 6836' PBTD, POOH 10.1 ppg NaCl/NaBr TIH, DO retnr @ 6437', CO to PBTD, circ hole cln (accum fluid loss 38 bbls), POOH. TIH w/new cmt retnr, set @ 6408'. Sting into retnr, est IR @ 3 BPM/2000 psi, hesitate sqz w/42 bbls cmt. Displ cmt w/10.1 ppg brine. CIP @ 0815 hrs, 10/6/84. TIH w/BHA, tag hard cmt@ 6333', DO cmt& retnr. Tst csg to 1500 psi/15 min; OK. Circ, wsh out fill to 6836' until hole cln, POOH. TIH w/7" csg scrprs, displ hole to 10.1NaC1/NaBr, POOH, LD DP. RECEIVED I-' AJaska 0il & Gas Cons. CommJssic Anchorage The above ia correct P~'A Signature For form preparation and di~r~ution, sea Procedures Manual, Sectlo~n 10, Drilling, Pages 86 and 87. IData [ Title 11/d2/84 Drilling Superintendent Number all dally well history forms consecutively as they ~re prepared tor each wall. i Pag~ no. - . L ARCO 011 and Gas Company Daily Well History--Interim I,Itllictl~lll: This form is used during drllllhg or workovlr operations. If lasting, coring, or perforating, show formslion name in dascribing work parlormed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Seclion will be reported on "lnlerlm" sheell until linll completion. Report official or ~pre~,lntlflve lest on -Final" form. 1} Submit "lnllrlm" sheels when filled out bul nol leis fraquanlly Ihan avery 30 days. or (2) on Wednesday of the week in which oil string ia slt.-Submit weekly for workovers and Iollowing setting of oil siring unlil completion. District Field Alaska Kuparuk River County or Parish North Slope Borough ADL 25656 IStale Alaska IWall no. 2B-2 Date and depth as of 8:00 a.m. 10/09/84 10/10/84 Complete record for each day while drilling or workover in progress 7" @ 6933' 6836' PBTD, Rng 3½" tbg 10.1 ppg NaC1/NaBr Perf 6622'-6710' @ 4 SPF/120° phasing & 6526'-6568' @ 12 SPF/120° phasing. PU 6.125" gage ring/JB, TIH to 6880', TOH. TIH w/FB-1WL perm pkr, set @ 6592', TOH. RU to rn 3½" compl string. 7" @ 6933' 6836' PBTD, Prep to RR 10.1 ppg NaC1/NaBr Fin rn'g 209 jts, 3½", J-55 EUE 8RD CA & lnd FMX SSSV @ 1891' w/HRP-I-SP retrv pkr @ 6377', FB-1 perm pkr @ 6592', "D" Nipple @ 6604', Shear sub @ 6608' Circ. 30 BBL diesel followed by crude. Set .BPV, ND BOPE, NU & tst tree to 5000 psi. GLM's: 6582', 6483', 6414', 6325', 5864', 4837', 3478', 1929' The above is correct ~ ~--,~. Signature For form preparalion andj~lislribution see Procedures Manual ~ction 10. Drilling, Pages 86 and 87 Date mT~,e ~/02/84 Drilling Superintendent A FI.'IR-4RCI-~-R Number all daily well hislory forms conseCullvely as Ihey are prepared for each well. IPagsn° ARCO Oil and Gas Company Daily Well History-Final Report Inetrucliona: Prepare and submit ~!~1~1'1" on ~'ll--flret Wednesday after allowable has been assigned or well is Plugged. Abandoned. or Sold. "Final Rel~orl" should be eubmfttt~l--tli~.~ll~l~l~l~l I~, ,uspencled for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, re, port ~1~1~_ _~ IIl~l'lllfl~lt!ve test data in blocks provided. The "Finll Report" form may be used for reporhng the entire operation if space is available ~---~'~'~"~-' - ' Spudded or W.O. begun Complete I Accounling coat center code District County or Parish I SI,la Lease I Aiaska Alaska North Slope Borough Field or Unit Well no. Kuparuk River ADL 25656 2B-2 Auth. Or W.O. no. T t e AFE 104949 Completion Roll'N (t4 API 50-029-21154 Operator A R.Co. W.I. [Total number of w311s (active or inactive) on th~s ARCO Alaska, Inc. 56.24% Icost center prior to plugging and J abandonment of this well Oats JHour [Prior st,ia, if a W.O. 10/03/84 1800 hfs Complete record for each day reported 10/11/84 Date and depth as of 8:00 a.m. 7" @ 6933' 6836' PBTD, RR Diesel in tbg/crude in ann Set BPV. RR @ 0800 hr,, 10/10/84. Old TD Released rig 0800 hrs Classifications ~oil. gas. etc.) 0il RECk IV EUr°ducing meth°d Flowing INew TO IPS Oep,~ 6836 ' PBTD Date J Kind of rig 10/10/84 Rotary Type completion (single. dual, etc.) Single Official reservoir name(s) Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production \ Oil on test Gas per day ~mission Puml~ size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected bEC 0 Alaska 0il & Gas Cons, Co~ Anch0racje The above is correct Signature~ -,- -- IDate ITitle ~.~..~ 11/02/84 Drilling Superintendent For form preparation and/distribution. see Procedures Manual. Section 10, Drilling. Pages 86 and 87. AR3B-459-3-C INumber all daily well history forms consecutively I Page no. as they are prepared for each well. I 3 DlvlIIMI M Al~intlcRIchfb~Qml)eny ARco Alaska, inc.,' Post Office c.,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 t I'::--. t t -/ i (;)-.- ? ~ .... t.(;!--. ', o · ' ::! n .... :7 ;.:'~ .... f ;:.'.B.-- 2 ~/ ,:..P .... t ;::': D-.- ,'.":, ... ... ,{:, ~ ""(; :" c/ ;:. '"' '" C; ..... t '') ..¢.. ~jl' ""...- ;;.: i-~.- o '-.? {4 .-- ~ 0 '"H .... :~ i K.. .... L.J .-i · ..:...--~ · ::::x .... i 7:-; ,'g 4 -' 0 i c:, ~ · . . ~- ~..! '(:[.N:[T]:.AL) 04 .... 04 .... ,9,.5' I'"'):':'.U : · 'O::~ .... 0i .... ,? .T.:: I Il':' 0 4 ---0 2-' ,?.'~ Fi F' ..r:.~ U. " ." '- 0..'7, -" 1 9 -': S 5 - F" I:: !.1 0 B -" 2 i .... (::::5 F:' i~:11 0,7 - 2 3 '- '" ':'" ...... (-, ..? ,?P.t IF' ' ......0 3 '"'; ""'::' ..... '" k.: ~ .... (.:'.,.>. I--' }:'. I I' ;; 'r N I '" :': :"- - ,= ' E,"..'"'; .... ~ .I. ,..~1... ) 0'~--2,':,-..- F:. t_-,, i 0 73...o ~-.,. ,,,,::- .L' t. ..- ~-: "' C) ..;' F' !';U 0 7,'-' 0 ,", <:: .; F:' I:: U 0 ~ "- 0 .a. -.. ,:>:', ..~'-'-' F" ..... t",l I -- ' - "?',, 7 -- ~:.:° "-U'" ...."'" .. I::' P, U C-..,'z -- 75,':~ ";'::' .... · ..., . ,Y .... C) ...> (; 1:.". ,. A C K ~..! (-I H L. I:: :9 .'5 E: ,, -. l/ .i- e.;. / t '~ .I..,..' U-~ I .i.t. I' · ~'"- ~" ';' I.." ~' ~'-! ::; LI '"" ..... I" ~--~..:. I lie F;: , I .,"i L-!,'-~ ~'i' r-~ i..! E ;,-", )-:' f'l N J. i i i '.l~- i .... i '% % .. :.: ¢', T:, ':' ~ :,'. ':':' t [ 'r i I T r.:, ~-' f'j 1' I .',,:. .,.I · '.^:|-. · ,L '. "~.. , J.~ .... ~. ,~ h!;.:.'k'. F" r",';.~¢ ,j , ...... ," ~i.-.:r", .. ' L. ~.-~ . I',l , ,. . ,.: !...j... ..5 J r l I ,:,. ," ,... l"; - S' ()j-'J J7 [) ':: . . L.I h! ]: 0 :,'-!..",-: ........ I/ '"1" I I I '~' '' J 'I Il t " f I ' "ti' Ik, ,~ , ...'1 ..... : . · ... I ARCO Alaska, in,"' Post Office ...ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Date: 1/23/85 Transmittal No: 4925 RETURN TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 / Transmitted herewith are the following items. Please acknowledge receipt /~nd return one signed copy of this transmittal. BHP REPORTS & SEQUENCE OF EVENTS 2B-l~~> 10/16/84' "Static" SBHP lB-3 ~ ~'~' ,6/26/84 2B-i~ .... 10/17/84 " " 1B-4A~ ~..6/26/84 2B-2~ .... 10/17/84 " " lB-6 Y .~ 7/01/84 2B-6f- ........6/02/84 " 1E-2 ~ .... ~ 6/22/84 2B-10~ 6/02/84 " 1E-7 % '-~' 8/14/84 2B-11~- 6/03/84 " 1E-4 ~-- 10/15/84 2B-12~ 6/02/84 " 1E-12 ~.~ 6/24/84 2B-14~-- 10/28/84 " " 1E-20~~ 6/23,22/84 2B-13y~ 10/28/84 " " 1E-22~ ~ 4/23/84 2D-5-A'~ 10/05/84v " "' 1E-25~.~ 6/23/84 2G-l~- - 9/21/84 "Static/G. Ring" 1E-25~ 11/09/84 2G-2 ~'~ 9/22/84 " " 1E-29-~"- 6/23/84 2G-3 .~ 9/23/84 " " 1E-29} 10/14/84 2G-4 ~ 9/23/84~ " " 1F-4 ~ 9/14/84 2G-8 %~- 9/30/84 2F-15~--~ 4/13/84 2X-13~,'12/18/84 2X-14F 12/21/84 2X-15¥~12/23/84 2X-16~ ~'12/21/84 1F-4 ~-" 9/14/84 1F-7'~ '" 7/05/84 1F-11~~ 4/.25/84 1F-14~~ 2/07/84 1F-15~ 2/14/84 10-1, ..... 6/29/84 ¢iG-i~ ~ 9/13/84 ZIG-3'..--~ 5/16/84 ~lG-5'- 6/29/84 1H-4~~ 6/24/84 1Y-3~- 1/21/84 1Y-5~ 5/06/84 1Y-9~'~- 5/06/84 .1G-14.--' 1/12/84 Receipt Acknowledged: "Static/G. Ring/Tagh SBHP 1L-2~? 10/21/84 iL-3 -6~ Date: DISTRIBUTION B. Currier Drilling W, Pasher BPAE Geology Chevron Mobil G. Phillips Phillips Oil D & M NSK Ops. J. Rathmell SBHP " "Static" " "Static" ,! ,1 II II II I! 11 ' II 11 " "Static" II Il 11 II I, II I, II II II II ,I Il Sohio ~ -~, ~. ~... -~.~. Well Files ARCO Alaska, Inc. ?--.~ Post Office' 360 Anchorage," ,..,aska 99510 Telephone 907 277 5637 Dace: 11/27/84 Transmittal No: 4868 R~TURN TO: ARCO ALASKA, INC. ~ ATTN: Records Clerk ATO-1115B P.O. Box 100360 T~ransAnChorage, AK 99510 mi,ted herewith, are the following items. Please acknowledge receipt and return one signed copy of this transmittal. CBL's/Schlumberger/FINALS "Variable Density" "GCT/JB/GA" 9/19/84 " " " 9/31/84 ,I I, ,, ,, ,! I, ,, ,, ,, ,I ,, 1, ,! ,, ,! ,, ,, ,, ,, ,, 11 1, ,1 ,, .- 11 ,1 o. ,! 11 ,1 ,I ,! 1, If Il ,I 11 Il 11 It II II II 11 Il II II "GCT" 10/07/84 " "GCT" 10/07/84 " "GCT/JB/GA" 9/31/84 " "GCT/JB/Ring 9/17/84 " "GA/JB/GCT" 9/19/84 " " 9/17/84 " "GCT" 7/21/84/ " "GCT" 9/21/84 " "scr/oA/~" .9/14/84 " " ~/15/84 " · '!seT/JO" lO/12/84 " " 10/15/84 " " lO/Z2/84 " ". 10/13/84 " "GCT/~/OA" 10/22/84 " " 10/22/84 " "n/CA" 8/19/84 " " 8/2o/84 Run 3 9/21/84 Hun 1 "GCT/JB" 10/14/84 Run 1 " 10/14/84 " " lO/O5/84 " "GCT" 10/05/84 " "Perf 4"a 9/10/84 Run 2 5 l/2"/P?S/~" 11/05/84 Run 1 Acoustic "VDL/Signature/GR" /cat Receipt Acknowledged: DISTRIBUTION 6597 - 8292 P'2B-3/ 7000 - 8460 J2B-16~ 4950 - 7004 a~2B-13vz 5750 - 8408 -~2B-14 ~ 5700 - 7970 '~2B-15/ 5348 - 6824 ~2B-2 ~ 7250 - 9182 -~2B-4 ~ 5055 - 6487 --2B-l~ 6200 - 7866 ~2D-5~' 6800 - 8954 --2D-6 ~ 5054 - 6650 ~2Df7/ 5597 - 8084 --'2D-'8°~/ 5650 - 7951 ~2G-9~ 5840 - 8524 --2G-11~ 4940 - 6765 ~2G-10~ 5730 - 7950 --2G-12~ 5790 - 7814- 2G-13~ 5989 - 8624 -2G-14~ 8650 - 9334 ~F-6~/ 8650 - 9562 ~lF-6~ 5692 - 6742 ~lY-5~/~ 5150 - 7252 ~ 1L-1/ 4500 - 6550 JlL-2~ 6800 - 7518 ~L-4~/. 7000 - 8210 --1L-3~/ 7961 - 8941 --2V-8A 6100 - 6992 ~1E-24 B. Currier BPAE Chevron Drilling W. Pasher Oeology'..~~L.~ O. Phillips Mobil Phillips Oil · :' Sohio Union D&M NSK Ops. J. Rathmeli Well Files ARCO Alaska, Ir Post Offic= ~Jox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 November 28, 1984 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2B-2 Dear Mr. Chatterton' Enclosed are the Well Completion Report and the gyroscopic survey for the subject well. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU2/L113 Enclosures RECEIVED DEC Alaska Oil & Gas Cons. Cmmmission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ..... STATE OF ALASKA .-- .---.. ' ALASN. ' ~,._ AND GAS CONSERVATION. . IlSSION ' WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~(× GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-122 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21154 4. Location of well at surface 9. Unit or Lease Name 744' FSL, 273' FEL, Sec.19, T11N, R9E, UM LOCATiONSi Kuparuk River Unit At Top Producing Interval VERIFIED ~ 10. Well Number 1037' FNL, 935' FEL, Sec.30, TllN, R9E, UM .Surl:. ~ 2B-2 J At Total Depth B.H. ~-~ 11. Field and Pool 1267' FNL, 1010' FEL, Sec.30, T11N, R9E, UM -- Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 126' RKB ADL 25656 ALK 2582 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. 15. Water Depth, if offshore 116' No. of Completions 08/17/84 08/22/84 ,: . · :,10/10/84 N/A feet MSL[ 1 17. Total Depth (MD+TVD) 18. PIugBaCkDepth(MD+TVD) 19. DirectionaISurvey 20. Depth where SSSV set I 21. Thickness of Permafrost 6976'MD,6~22'TVD 6851 'MD,6216'TVD YES [] NO [] 1891 feet MDI 1450' (Approx) 22. Type Electric or Other Logs Run · DIL/SFL/GR/SP, Cal/FDC/CNL, Gyro, CBL/VDL/GR/CCL/JB 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 103' 24" 119 sx Cold Set II 9-5/8" 36.0# J-55 Surf 2725' 12-1/4" 800 sx Cold Set Ill & ]00 sx Cold Set II 7" 26.0# J-55 Surf 6933' 8-1/2" 280 sx Class G & 250 s~ Cold Set I 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) 6622' - 6710' w/ 4 spf, 120° phasing 3-1/2" 6608' 6592' & 6377' 6526' - 6568' w/12 spf, 120° phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 6586' - 6588' 42 bbls Class G 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I , Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (c~r~) 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. NONE RECEIVED DEC o Alaska Oil & Gas Cons. Commission Anchorage Form 10-407 GRU2/WC13 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. . ~. ? .. , 30 ..... ~' GEOLOGic MARKERs .... FORMATION TESTS '" · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 6525' 5941' N/A Base Upper Sand 6569' 5978' Top Lower Sand 6610' 6013' Base Lower Sand 6774' 6151' .. 31. LIST OF ATTACHMENTS Well History (incl.dinn addend.m). Workover Well History. Cvroseonic Survey (2 conies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed i ~' ' Title Area Drilling Engr.. Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt' water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for 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- lng 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". $ UB-S URFA CE DIRECTIONAL SURVEY F~ UIDANCE ~ONTINUOUS I-fi OOl Company Well Name Field/Location ATLANTIC RICHFIELD COMPANY 2R-2 (74a' F_~t, 273' FF[, Slg, TllN, I~cJE, UM- -. KIJPARUK, NORTH SLOPE', ALASKA -_ Job Reference No. 69536 L. ogged By: BAUMEISTER RECEIVED DEC 0 ~ 19~$~ Alaska Oil & Gas Cons. Commission Anchorage Date OCT 2, 1984 Computed By: S. STEVENS GCT D.~I~t~iCT]C)NAL ,SURVEY F[.!R ARC[] A L, ASI," A, 2 [.~ -2 KI,IPARL!K $tlRVEY DAT~.: 17-SEP-84 ErlG] NF':EI~: I-'3 A U M E [ S'I.' VR ARCO ALASKA, TNC. 28-2 KUPARUK NORTH SLOPE~ AI, ASKA COr.~Pi. iTATTON DATE: 3-0C]'-84 T R U E S U B - S g A C 0 U R ,$ MEASUR£D VERTICAL VERT]'CA[, UEVIATIUh AZINUTH PAGE DATE nF' ,SURVEY: 17-SE;P-B4 Kt~JI.,I...Y [~!,!,SF!.[NG ELEVAT1UN: 126.00 EF.!C;]'NEE[~: BA.UMEISTER IH'rEFPf)LATF[) VAI..,UE:S FOR EVEN 100 FEE',T VERTICAL L~(~(;l~k',C; Rh;CTAr~GU[,AR C[)~RDINATES HOHIZ, DEPARTURE GECTIC]N SEVKRITY N[1RTH/SO~!TH EASI"/WEST DIGT, AZIMUTH O E P T H [) E P T H r) E P T H 0.00 0,00 -126,00 (') 0 N 0 0 E'. lO0~O0 100,00 -26.00 0 10 I"~ 32 2 W 200,00 200 oo 74,00 0 24 300.00 300;00 174,()0 0 22 $ 88 21 w ,~00~,00 399 99 273.9, 0 13 ;': 79 22 ~ ,00 499~,99 373.g9 011 N 8342 W 600.00 599.99 473,99 0 11 ~, 78 35 ~ 700800,00 699~;99 573.99 0 4 N 76 2 W 900,00 79999 673.99 0 2 N 5350 ,00 89999 773,99 (.)3 N 5641 W ~000,00 999,99 873.99 0 0 N 6436 W 1100,00 1099,99 973.99 0 20 .$ 39 25 I< 1200 ,00 1199.99 1073,99 0 19 0,00 1299,99 1173 q9 ~iSO.OO 1399.99 1273:99 O 7 S 55 6 g t5 00,00 1499,99 1373.99 600,00 1599.99 1473.99 026 S 4720 E 700,00 1699 98 1573,g8 '800.00 1799;97 1673.97 0 46 $ 40 58 F. 1900,00 1899,96 17'13,96 O 44 S 3238 E 000,00 1~99,96 1873,9b 043 ,,oo.oo o 00,"00 2299,89 2173.89 1 39 S 38 11 E 2400,00 2399 83 2273.83 2 ] S 35 26 E 2500,00 2499:76 2373.76 2 23 $ 37 39 Fi 2600,00 2599,67 2473.67 2 30 $ 3542 E 2800,00 2?99,47 2673.47 2 20 290000 . ':~'2'~:g'9 ,:,:372773,37 3 1 3 $ 13 4 E ]000,00 '}~.~:~8i4 2872.84 8 27 3200. ~m~ 3068.36 13 49 O0 31~4.b'1 17 54 3300, ; ' 3258.78 20 .~9 3400, 3500,00 21 '352,21 3600. :"' ~ ' 10 3445.10 22 34 F E F: T [) k: (; / ] 00 F F: E T F E g'f F g E T D E G M I N 0,00 0 O0 0.00 -0,07 0:38 O, 10 0.05 U,O4 0,21 0,45 0,10 0.07 0,67 0,34 0,11 0,75 0,04 O, 17 0,85 0,12 0.23 0.90 0,15 0.28 0,9¢) 0 05 0.31 0.80 0:11 0,3'/ 0,87 0.16 0.40 1,01 0,27 0,1'1 1.23 0,15 0,2b 1.3(.) (),42 0,54 1.35 0,1.7 0,71 1,42 0 37 0,89 1.63 O' ,lO 1,33 1.90 t).06 1,93 2,30 0,23 2,75 2,94 0,14 3,84 .],62 0,06 4,9~ 4.38 0,60 6,09 5.41 0,34 7,77 6,63 0,29 9,89 8,16 O,b4 12,46 10.03 0,05 15.65 12.00 0,17 19 09 14.25 0.26 22:75 16.32 0.21 2h 22 18.91 4.65 30:04 28.33 6.11 39,66 47.43 2.13 57.71 69.62 2.21 79.75 95,64 5,16 1(.)~, 09 128,70 3.77 138.93 lh4,26 2.~1 172.20 201.23 2.40 2o5.15 241 .60 3,23 24C', 48 287.68 3,19 339,77 5.11 0,00 0,07 0,56 1.23 1,84 2,16..W 2,51.~ 2,75 2,~2 2,90 2,93 'W 279 w 2:36W 1.93 .W 1,68 W 1,47 W 1,00"~ 0,35 ~ 0,47 E 1,30 E 0,00 N 0 0 g 0,12 N 32 53 W 0,60 N 69 34 W 1,24 N 86 31W 1,84 N 8625 W 2,16 N 85 22 W 2,52 N 8450 w 2,76 N 84 13 W 2,8] N 83 39 W ) 2,93 N 82 48 W 2,96 N 8216 W 2,79 N 8626 W 2,38 S 8341 W 2,00 $ 7419 W 1,82 $ 67 8 W , '11 8 58 49 W ,67 $ 36 58 W 1,96 $ 10 25 W 2,79 $ 9 40 E 4,06 $ 18 42 E , 98 g 5,29 $ 21 58 E .72 E. 6,67 S 24 5 g 3,92 g 8,70 $ 2645 g 5,58'E 11,36 $ 29 26 E 7,50 'E 14,54 $ 31 2 E 9,93 E 18,54 S 32 23 E 12,53,.E 22,83 S 33 17 E 15,23 E 27,38 S 33 48 E 17,79 F 3168 S 34 9 g 19,88 E 36:02 $ 33 29 E 18,26 g 43,66 S 24 43 E 11,77 'g 58.90 $ 1131 g 6,56 El 80,02 S 441 E 1,54'"E 106,11 $ 0 50 E 6.23 w 139.07 S 2 33 W 19,02 W 17.) 24 $ 6 18 W 35,84 W 208:25 $ 9 54 W $ 13 I w 55'78 w . 61'w 240 83 281.00 $ 77 291~57 S 15 28 W 325.30 $ 103,91 .~ 342,45 S 17 39 W ARCO ALASKA, INC. 28-2 KUPARUK NORTH ,SLOPE, AI,,ASI<A COmPUTATiON [)ATE.' D A T E: O I' KI<L [, ¥ FOR EVEN [o0 FF;E;T OF' Mi'ASUREI') i')' ,'H T R U E NEASURED VERTICAL DEPTH DEPTH DEP'I~! 4000.00 t917.44 3791.44 37 30 4t00.00 3995.~0 3869.80 39 3 4200,00 4073..Jl 3947.3! 39 4~00,00 4150.92 4024.92 38 59 4400.00 4228.78 41. 02.',,)38 46 4500 ,00 4306,93 4180.93 38 22 4600 00 4385.52 4259.52 37 56 4?00:00 4464.65 43~8.65 37 28 4800,00 4544,25 4418.25 ~7 2 4900.00 4624.64 4498.64 35 38 $000.00 4706.30 4580.30 34 57 5~00 O0 4788,38 4062.3~ 34 5~00:00 4870.69 4744.69 35 20 5300,00 4951 33 4825.33 36 57 5400.00 5030:06 4904.06 3~ 44 55 00,00 5107 92 4981.92 39 5 : 5700,00 5265.23 51'j9 23 37 33 5800,00 5344.77 5218~77 36 44 5900,00 5425.73 5299.73 35 32 6000 O0 5507,09 5381.09 35 31 6100:00 5588.66 5462.66 35 1. 6200,00 5670.74 5544.74 34 39 6] 00,00 5753.29 5627.29 34 5 6400.00 5836 36 5710.36 33 27 6500,00 5920:16 5794.16 32 41 6600,00 6004,5! 5878.51. 32 15 6700.00 ~608,'9,05 5963.05 32 29 6800,00 6,173,35 6047.35 32 28 6900.00 6~?, 17 6131.71 ]2 28 6976.00 ':"6~i~82 6195.8~ DEG PAGE ,,VEY~ 17-8EP-84 ~ING EUEVATION: ~26.00 .~: BAIJ~EISTER VERTICAl., DO(;L, EG ~.CTANGUi..,,~R COORD'INATE8 HURIZ, SECTION SEVERITY NOR'I'H/,S[)UTH EAST/WEST D,IST, F'EET D k',G / 10 0 FEET F~:ET FEET $ 29 37 W 398.02 8 27 21 W 459.99 8 27 4 w 523.13 S 26 57 w 586.15 S 26 54 W 648.85 S 26 51 W 711,20 S 26 46 W 773.00 $ 26 37 W 834.10 5 26 32 W 894.61 $ 23 1.3 W 954.07 $ 22 2 W 1011.73 $ 21 58 W 1068.77 S 18 49 W 1125.44 S 14 2(.)W !183.87 $ 12 3 W 1244.16 S 11 53 W 1305,34 S 12 1.4 W 1366,10 $ 12 55 W 1425.88 S 16 13 W 1485.45 S 18 53 ~ 1543.75 S 18 56 ~ 1601.57 $ 18 35 W 1659.09 5 18 10 . 1715.86 S 17 56 W 1771.91 S 17 36 w 1827.14 S 17 17 ~ 1881.27 S 17 4] ~ 1934.53 S 18 7 W 1987.55 5 18 4 W 2040.98 $ 18 4 W 2094.31 5 18 4 w 2134.83 2,69 1,06 0,18 0,30 O , 39 0,48 0,59 0,44 0 31 2~86 0,83 1,04 5.07 2,85 0,35 0,38 0,44 0.73 3.38 0.26 0,42 0,95 0,46 0,68 0,26 0,52 0,83 0.00 0.00 0,00 DE'ARTURE AZimUTH DEG ~IN 370,76 $ 133,57 w 399,73 $ !9 3! ~ 431,33 S 163,20 W 461,18 S20 43 W 487 5'1 5 192,01 W 524 02 $ 21 29 W 543:76 S 220.65 W 586 82 $ 22 5 W 599.69 S 249 08 ~ 649 37 S 22 33 W 655.34 $ 277~28 W 711 59 S 22 56 w '/10,52 $ 305,21 w 773 30 $ 23 14 W 765,15 S 332.64 w 834.33 S 2~ 29 W 819.29 S 359.73 '~ 894,79 $ 23 42 ~ ) 872,97 ~ 3~5.3'0 W 954.22 S 23 48 ~ ' 926,40 $ 407,15 W 1Oll.92 $ 23 43 w 97~.34 S 428,57 W lob9 01 6 2~ ~8 W 1032.30 $ 449,06 W ~125:'14 $ 2~ .0 W 1U89 09 $ 465,4.7 W 1184,39 $ 23 8 W 1149:19 $ 479,16 W 1245,08 S 22 38 W 1210~58 S 492.16 W 1306 80 $ 22 7 W ]271.49 & 505,2~ ~ ~368:~9 S 21 40 W 1331.20 $ 518.41 W 1428,63 $ 2~ ~6 W 1390.00 S 533.31 W 1488,80 S ~0 59 W 1445.74 $ 551.66 W 1547.42 S 20 53 w 1500.75 $ 570.48 ~ 1605,52 5 20 48 W ~555.50 $ 589.11 W 1663.32 S 20 44 W 1609,71) $ 607,19 ~ 1720 41 $ 20 40 ~ 1663,~7 S 624.66 W 1776:79 $ 20 34 w 1716.3b 5 641,6'7 W 1832 38 $ 20 29 W 1768.43 $ 65~.02 W 1886:89 $ 20 24 W ~819 69 S 674.09 W 1940,53 ~ 20 ~9 w 1870:49 $ 590,57 W 1993.89 S ~0 ~5 W lq21.~4 S 707,24 w 2047 66 $ 20 12 w ~972.69 S 723,90 W 2~01:32 S 20 9 ~.) 2011.4U $ 736,56 W 2142.10 $ ~0 6 W ,'o _ , COF, PUT~TiON ir)ATE: 3-£)CT-84 PAGE: 3 ARCO ALASKA, INC. 2H-2 KUPARUK NORTH ShOPE, ALASKA [')A'rL: OF SURVEY: 17-$EP-84 E ~ G .I N E E R: B'A U M g' ! $ '1' E: R 126,00 [N'];EPPULATED VAI.,U[<S FOR EVEN 1,0(}0 FEET T R U E $ tJ B -,.) ° El A C 0 t.) R 8 E MEASUI~ED VERTICAL VERTICAt,, DEVIATION AZIMUTH DEPTH DEPTH I}F,,PTIt bEG t'~lt',~ [;EG 74I~ VERTICAL l.)r3(;I,,~t~.:G RECTANGtJt.,AR COURL)'it'~AI'E$ HORIZ. DEPARTURE SECTIC)N SEVERi'I'¥ Nr)RTH/$UUTH EAST/WEST PIST. AZIMUTH FEET I.)E(,;/1 O0 I""I~]E"I' FEET ', FEET DEG 100~.00. 0 O0 -126.U0 0 0 .00 999:99 873.99 0 0 .2000.00 1999.9b 1873.96 0 4.3 $000,00 2998,84 2872.84 8 27 4000,00 3917,44 37~1.44 37 30 5000 ,00 4706.30 4580.30 34 57 6000.00 5507,09 5381.09 35 31 6976,00 6321,82 61.95.82 32 28 tq 0 0 E 0.00 N 64 3b W 0.87 S 31 46 E 3,62 S 20 41 W 28,33 S 29 3'1W 398.02 S 22 2 W 10~1.73 $ 18 56 W 160~.57 S 18 4 W 2134,83 U.O0 0,16 0,06 6,11 2.69 0,83 0.42 0.00 ().00 N 0,00 E 0,00 N 0 0 E 0,40 N 2,93 ~ 2.96 N 82 16 W 4,91S 1,98 E' 5,29 S 21 58 E 39.66 $ 18 26.E 43,66 $ 24 43 E 376'.76 ~ 133:57 W' 399,73 6 19 31 w 926.40 S 407.15 W ~011,92 $ 23 43 ~ 1500,75 $ 570.48 ~' 1605"52 $ 20 48 W ~011,48 $ 736.56 ~ ~142,10 $ 20 6 W ARCO ALASKA, INC, 2B-2 KUPARUK NORTH SLOPE, AbAGKA COMPUTATION DATE: 3-[)CT-g4 PAGE 4 [)ATE ['}F SURVE¥I 17-$EP-B4 KEbI.,¥ P~USHING ELEVATION: ENGINE;Ek: OAU~EISTER IN'.rI~]t,~PI. tlL, ATED VAl,iJk;S FOR EVEN ].o0 FEET (.)P :51..IB-SE, A L)EPTt-I TRUE SUB-SKA COURSE M~ASURF, D VERTICAl, VERT.ICAh DEVIATION AZIMUTH DEPTH DEPTH b t it:.' T H DEr.; Mlt'i 0 O0 0,00 -126.00 0 0 N 0 0 g 2:00 26.00 -100.00 o 8 S 19 58 W 126,00 126,00 0,0C) 0 15 N 53 44 W 226.00 226.00 ~00.00 0 23 S 73 6 W 326 O0 32b OO 2()0,0o 0 23 F.,, 88 24 W 426:01 426:00 300.0() 0 11 N 76 33 W 526.01 526,0o 400.00 () 11 N 82 17 W 626,0~ 626.00 500.00 0 10 N 76 54 ~ ~.01 726 O0 6(,(,,00 r) 3 N 66 50 ~ 826.01 826:00 700.00 0 3 N 58 39 w 926,01 926.00 800,00 0 1 N 40 54 W 1026,0! 1026,00 90().00 0 3 S 6 31 ~ 1126,01 1126,00 1000.00 0 22 S 40 22 g 1226,01 1226,o0 llt, O,O0 0 18 S 57 55 E 1632 ,01 1326.00 1200.00 0 11 S 56 43 E 1526 .01 1526,00 1400,00 0 19 S 45 32 E 1626 02 1626,00 1500,0,) 0 29 S 46 26 E 1726:02 1726,00 1600.00 0 35 S 47 25 g 1826.03 1826,00 17o0,00 0 ,{~ S 39 8 g 0 43 S 32 53 g 0 44 S 31 41 E 1 6 $ 34 3 ~: I 29 $ 37 48 g 1 44 S 37 2~ F 2 ~5 S 37 4 g 2 33 S 36 21 E 2 35 $ 36 45 E 2 20 S 34 25 E 1926 04 1926,00 1800,00 2026 05 2026.0O 1900.00 2126 2226 2326 2426 2726 2826 06 2126,00 2000,0o 08 2226,00 2100,00 12 2326,00 2200,0() 19 2426.00 2300.00 7 252b,00 2400.00 6 .2626.,00 2500.00 56 ' 0 2700.00 S 0 42 g $ 22 18 w S 13 48 W S 1~) 50 w 8 11 47 w $ 20 44 W 527 S 29 9 w S 29 25 S 30 24 126,00 FT' VER"],IC~I.., DOGLEG RFTCTANGUI,AR CL~ORI)I~ATES HURIZ. DEPARTURE . '' ;" AZIMUTH SECT]ON SEVERITY N[}R'rH/S(.)I. IH EAST/wEST DIST. F E E '.r D E G / ! 00 ~ I< g,J: F' F,: F, T F E E T D E G M I N 0.00 ().¢)0 N 0.00' 0,00 0.00 N 0,00 0,40 0,17 hi 0,14 0.!.6 0.15 0,03 0.08 0.13 N 1.92 0,12 0,1~ 0.13 0,24 N 2'59 0.08 0,29 N 2,77 0.06 0,32 N 2.83 0,12 0,3~ N 2,92 0,38 0.39 0.06 0,05 N 2,6'8 0,16 0,01 0.59 S 1,85 0,21 0.74 0.1.2 0,98 S 1,37 0,21 1,48 $ 0,8, ~5 0.26 2 10 S 0,16 0.1,,9 O~ 4,12 5 1 48 (1'08. 5,19 S 2i16 ~,34 6,48 S 2 98 0,55 8,28 $ 4,3.2 0,45 lO.bO 0.75 13,26 $ ~.08 0 25 16 52 0:30 20:03 0,68 23,74 S 15,97 0.23 27,10 S 18.41 5,16 31,78 S 20,05 6 17 43.78 S 16,60 1194 64.08 S 10,12 3,46 BT,b3 S 4.07 117.89 S 1.34 153,"4 3.45 189,.t4 S 3.11 5.11 5.55 0,00 0,00 '0,10 0.17 0.52 0.69 0,77 0.87 0,91 0,90 0.88 1.08 1.25 1.31 1.36 1.47 1.70 1.97 2 3,12 3.81 4,63 5.70 6,9~ 8.64 10.54 12.63 14.83 16.87 2926 69 i{~H~J6,00 2800.00 4 23 ..: ' . sOO 9 ,O(I () 3129 3 0 oO 4 ,:' :~'00 00. 12 5 3337~ ?~'~$'0o 32oo,o0 t9 ~4 3444,10 3426,0o 33t)o.,')o 20 50 355i,34 ~526',00 3400,00 21 43 3659,81 3626,00 3500.00 24 8 3771,13 3726,00 3600.00 28 38 3887,54 382t,. O0 3700.00 33 14 20.42 32.74 53,90 7'1.41 107.29 144,29 182,98 224,84 273.60 332.9~ 0,00 N 0 0 E 0,00 N 90 0 E 0,22 N 38 19 W 0,76 N 78 20 w 1,41 I'~ 86 54 W 1,93 N 86 2 W 2,25 N 85 17 W 2,60 N 84 36 W 2,79 N 84 6 ~ 2,85 N 83 28 W 2,q4 N 82 37 W 2,96 N 82 29 W 2,68 N 89 0 W 2,2'1 8 81 28 w 1 94 S 72 17 W 19 w ,68 S 54 17 W {,70 $ 29 51 W 2,11 S 4 24 W 3,11 S 13 0 E 4 38 $ 19 45 g 5:62 S 22 32 E 7,14 5 24 42 g 9,34 S 27 31 E 12,12 $ 29 59 E 15 52 $ 31 21 E 19~63 S 32 41 E 23,99 $ 33 24 E 28,61 S 33 56 ~' ) 32.77 S 34 11 g · 37,58 S 32 14 E 46,80 $ 20 40 5 64,87 S 8 58 E 5,02 E 87,77 S 3 16 g 0,73 W 117,89 S 0 21 w 11,56 w !54,08 5 4 18 w 26,98 N 191,06 S 8 7 W $ 11 55 w 225,'/0 $ 47.64'W 230,67 26~.74 S 70,73 ~ 277,89 S 14 44 W 32(),3~ S 1o0.4t w 335,73 S 17 24 ~ ARCO ABASKA, INC. 2B-2 KUPARI.iK NOETH SLOPE, AbASKA CO~FUTATIO~ DATEI 3-0CT-84 T R Ij E S U B- 6 [< A C (')U R S E MEAI~URED VERTICAL VERTICAI, D[::VIA'rlOt,1 AZIMUTH DEPTH DEPTH I)~.PTH I~PiG' h~II': [:,EG t~IN ~0~0.~ 3926 O0 aSO().(l() 37 44 ..~1,8' 4026:00 3900.00 39 12 i]~i 92 4126,00 'tO00.o(, 39 3 4651 23 4426.00 4300.00 37 40 49 10 68 4626.00 4500,00 35 37 024,01 4726,00 4600.00 34 51 145,61 4826,00 4700.00 34 26 5268,41 4926.00 4800.00 36 30 5523 ,30 5126.00 5000.00 38 58 5650.47 522b.00 5100,()0 37 44 5776,50 5326.00 5200.00 37 5 5900.34 542b.00 5',00.00 35 32 602~ ,24 5526,00 5400,00 35 28 ~,52 5626 O0 5500.0() 34 52 ~.~.6387,02 5726:00 5600.00 34 15 ,57 582b.00 5700,00 33 '33 6506.93 5926.00 5800.00 32 39 6625.41 6026.00 5900.00 32 13 743 85 6126.00 6000.00 32 35 862~4! 6226.00 6100.00 32 28 6976.00 6321,82 6195.82 32 28 VERTICAl, [>('!(;bEG Rf','CIANGUi.,AR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY N(,')R'I'H/SOI..JI"H EAST/WEST DIST. AZIMUTH FE~;T DEG/] 00 FEET FEET FEET DEG ., S 29 2b ~ 404.62 $ 27 7 W 484,59 $ 2b 59 W 565,96 S 26 54 W 646,62 8 26 52 W 726,25 S 26 38 W 804.38 S 26 32 ~ B80,83 S 23 9 W g55,04 S 22 2 ~ 1025,44 S 21 31 ~ 1094,54 2,01 0,33 0,17 0.36 0.20 0.50 0.55 2,72 0,11 1,22 453:23 8 1'14:44,~ 405:65 $ 3 W 525.75 $ 21.1 49 ~ 566.69 $ 21 54 ~ 597,70 S 248~07'~ 647.14 ~ 22 32 . 668,'t8 S 284,09 ~ 72b,b2 $ 23 0 W 738,57 S 319.32'W 804,64 S 23 22 W 80~.96 $ 353,56 W 881 02 $ 2~ 39 W 873 87 $ 385,68 W'"955:19 $ 23 48 w 939:12 S 412 30 w .1025 64 $ 23 42 W 10()3.29 S 438:1'8. W 1094:80 S 23 35 W $ 15 19 w 1165.29 $ 12 4 W 1240,99 $ 11 52 W 1319.67 S 12 25 w 1396,32 S 15 13 W 1471.49 S 18 53 W 1543.94 $ 18 54 W 1615,01 S 1~ 31W 1684.9~ S 17 59 w 1753.52 S 17 39 W 1820,33 2.06 0,33 1,02 0,~1 2.71 0 25 ()' 0,31 0,69 0.75 1070.86 S 460,61.W 1165,72 $ 23 16 W 1146,00 8 478,48 W 1241,88 $ 22 39 W 1224.97 S 495.17 W 1321'27 S 22 0 W 1301,'16 S 511,78 W 1398,74 $ 21 27 W 1376,38 S 529,50 W 1474,71 S 21 2 W 1445,93 $ 551,72 ~ 1547,61 $ 20 5~ W 1513,53 S 574,86 W 1619,02 $ 2047 W 1580,20 6 597,40.' W 1689,35 S' 20 42 W 1645.75 $ 618,95'W 1758,30 S 20 36 W 1709.82 $ b39,59 W '1825,5~ S 20 30 ~ S 17 16 W 1884.98 S 17 53 W 1947.97 S 17 59 ~ 2011 O1 S 18 4 ~ 2074:26 S 1~ 4 w 2134.83 0.22 0.39 0.30 1772,01 S b59,13"w 1890 02 S 20 24 w 1832,58 $ 678,23 W 1954:06 S 20 18 W 1892 94 6 697 91 w 2017,50 S 20 14 w 1953:50 $ 717:64.W 2081,15 S 20 10 W 20]1,48 S 73b.56 W 2142,10 $ 20 6 W ARCO ALASKA, 1NC, 2B-2 KUPARUK NORTH SLOPE, ALASKA MARKER TOP UPPER SAND BASE UPPER SAND TOP BOWER SA~ID BASE bOWER SAND PBTD TOTAL DEPTH CO,~PUTAT I I.)N [)ATE: [NI't-.RPOLATI-:[) VAI,IIES FOR CHOS[".N Ht. JRI.'ZON$ P ,A G I/; 6 I')ATE tJF SURVEY.' 17-SEP-84 KELLY ~U,qH..ING FiI.jEVATI{IN: 126,00 FT. e'.NGINE~;R: tqA'U~,'~gI$'rElq iuIEASUR F,D DEPTH SURFACE LOCA'I' I UN A T ()R.[GIr. i= '/44' F,SI.,, 273' FEb SEC I~A TllN R9E, L}I~I TVD RECTANGULAR,~ORDIN[TES 6525,00 5941,21 5815,21 1781,31 S 6569,00 5978 · 31 5852.31 1fl03,89 S q6 588b 9~ 1824,77 S 6610,00 6012, .. o 6774,00 6151,41 6025.41 1908,37 $ 6851. O0 6216,3'! 6(J90,37 1947,68 $ 6976:00 6321,82 6195,82 2011,48 S 662 02 W 669 08 w 675 71 w 702 91 W 715 74 w 7.36 56 w ARCO AbASKA, INC. 2B-2 KUPARUK NORTH SLOPE, ABASKA TOP UPPER SAND BASE UPPER SAND TOP bOWER SAND BASE LOWER SAND PBTD TOTAb DEPTH COMPUTATION DATE: ************ STRATIGRAPHIC ~4EA,SURED D .EPTH BELOW !< H 6525 00 6569:00 6610,00 6774.00 6851,00 6976.00 3-OCT-[~4 PAGE 7 DATE OF SURVEY.: 17-SEP-84 AE[,,bY BOSH1NG, EbEVATI(,)N: 126,00 E,'~GINEER: BAUNEISTER L)RI(;1N: 744' FSI,, SOB-SEA 5941,21 5815,21 5978,31 5852,31 6012,96 5886,9~ 6151.41 6025,41 6216.3'7 6090.37 6321,82 6195.82 18.0 ~9 $ 669:08 , 182 ' 77 $ 675.71 190~,37 $ 702.91 1947.68 S 715,74 201j'48 S 7]6,56 FINAL WEL, L LOCATION A T T D: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 6976,00 6321.82 6195.82 HORIZONTAL I.)EPARTURI< DISTANCE AZI~aLITH F E E I' I) E G ~ I N 2142,10 t-; 20 6 ' o SCHLUMBEROER ARCO ALASKA, INC. 2B-2 PRUOHOE BAY NORTH SLOPE, ALASKA SEPTEMBER !?, 1984 TVW PLOT FROM OCT DATA JOB REFERENCE BBS:SS WELL: 2B-2 SURFACE LOCATION: 744' FSL, 273' FEL, S19, T11N, R9E, UM VERTICAL PROJECTION 5O0 1000 15O0 20O0 2~ PROJECTION ON vERTICAl. PLANE OF AZIMUTH 205 SCALEO IN VERTICAL. I~!PTHS MORIZ SCALE -- i/SOO IN/FT · WELL' 2B-2 N~H ~ -50O -lO00 - I SOO -~000 -2SO0 -~000 souT~ -3S00 -gSO0 NEST SURFACE LOCATION' 744' FSL, 273' FEL, S19, T11N, RgE, UM HORIZONTAL PROJECTION R[F 69~.~6 SCALE = I/S00 [N/FT · ~~'..,[ .... ~'' '~'~1~ ~'~:~~:~ -' ..... ~J' ;: ~ ~l' ~ f ' ' ~ - ................ : ~f ~ ~ --' ,'~' . -','-r*~"* .........~','" ~ f .'.'": .................... ,'~ ....... : ............... r ...... : ........ ~ ......................................... + ........... , ; · *~' · ;~, ~ ' ' '. ' ,~ , i--- ~ - ' ' ' · .~...,...,...~.+....~"'~:'~":"~~:'~:'4~";44~ ~-!;:"':"~"I .;-.:..:..:..~.:.-~.~.:.-:.:-:..[..*...:..:~ :--~ .......... .---~.%.-,:"': .; ....... ; .... ~i~=...:.:...:...&...l.....::: 1...::: ~ ......... ~.--~4 ~;: ,-. ~...~4...~ ~ ..... :...~ .........~,~-- i .-.~---,.*-~ ........... ~ ............. 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L.~..-, .............. :...:...~...; ...... :..~-..:..~..l ........ ~ ,-~ :- ~..: ......... ~--: ..-:.; - . - [ ..........~ ........... ......... ; ...... 1 ..... ;~ -.;-.~ ~ ...... ~.:-.~ ......... ~ .......... ;.-,-4---~---~-.-; ...... 1 ....,--;-- - , -i ............. i ........; - - - ~ ...... ~ ...... %7"; ' '.: :.1' .-~ .... 1:.:.,~..;.;.,;1;; i :L;: ; ;J :.. -~ .... I - · : -~ ::~ ; --~.- 'r ~ ....... t ..... ~ .... ~ t .......... ~-!---: ....... ,---:--F: ...... ,--.~---t---~.-.:-~- t ....... ~-,--! ......... , ....: ....t .... ~--~-.~ ....... t ..~ ......... I ........ ~ ....... t ................ · '"'~'"~ .......... 4 ............ ~ ..... ;-~ .......................... ~ ......... ' ........ ; ..... ' .... ; ~ ................. ~ ..... , ........ ; -3000 -2SO0 -2000 - 1500 - 1000 -SOO 0 SOO EAST Su~gg~Sted form to be inserted in each "aCt ive'' ~ell folder to d~.eck for timoly ccmpliance with our' rc<julations. Operato~, %~ 1 N'an~ -a~d Number Reports and Materials to be received by: //- ~q-'FV Date Required Date Received Remarks ., Ccmpletion Report ,. Yes , '/~_~ ~~ ~~..,, ..' Well History Yes I~._/~i~ '"/~/"/ . · · Core Chips '' Core Description Registered Survey Plat ~ .... , ,, ..... · .,Inclination Survey Directional Survey Logs Run., Yes /t.... 0~/_~~ .~ ~ig, itized Data , ', ;( ;..*:cr, c .~ ;7 5C37 Re ~urm To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Date: 1~. Transmittal No: .~815 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of th_ts transmittal. OH FINALS Schlumberger :::~. ~:~..: ,-~; ,.,-~ ~ , -., l, e- ~-o ;~:~..~ . '/'" 2"/5" -- · ~:.;.:.:~-~::-~~lf.~~ ' - '-'::-~C'~ ' I~ ' :.-- -' ' ......... "~'~'~?~CPL Cyberlook :-~:;'~:~ .... ~'~'~'--~-' ..... , 7700 -' 8424 ~ 2D-8 2"/5" DIL-SFL/GR 8/20/84 Run 1 3754 - 8160 _W" 2"/5" Density Neutron "Raw" " " '3754- 8133 0k " 2"/5" " " "Poro"" " 3754 - 8133 " CP-L Cyberlook 8/19/84 " 7550 - 8150 2D-11 2"/5" BHC sonic/GR 7/21/84 'Run 1 7150.- 7590 "DIL/~DC/CNL/GR" 2G-4 2"/5" DIL/SFL ~/24/~4 " 2810 - 7795 ' 2"/5" FDC-CNL/GR "Raw'; "' " 6190- 7795 ~. "' 2"/5" " "?oro" " " 6190 - 7795 " CPL Cyberlook 8/22/84 " 7090 - 6950 2B-2 2"/5" Density Neutron "Raw". " 2"/5" " " "Poro" " CPL Cyberlook " .2"/5" DIL-SFL/GR 8/22/84 Run 1 "2729 - 6926 " 5500 - 6900 RECEIVED " 5500- 6900 " 6300- 6900 NOV 0 8 /ca .' Ret&pt Acknowledged: _ DISTRIBUTION '(~.~,f~.~~l"'&?Gas Cons. Commlssior, Dat~: ~ Anchorage v B. Ada~.s F.G. Baker -P. Baxter BPAE Chevron C. R. Smith Phillips Oil Sohio Mobil J.J. ~t~ell ~nion W.¥. Pasher G. Phillips R & D 'Well Files ARCO Alaska, Inc:r · Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 nctober 31, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2B-2 Dear Mr. Chatterton. Enclosed is a Subsequent Sundry Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU2/L55 Enclosures If · ~a Cons. Corem~ Sio Anch°ra~7° $ ~I ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELLx~ OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage~ AK 99510 4. Location of Well Surface: 744' FSL, 273' FEL, Sec.19, T11N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 7. Permit No. 84-122 8. APl Number 50-- 079-711 kb, 9. Unit or Lease Name 10. Well Number 2B-2 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool 12. RKB 126~ ADL 25656 ALK 2582 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe .Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). 2B-2 was drilled to a total depth of 6976'MD. The 7" production casing was set ~ 6933' and cemented with 280 sx Class "G". The bottomhole location of this well is: 1267' FNL, 1010' FEL, Sec.30, T11N, R9E, UM RECEIVED \'ov o 6 Alaska 0il & (~as Cons. C0mmissbr~ Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space(be~w fo~~_/ion se Conditioj;~' of Approv~f'any: Approved by By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate Form 10-403 GRU2/SN27 Rev. 7-1-80 and "Subsequent Reports" in Duplicate ARCO Alaska, '~ Post Ofh~,,~Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 14, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska~ 99501 Dear Mr. Chatterton: Enclosed are the Monthly State Reports for the following wells: 2G-2 1L-5 2D-9 2B-3 2G-3 1L-6 2D-8 2B-2 2G-4 1L-7 2D-7 2B-1 Thank you. Sincerely, Area Drilling Engineer JBK: ih L01 06/28/84 Enclosures ARCO Alaska, Inc. is a Subsidiary o! AtlanticRichfieldCompany .,~'-~'" STATE OF ALASKA ~-' ~"- ALASK.. O~L AND GAS CONSERVATION c-~,..,VlIsSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well I~X Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 84-122 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21154 9. Unit or Lease Name Kuparuk River Unit 4. Location of Well atsurface 744' FSL, 273' FEL, Sec. 19, TllN, R9E, UM 5. Elevation in feet (indicate I<B, DF, etc.) 6. Lease Designation and Serial No. Pad 92, RKB 127 ADL 25656 ALK 2582 10. Well No. 2B-2 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of, August , 19 84 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spud well @ 0001 hrs 08/17/84. Drld 12-1/4" hole to 2740'. Ran, cmtd & tstd 9-5/8" csg. Drld 8½" hole to 6941'. Ran logs. Drld 8½" hole to 6976' TD as of 8/22/84. Ran, cmtd & tstd 7" csg. Secured well and released rig @2000 hrs, 8/23/84. 13. Casing or liner rgn and quantities of cement, results of pressur9 tests 9-5/8" 36# J-55 HF-ERW BTC csg w/shoe @ 2725' cmtd w/800 sxs CS III & 300 sxs CS II. 7" 26# J-55 HF-ERW BTC csg w/shoe @6933'. Cmtd w/280 sxs class "G". 14. Coring resume and brief description N/A 15. Logs run and depth where run DIL/SFL/GR/S? f/6926' to 2729' CAL/FDC/CNL f/6900'-5500' 16. DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. //~//... ///~. .... ~' Area Drilling Engineer ~/~~ SIGNED "/I /.f/,,/'/,,,~-,,~/~......~./'~,~1 TITLE__ ~ ~ DATE NOTE--Re~rton~orm is required for each calendar month, regardless of the status of operations, and must be reduplicate with the Alaska Oil and Gas Conser~tion Commission by the 15th of the succeeding month, unless otherwise directed. F~,~ ~nana HILL/MR 186 Submit in duplicate ARCO Alaska ~.. Ar, cho,~agc. Alaska 99510 ~L!(.?,~,on.~ 9~7 277 5637 Date: 9/05/84 Transmittal No: 4713 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 itted herewith are the following items. Please acknowledge receipt turn One signed copy of this transmittal. OH LiS/Schlumberger #69485 8/24/84 Run 1 2780 - 7700.5 2G-4/ #69484 8/22/84 " 2720 - 6953.5 2B-2 / . #69468 8/20/84 " 3745 - 8189 2D-8~' /cat Receipt Acknowledged: B. Adams F.G. Baker P. Baxter BPAE Chevron Date: DISTRIBUTION D&M Drilling Geology Mobil NSK Operations W.V. Pasher C.R. Smith G. Phillips 'Sf~'t~¥Alaska Phillips Oil Sohio J.J. Rathmell Union R & D Well Files MEMORANDUM TO: THRU: FROM: Staze of Alaska ALASKA OIL AND GAS CONSERVATION CO},~iISSION C.V. e~rton DATE: August 22, 1984 Chaif~¢-~/ Lonnie C. Smith CommiSsioner Bobby Foster ¥/-' ' Petroleum Inspector FILE NO: D. 3I. 46 TELEPHONE NO: SUBJECT: Witness the BOPE Test on ARCO's 2B-2, Sec. 19, TllN,R9E,UM, Permit No. 84-122. Saturday, August 18, 1984: The BOPE test began at 9:00 am and was h°~clUded~ at 10.'30.' am.' As the attached BOPE test report shows there were no failures. In summary, I witnessed the BOPE test on ARCO's 2B-2. At tachment 02-00IA(Rev. 10/79) o&¢, 5/84 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Locatio'ni Sec /~ T~ qEM /~/ ~~asing Set @_~ ~_~ 7 ft. Drilling Contractor y/~J - Rig #~~Rep~esentative Location, General ~/_. Well Sign~. ACCUMULATOR SYSTEM General Housekeepin~~_~Rig ~/~ Trip Tank Pit Gauge · ! Flow Monitor c.~- Gas Detectors / Audio~Z BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H. C.R. Valve Kill Line Valves Check Valve Test Pressure Test Results: Failures ~ Repair or Replacement of failed equipment to be made within --- Wen Representative Permit # ~r,-//-- )3~_~ ' ' ' Full Charge Pressur~~ ~, psig Pressure After Closure'/~fP psig Pump incr. clos. pres. 200 psig -- min.~, sec. Full Charge Pressure Attained: ~ min~ sec. N2~_~c~.t~v ,~ ~/ ~) .~o.~g)~p psig ...... Controls: Master / Remote L~/~_~ Blinds switch cover~.~ / Kelly and Floor Safety Valves Upper Kelly / Test Pressure Lower Kelly / Test Pressure Ball Type ] Test Pressure Inside BOP~ / Test Pressure ~~ Choke Manifold ~Test Pressure V No'. flanges Adjustable Chokes ~ Hydrauically operated choke / Test Time / Y~'~ hrs. Commission office notified. days and Inspector/ Remarks: Distribution orig. - AO&GCC cc - Operator cc - Supervisor ARCO Alaska, Inc{ Post Office"r_,ox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 14, 1984 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2B-2 (Revised Bottomhole Location) Dear Mr. Chatterton: Enclosed is a Sundry Notice proposing to change the bottomhole location of 2B-2. If you have any questions, please call me at 263-4970. Since we expect to spud this well on August 17, 1984, your earliest approval will be appreciated. Sincerely, Area Drilling Engineer JBK/JG/tw GRU8/L95 Enclosure RECEIVED Alaska Oil &,{~as Cons. Commission /~nchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ALASKA~TL AND GAS CONSERVATION C~MISSION NOTICES AND REPORTS oN WELLS DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 84-122 3. Address 8. APl Number P. 0. Box 100360, Anchorage· AK 99510 50- 029-21154 4. Location of Well SHL: 744' FSL· 273' FEL, Sec.19~ T11N, RgE, UN At top of proposed Producing interval (Revised): 1048' FNL, 1087' FEL, Sec.30, T11N· RgE· UN :. BHL (Revised): 1307' FNL, 1205' FEL· 5ec.30· T11N· R9E· UN 5~Elevationinfe~ (indicate KB, DF, etc.) I 6. Lease Designationand SerialNo. RKB 127' Pad 92~ I ADL 25656 ALK 2582 · . 12. 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 2B-2 11. Field and Pool Kuparuk River Fie]d Kuparuk River 0il Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing ~ Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other ~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) [] [] [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work. for Abandonment see 20 AAC 25.105-170). ARCO Alaska, inc.· proposes to change the bott0mho]e location of we]] 2B-2 to 1307' FNL, 1205' FEL, Sec. 30~ TllN, RgE, UN. 7" production casing wi]] be set ~ 7085'ND (6335'TVD) and cemented per AOGCC Regulations 20 ACC 25.030 Casing and Cementing. The 9-5/8" surface casing depth wi]] not be affected by the new BHL change. We]] 2B-3 is the closest we]] to 2B-2 at a distance of 60' at the surface. There are no closer we]]bores anywhere downho]e. Attached are the revised directional plats and proximity plat. Estimated Start: August 17, 1984 RECEIVED Subsequent Work Reported o. No/ AUG 1 41~!~ Alaska Oil & Gas Cons. Commission Anchorage 14. I hereb)c,C~ify that the foregoing is true and correct to the best of my knowledge. Signed'/ //.~.(/.~ /.~/~,~.-,I.**~,' Title Area Dril ling Engineer The spa odf~r Ce/mmission use Conditions of Approval, if any: Date ORIGINAL g~ tONfll£ C, SIIllli Approved by COMMISSIONER _Approved Cop)' _Returned , By Order of the Commission Date Form 10-403 Submit "Intentions" in Triplicate Rev. 7-1q~O GRU8/SN38 =.~ "q,,h ........ I:~ ...... "in n,,nli~-=t. ....... .. ARCO :'F-:;;-!'7:':'-i:PAD.;Z,;:IdELL;NO.. _~;:RE~I'SEDjPROF, OSAL;'.' , · .......... ~ .......... KUPARUK .... F~EL-D,~---NORTH--SUOPE--,--jALAS~KA-' ~ /~-)t -~-- i ...... ; .... ~ ~ ~ ~ ~ i J ~ · : ...... i . . : _ . .i .... '. ...... i ..... ~ .... !. _ ~ ..... l . . ~ . ~ .... : ...... _ ' _ ..................... , ......... t · ; t .- , ...... ~ .... ~ .... - ....... i .....~ . ~_,_.~ .... .... ~. ~.. _ ~ ...................... ........... : ....... S~_~D_~9~ ~ ~ ~ -"~' ,' ' -: ; ...... UGNU SND - TVD 1 .. . ~ ', .... ~O.O :' - ...... · . ~ ..... TOP~ ..... ~ ~ ...... CSG~ PT-- fVD=2747 ......... j ~ '-~'': KDP~' ~VD~2900~THD=2900 DEP-O~ .... ~ .....J"' ~' ~ .... ~ j ........... ~ ~- - ~ ...... 1~ .- " ...... --t ............ ~ .... : ~ -~ ~BASE ~UP SNDS ~VD=6~80 THD=6885 DEP=2126 .... .:.: ..... , ...... SCJ~?-' : IN' ;,'"_ 1000 FEET ', · KUPARUK FIELD,-NORTHtSLOPE. -ALASKA EASTMAN WHIPSTOCK. INC... ~ I ~ · i ~ ~ ~ .. . ~000 ~'~ : ~000 .... P ~000 .......... ~ ] ' · ! : ~j ............................. ~-/ j ............. ..... J ' '~ ' -24 ~DEG~ ............. aO4T'; (TO TARGEt) .................. i '' ' ~ ..... ~ ....... j -'' i ......... ~'' ' ..... } ............. I Alaska pd & Ga~ cons. Comm'ssldln ARCO Alaska, In Post Office ,.,~x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 5, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Conductor As-Built Location Plats - 2B-Pad Wells 5-12, 1-4, 13-16 Dear Elaine' Enclosed are as-built location plats for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU8/L27 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany i NOTES: · LOCATED IN PROTRACTED SECTION 19, TOWNSHIP II N., RANGE .gE., UMIAT MERIDIAN. _ BASIS OF ELEVATION IS r.~.M, 2B 'r ~ ~B8 PER LHD ~ ASSOC. BASIS OF LOCATION !$ TEMPORARY MONUMENTS 2B NORTH 8~2B SOUTH PER LHD~ASSOC. ORIGINAL GROUND (O.G.}ELEVATIONS TAKEN ON TUNDRA EAST OF WELL LOCATIONS. i o o o o el e~ DRILL. ~' - '-, TE 2 -El CONDUC'I'O~ ~- AS. uUILT LOCA~ON $ WELL 1 Y"5 , 954 , 9';4 .6 $ LAT. 70 X~ 508,346.10 LONG.149 798 FSn 298 F~L EL. 91.9 }'-5,954,890.07 LAT. 70 X- 50 8,370.9 3 r,~NG. 149 744 FSL 273 FEL EL. 92.0 WELL 3 ¥-5,954,$35.49 LAT. 70 X- 508,395.79 ACNG.149 689 FSL 249 FEL EL. 92.0 WELL 4 ¥~'5 ,954 , 780 .9 3 r--AT. 70 X- 508,420.79 LONG .149 634 FSL 224 FEL EL. 91.9 WELL 13 Y~5 ,955 ,608.84 LAT. 70 17' 17.2395- 55' 56.$026" ' O.O. 87.4' 17' 16.7020" 55 ' 56 ' O,O. 87,6' 17 '16.2649" 55 '55.3S82" ' O.G. $7.9' 17'!5 55'54 ' O.G. .6280" .6317" 87.6' · 7754" X- 508,043.50 LONG.149 56'05.5995" 1463 FSL 597 FEL EL. 89.5' O.O. $$.4' WELL l& Y'5,955,554.18 LAT. 70 17'£3.£374" X- 508,068.46 LONG.149 56 '04.873£" 1408 FSL 573 FEL EL. 89.3' O.G. 8~.4' WELL 15 Y-5,955,499.50 AAT. 70 17'22.6994 X' 508,093.22 LONG.149 56'04.1538 1353 FSL 548 FEL EL. 89.4' O.g. 82.8 W~LL 16 ¥-5,955,445.14 LAT. 70 17'22.1644" X- 508,117.88 LONG.149 56 '03.4370" I~99 FSL 524 FEL EL. 89.2' 0.3. 82.5' 17'23 ,.-' OFA ~ ~0 ~' 49th _. Kuparuk Project North Slope Drillin~ DRILL SITE 2.B CONDUCTOR AS' BUILT ~ATIONS _ n,. - _,_ - ..... D~e: 6/1~/B4 Scale, 't"= 4~' ~_~t~: ~N ~. n~: N~ 9DB.2OZ~2 J Alaska ~iI & (;as LOCATED IN PROTRACTED SECTION 19, Cons, Commission ~ TIt N, RgE, UMIAT M~;RIDIAN. /~nchora(,e --~f- ' - ' I HEREBY CERTIFY THAT I AM PRO~RLY REGISTERED ~ -- ", utL[ U~N~ ~ ~TICE LAND SURVEYING IN THE ~ATE OF ~ i ~ '- ~~ ,~AT~I, ~TREPRESENTS A SURV~'ADE ~.$~. ~i ~ Iai-- CORRECT AS OF JUNE 3,1994 U#DF.R MY DIRECT SUP'ERVISION ~/ THAT ALL DETAILS ARE July 24, t984 Mr. Jeffrey B. Kewin Area Drilling Engineer ARCO Alaska, inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 2B-2 ARCO Alaska, Inc. Permit No. 84-122 Sur. Loc. 744' FSL, 273' FEL, Sec. 19, TllN, R9E, UM. Btmhole Loc. 1526' F~L, 1323' 'FEL, Sec. 30, TllN, R9E, U/~. Dear Mr. Kewin: Enclosed is the approved applicat, ion for permit to drill the above referenced well. If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a mud log are-not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log iufo~mation shall be submitted on all logs for copying except experimental logs, velocity surveys and ~lpm ter surveys. ~y. rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16o05.870 and the regulations promulgated thereunder (Title 5, Alaska Adm~istrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Coz~trol Act, as amended. Prior to commencing operations you may be contacted by. a representative of the Department of Environmental Conservation. To aid us in scheduli~ field work, please notify this office 24 hours prior to commencing installation of the blowout preventien Kuparuk ~{iver Unit equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Veery truly yours, ---,vI "~ ,,-,-/x, :':'x?, ~ ~. V. ~tterton Chai~an of Alaska Oil and Gas Conservation Co~ssion BY ORDER OF TILE COI~{IS$ION ic Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ARCO Alaska, Inc.,~. Post Office, 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 18, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Kuparuk 2B-2 Dear Mr. Chatterton' Enclosed are' o An application for Permit to Drill Kuparuk 2B-2, along a $100 application fee o Diagrams showing the proposed horizontal and vertical projections of the wellbore o A proximity plat o A diagram and description of the surface hole diverter system with o A diagram and description of the BOP equipment Since we estimate spudding this well on August 10, 1984, your earliest approval will be appreciated. If you have any questions, please Sincerely, J. B. Kew~q - Area Drilqing Engineer call me at 263-4970. JBK/JG/tw GRU8/L54 Attachments RECEIVED JUL 1 9 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ,/-~.. STATE OF ALASKA ALASKA .L AND GAS CONSERVATION C~-.,~MlSSlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work. 2. Name of operator ARCO Alaska, Inc. 3. Address DRILL [~X REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL I~X DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE ~ '~ MULTIPLE ZONE []~ ,~ P. O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 744' FSL, 273' FEL, Sec.19, TllN, R9E, UM At top of proposed producing interval 1237' FNL, 1190' FEL, Sec.30, TllN, R9E, UM At total depth 1526' FNL, 1323' FEL, Sec.30, TllN, RgE, UM 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. RKB 127', PAD 92' ADL 25656 ALK 2582 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 30 mi. NW of Deadhorse miles 744 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 7242' MD, 6326' TVD feet 2560 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 2900 9. Unit or lease name Kuparuk River Unit 10. Well number 2B-2 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool Amour $500,000 L~' ~lstance to nearest drilling or completed I.,~,~ well 60' e surf see feet 18. Approximate spud date J 08/10/84 feet. MAXIMUM HOLE ANGLE 43 ol20. Anticipated pressures (see 20 AAC 25.035 (c) (2) 2683 psig@ RO°F . Surface ~psig@ 6084 ft. TD (TVD) 21 SIZE Hole 24" [12-1/4" !8-1/2" Casing 16" 9-5/8" Weight 62.5# 36.0# 7" 26.0# Proposed Casing, Liner and Cementing Program 22. Describe proposed program: CASING AND LINER Grade I Coupling H-40 / Wel J-55 HFIERW BTC J-55 HFIERW BTC Length SETTING DEPTH MD TOP TVD MD BOTTOM TVD 80' 34' I 34' I 2713' 34' I 34' 7209' 33' I 33' 114' 114' 2747' I 2747' I 7242' I 6326' I I QUANTITY OF CEMENT (include stage data) ± 200 cf 800 sx Cold Set Ill & 300 sx Cold Set II 300 sx Class "G" ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7242' MD (6326' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure is 2683 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 2000 psi prior to releasing the drilling rig. N~-~eezing fluids will be left in uncemented annuli through the permafrost interval. 2B-2 will be 60' away from.,?,~-4-at the surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any (see attached sheet) 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNEDL~#, /~. ~,..~Z~-'(.~.~l ~,~,'A,~ TITLE Area Drilling Engineer CONDITIONS OF APPROVAL Samples required Mud log required t--lYES ~¢~NO []YES Permit number Approval date ~ff'"/.~ /~.-'"-~z~7~24_784 Form 10401 '"'- GRUS/PD22 ~ / DATE SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE July 24, 1984 · by order of the Commission Submit in triplicate Directional Survey required I APl number I J~kyEs []NO I 50- b% ~ - ~. i l ~ Y' Permit to Drill 2B-2 interruptions in the disposal process. The well will be completed by the workover rig using 3-1/2", 9.2#/ft, J-55, 8rd tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. RECEIVED JUL 1 9 lgB4 Alaska Oil & Gas Cons. Commission Anchorage · 3~ 2' PRaPOSED - ~ ' KUP-A~ U~' F ! ELD. NORTH- SL OPE, AL AS[~LA .... ~ ...... . ........... ...... I_QOQ .......... ' B~.E. ~ER~FROST TYD=l.497 , TOP UONU~SHDS TVD, 1807 ; TOP W SAK SNDS TvD=2347 ' ;, .... K~12' TV~=269~ ' * ............................ ' .... _~ CSO'PT TVD=2T47 ' I, - KOP TVD=2900 T~D=2900 DEP=O 2 ~ 15 :BUILD 3 D[O ~ i : · ~ .... t~__ ~ ~__ 2 ...................... L ..... : ~ ......................................................... : ; ~ TOP U~PR SNDS ~VD=5987 THD=ez78 BEP~218* : : *, % :' TAROET CNTR .TVD=6084 TMD=6910 DEP=2274 ~ ~ ~ ~ BASE KUP SN~S TVD=6180 THD=7042 DEP~2364 '~ ............... ~ ...... ~ ......... TD CLOG PT) TVD=6326 T~D=7242 DEP=2501 . , · , ~ : rnn~' ~ " ' , · .............. : ................. RECEIVED , b ~ooo ' ~ooo-~ sooo : ~ ~~ ~ . j ~ Alaska Oil & Gas Cons. Commission · , ~ - I · ~ 1 j Anchorage PRndFCT ! aN ARCO ALASKA, !NC. i ~ PAD 2B. WELL NO~ 2 ITROPOSED ' KUPARUK FIELD. NORTH:SLOPE, ALASKA EASTHAN WH~.PSTOCK. [~C. 3000 2000 1000 0 TARGET GEN"ER. TI"ID-EgI 0 DI[PI22/'~, SURFACE ._ 1/EST 955 ' ~ S 24 DEo 50 H[N W 2274' (TO TAR~£T) 1 000 SUrF^GE-LO0^I'IO# t 74~' FSL. 273' FEL ~IEC- 1~ T11N, ReE 'FAROET LOCATT ON ~ T320' FtlL. 1 228' FEL SIEC. 30, T11N. RCJd[ RECEIVED JUL .1, 9 ]~J4 Alaska Oil & Gas Cons. Commission Anchorage jBO0 7'00 600 400 ~.nnn ' i - ~ ' ' ~ ' ARCO ALASKA. I-NC. PAD 2B. WELL NO, 1-2-3-4 PROPOSED KUPARUK FIELD. NORTH SLOPE. ALASKA NOTE'WELL PATHS EXTEN~ BEYOND T~IS VJEWJN~ W~N~OW ~77 i i ~g 4102 /,,:,-.., /.,,. ~o~ 300 1527 791 200 I , 1709 100 I ,t'~P~ 307D Surface Diverter System 1. 16"-2000 psi Tankco starting head. 2. Tankco quick connect assy. 3. 16" X 20" 2000 psi double studded adapter. 4. 20" 2000 psi drilling spool w/10" side outlets. 5. 10" ball valves, hydraulically actuated, w/10" lines to reserve pit. Valves to open automatically upon closure of annular preventer. 6. 20" 2000 psi annular preventer. 7. 20" bell nipple. Maintenance & 0Deration 1. Upon initial installation close annular preventer and verify 6hat ball valves have opened properly. 2. Close annular preventer and blow air through diverter lines every ~2 hours. 3. Close annular preventer in the event that gas or fluid flow to surface is detected. If necessary, manually override and close ball valve to upwind diverter line. Do not shut in well under any circumstances. 16" Conductor RECEIVED J U L 9 g84 Alaska Oil & Gas Cons. Commission Anchorage 9 PIPF, ~ DIAGRAM ~1 13-5/8" 5000 PSI RSRRA BOP STACK 1. 16" - 2000 psi Tankco starting head 2. 11" - 3000 psi casing head 3. 11" - 3000 psi x 13-5/8" - 5000 psi spacer spool 4. 13-5/8" - 5000 psi x 13-5/8" - 5000 psi drilling spool 5. 13-5/8" - 5000 psi pipe rams 6. 13-5/8" - 5000 psi drilling spool w/choke and kill lines 7. 13-5/8" - 5000 psi pipe rams 8. 13-5/8" - 5000 psi blind rams g. 13-5/8" - 5000 psi annular BLIND · ~,A~ DRILLING SPOOL 6 HD 2 ACCUMULATOR CAPACITY TEST '1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REfrAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON NADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REI~U~INING PRESSURE. 13-5/B" BOP STACK TEST 1. FILL BOP STACK AND MAJ~IFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETILACT- ED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SE, AT IN WELLHEad3. RUN IN LOCK DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND 'V'ATL~¥]~S UI~S~ OF C}~OKES. DON~T TEST AGAINST CLOSED CHOKES 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD 'FOR 10 MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLE FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 B. ~'PRESSU~ DOWN&~REAM OF CHOKE ISOLATION ~AL¥-~S, TO ZERO PSl TO TEST VALVES. TEST REI~AINING UNTESTED MANIFOLD .VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN TOP SET OF PIPE RAMS AND CLOSE BO1-FOM SET OF PIPE RAMS. 10. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR lO MINUTES BLEED TO ZERO PSI. 11. OPEN BOt'FOM SET OF PIPE RAMS. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE ~tANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLING POSITION. 13. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 15.RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. 16. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. RECEIVED JUL 1 91~ ,Alaska Oil & Gas Cons. Commission Anchorage CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (1) Fee (2) Loc (3) Admin (~[~.. (9 thru ~ ~) (~0 and ~) (12 thru 20) ("21 thr~ 24) ( 6 ) Ad d: //~// 7-~-~? ~ Company Lease & Well No. YES NO 1. Is the permit fee attached .................................... ' .... .-~'~-, 2. Is well to be.located in a defined pool ............................. ~-- 3. Is well located proper distance from property line ................. 4. Is well located proper distance from other wells ................... 5. Is sufficient undedicated acreage available in this pool ........... '6. Is well to be deviated and is well bore plat included .............. 7. Is operator the only affected party ................................. 8. Can permit be approved before ten-day wait .......................... REMARKS ® 10. 11.. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. Is administrative approval needed · :''.'. :''..'' -' -.: .... '' Is conductor string provided ....................................... 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 .................... ii Will surface casing protect.fresh water zones .................... Will all casing give adequate safety in collapse, tension and burs Is this well to be kicked off from an existing wellbore ............ Is old wellbore abandonment procedure included on 10-403 ........... Is adequate well bore separation proposed .......................... Is a diverter system required ....................................... ~ Are necessary diagrams of diverter amd BOP equipment attached ..... Does BOPE have sufficient pressure rating - ~est to ~/Z~ pslg j~ Does the choke manifold comply w/AP1 RP-53 (Feb. 78) .................. /v~ 7" $ 08"//7'7-~D Additional requirements ............................................. Additional Remarks: o Ho Geology: Eng.i~g~ing: Hw K LCS WVA ~ JKT~%i~HJH ~ JAL ~~ / " rev:' ~- 12~08/83 6. CKLT INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE , , Well History File APPENDIX Information of detailed nature that is not pa[ticulady germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. LVP 019.H0Z VERIFICATI'~N LISTtNG P4GE 1 *-~ REEL SE::lV £C S NAqE :'EDIT 3RZGIN : REEL N~M~ : ~O'~TIN'JATi]N ~ : )1 PREVIOJS REEL : COMMENTS : '¢, T.~PE HE~OER SER¥£C~ NA~E : DATE :84/05/30 3RZGZN [APE NAME :9484 CO~TINJATI]N ~ :01 PRzVIOOS T~P,=.. COMMENTS : FILE N~MiE :~DIT .OJ1 :.~ ~ ~A: :t: ~ . ...... ........ ........ :.., ...... ~:: .; .~.......... '...~." .:'~?,.i. 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