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214-119
STATE OF ALASKA • AL :A OIL AND GAS CONSERVATION COIF .;SION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Performed Abandon f Repair w ell r Plug Perforations r Perforate r Other Fracture Alter Casing r Pull Tubing r Stimulate-Frac r Stimulation Waiver r Time Extension Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development R.r Exploratory r 214-119-0 3 Address. 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r 50-103-20271-01 7.Property Designation(Lease Number): 8.Well Name and Number. ADL 375074/380054 KRU 2N-319A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071) 10.Field/Pool(s): none Kuparuk River Field/Tarn Oil Pool 11.Present Well Condition Summary: Total Depth measured 7300 feet Plugs(measured) none true vertical 5576 feet Junk(measured) none Effective Depth measured 7290 feet Packer(measured) 6361,6420 true vertical 5568 feet (true vertical) 4965, 5001 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 108 108 SURFACE 2410 7.625 2439 2308 PRODUCTION 6543 5.5 7019 5585 LINER 885 3.5 7290 5568 RECEIVED Perforation depth: Measured depth: 6965'-6990' JAN 1 4 2015 sco True Vertical Depth: 5349'-5365' E© 1\. I'- Z AOGCC II Tubing(size,grade,MD,and ND) 3 5, L-80, 6414 MD,4997 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER 44SABL36X 27 L-80 SABL-3 @ 6361 MD and 4965 TVD PACKER-FLEX LOCK LINER TOP PACKER @ 6420 MD and 5001 TVD NIPPLE-CAMCO DS NIPPLE @ 517 MD and 517 TVD 12 Stimulation or cement squeeze summary: Intervals treated(measured): 6965'-6990' 1 Treatment descriptions including volumes used and final pressure: 299960#of 16/20 carbolate 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development l( Service r Stratigraphic r 16.Well Status after work: Oil I Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O Exempt 314-649 Contact Xuegin Yang A 265-6342 Email xuegin.yanqAconocophillips.com Printed Name Xuegin Yang Title Sr. Completions Engineer Signature «< 1p< 4 - Phone:265-6342 Date U/1// 3/ 2,,,,,1-- ,,,r /—. !/TL 31/9//5— RBDMSW JAN 1 4 2015 Form 10-404 Revised 10/2012 Ae 7A5,:f.--- Submit Original Only 2N-319A FRAC SUMMARY DATE SUMMARY 12/8/2014 SET BAITED PULLING TOOL ON BALL AND ROD @ 6385' RKB. PULLED SOV @ 6249' RKB, SET DV @ SAME. MIT TBG 4000 PSI, PASSED. MIT IA 3500 PSI, PASSED. IN PROGRESS. 12/9/2014 PULLED BALL& ROD AND RHC PLUG FROM XN @ 6385' RKB. ATTEMPT 25' DMY PERF DRIFT, SD @ 6824'SLM. -- 165'ABOVE PERF TARGET DEPTH. OBTAINED SAMPLE OF VERY THICK MUD. 12/15/2014 PERFORM WEEKLY BOP TEST, RIH WITH JSN TO TD @ 7070' CTMD PUMPING SLICK DIESEL AT 1.5 BPM TO SWAP HEAVY FLUIDS OUT OF THE WELL, TBG LEFT F/P TO TD, JOB COMPLETE. 12/16/2014 DRIFT W/25'X 2.25" DUMMY PERF GUN DOWN TO 7063' RKB. READY FOR E-LINE. 12/17/2014 TAG AT 7075'. LOG MAIN RCBL PASS FROM 7075'TO 6400'. TOP OF CEMENT ESTIMATED AT 6410'. LOGGED RCBL REPEAT PASS FROM 7075'TO 6800'. LOGGED JEWELRY PASS FROM 7075'TO SURFACE. 12/18/2014 PERFORATED INTERVAL OF 6965-6990'. FIRED GUNS AT A CCL STOP DEPTH OF 6957.5'WITH A 7.5' CCL TO TOP SHOT OFFSET. PERFORATED USING 2" HSC GUN WITH 6 SPF, 60 DEG PHASING AND HMX BH CHARGES. 12/18/2014 INJECTIVITY TEST PUMP DOWN TUBING AT DIFFERENT RATES/.5/1/2/3/4/5 BPM RECORD PRESSURES AND RATE JOB COMPLETE 12/21/2014 Performed fracture stimulation of the Bermuda formation placing 299,960#(100%design) 16/20 CarboLite, 3004-bbl total volume, 27#linear and x-link gel. • KUP PROD 2N-319A ConocoPhillips t Well Attributes Max Angle&MD TD Alaska,Inc, Wellbore API/DWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) r_ R 501032027101 TARN PARTICIPATING AREA PROD 52.87 4,865.11 7,300.0 ' --- Comment Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2N-319A.1/2/201511:16:30 AM SSSV:NIPPLE 35 1/13/2009 Last WO: 27.90 10/8/1998 Vertical schematic(actueAnnotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:SIDETRACK TO A,PULLED RHC, smsmith 12/22/2014 HANGER.255-• tiL ADDPERFS/FRAC Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ..,„ ,., ,.. ., CONDUCTOR 16 15.062 29.0 108.0 108.0 62.58 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 75/8 6.875 29.0 2,438.8 2,307.0 29.70 L-80 BTC-MOD Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread PRODUCTION 51/2 4.950 27.7 6,570.2 5,094.2 15.50 L-80 Hyd 563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread LINER 3.51 2.992 6,405.2 7,290.0 5,568.4 9.30 L-80 Hyd511 Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl("1 Item Des Com (in) ,Ah/CONDUCTOR,29.0-108.0 . /.... 6,405.2 4,991.9 51.75 HANGER BAKER ZXP LINER HANGER 3.990 2.990 6.420.4 5,001.3 51.74 PACKER FLEX LOCK LINER TOP PACKER Tubing Strings NIPPLE.516.9 I Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth D Wt Ib/fl Grade TopConnection p ITv 11��� 1 ) TUBING 31/2 2.991 25.5 6,413.5 4,997.0 9.30 L-80 EUE 8rd Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Ind("1 Item Des Com (in) 1 25.5 25.5 0.00 HANGER FMC HANGER 2.910 516.9 516.9 0.42 NIPPLE 2.875"CAMCO DS NIPPLE 2.875 6,308.1 4,931.8 51.78 SLEEVE CMU SLIDING SLEEVE 2.813 6,360.4 4,964.2 51.77 LOCATOR LOCATOR W/.97"BAKER KBH-22 ANCHOR SEAL 3.000 ASSEMBLY 6,361.2 4,964.6 51.77 PACKER BAKER 44SABL36X 27 L-80 SABL-3 3.640 SURFACE;29.0-2,438.8-+ 6,384.6 4,979.2 51.76 NIPPLE CAMCO 2.75 XN NIPPLE 2.635 - 6,406.5 4,992.7 51.75 SOS BAKER SHEAR PINNED FLUTED NO-GO SUB 2.991 GAS LIFT;2,895.8 6,412.5 4,996.4 51.74 SHOE MULE SHOE WLEG 2.990 Perforations&Slots Shot Den Top(TVD) 131711(TVD) (shots"( Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn GAS LIFT:4,232.5 ■ 6,965.0 6.990.0 5,348.7 5,364.9 S-5,2N-319 12/18/2014 6.0 APERF Perforated interval of I 6965-6990'.Fired guns j at a CCL stop depth of j 6957.5'with a 7.5'CCL to top shot offset. Perforated using 2"HSC GAS LIFT:5,465.7 ■ Gun with 6 SPF,60 DEG phasing and HMX BH charges Stimulations&Treatments I Min Top Max Btrn Depth Depth Top(ND) Blm(TVD) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com GAS LIFT:6,249.5 GP 6,965.0 6,990.0 5,348.7 5,364.9 FRAC 12/21/201 Performed fracture stimulation of the Bermuda I 4 formation placing 299,9608(100%design)16/20 CarboLite,3004-bbl total volume,27#linear and x- link gel..see attached job data. Mandrel Inserts SLEEVE',4308.1 ' St el on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (In) (psi) Run Date Com 2,695.6 2,498.5 CAMCO KBG 1 GAS LIFT DMY INT 0.000 0.0 11/25/2014 2.9 LOCATOR;6,360.4 ) 2 4,232.5 3,628.4 CAMCO KBG 1 GAS LIFT DMY INT 0.000 0.0 11/25/2014 2.9 PACKER;8,381.1 3 5,465.7 4,408.4 CAMCO KBG 1 GAS LIFT DMY (NT 0.000 0.0 1125/2014 2.9 4 6,249.5 4,895.5 CAMCO KBG 1 GAS LIFT SV INT 0.000 0.0 11/25/2014 DCK-3 2.9 NIPPLE;6,3846 Notes:General&Safety I End Date Annotation NOTE: SOS;8,406.5 .A SHOE:6,412.5 ' r1 F X0 I i. 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They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. jL . - 1 Lq Well History File Identifier Organizing (done) Two-sided ❑ Rescan Needed RESCAN: OVERSIZED: NOTES: /Color Items: ❑ Maps: viz(G'rayscale Items: Logs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: Maria Date: 3//0 `� isi 11(P Project Proofing BY: Maria Date: 3 D /s/ U ' Scanning11 1 Preparation 3 x 30 = d + I = TOTAL PAGES p � � 1] ! (Count does not include cover sheet) BY: AIM Date: 3 /0/A5— /s/ Production Scanning Stage 1 Page Count from Scanned File: 1 I c- (Count does include cover heet) Page Count Matches Number in Scanning Preparation: YES NO BY: 41!. Date:31 10( 13' /s/ 1 ' 1 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: 0 NO TOTAL PAGES: -72— Digital version appended by: MeredithMichal / Date: *OS' /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: 1 5_!g g Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked 7/8/2014 Well History File Cover Page_20140708.doc kn 0 0 0 N o O p r • . • M n o Z _c • • ` ` • . - • a• a)i N N at N @ z • z Z Z Z z Z Z Z Z Z Z Z ❑ Clcs U ' 21 2 NI _0 0 0 0 0 0 0 0 0 0 u) -' — D >- @ Q @ U) U) U) U) U) U) Cl) U) U) CO— — —@ @ ce tO l] U!!) > > > > > > > > > C C C b I I I I LL it U `' o a) - -I rn a) a) rn a) rn rn < rn a a ai Z j C MI M ?LL ? c?-6. 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C7 ` 0 E E a M 0 0 RECEIVED • STATE OF ALASKA DEC 17 2014 WELLALASKA OIL AND GAS CONSERVATION COMMISSION la.Well Status: Oil COMPLETION OR RECOMPLETION REPORT AND LGCc ❑ , Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑' Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No.of Completions: Service ❑ StratigraphicTest❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. • or Aband.: November 26,2014 214-119/ ' 3.Address: 6.Date Spudded: 13.API Number: P.O.Box 100360,Anchorage,AK 99510-0360 November 1,2014 50-103-20271-01 • 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number Surface: 54'FNL,734'FEL,Sec.3,T9N, R7E, UM November 15,2014 KRU 2N-319A ' Top of Productive Horizon: 8. KB(ft above MSL): 149'RKB 15.Field/Pool(s): 650'FNL, 1631'FWL,Sec.3,T9N,R7E, UM GL(ft above MSL): 121'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 1077'FNL, 1104'FWL,Sec. 3,T9N, R7E, UM 7290'MD/5568'TVD Tarn Oil Pool • 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-460859 y- 5911953 Zone-4 7300'MD/5576'TVD ADL 380054,375074 TPI: x-457942 y- 5911373 Zone-4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x-457414 y- 5910949 Zone-4 nipple @ 517'MD/517'TVD 4602 18.Directional Survey: Yes ❑ • No❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1242'MD/1204'TVD 21.Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD GR/Res, Neutron, Density 2443'MD/2310'TVD 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.58# H-40 29' 108' 29' 108' 24" 9 cu yds High Early 7.625" 29.7# L-80 29' 2439' 29' 2308' 9.875" 260 sx AS III Lite,240 sx CI G,60 sx AS I 5.5" 15.5# L-80 26' 7019' 26' 5585' 6.75" 75 bbls 12 ppg LiteCRETE 57 59( 3.5" 9.3# L-80 6405' 7290' 4992' 5568' 4.75" 1/5/bbls 12 ppg LiteCRETE 7 5"W6 2 5-9t / r'j 1130115- 24. /3011s24.Open to production or injection? Yes ❑ No Q If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 3.5" 6413' 6361'MD/4965'TVD no perfs COMPLE11001 w 6405'MD/4992'TVD 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. -1I`5111 Was hydraulic fracturing used during completion? Yes No 0 Wil, DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) waiting on facility hook-up j Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 24-Hour Rate-> 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No Q \ Sidewall Cores Acquired? Yes ❑ No Q . If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. NONE Form 10-407 Revised 10/2012 vrL //3 L`7 / CONTINUED ON REVERSE `rte 001 Submit original only ,41 / ' RBC MS DEC 17 21 29. GEOLOGIC MARKERS(List all formations and mat ncountered): 30 FORMATION TESTS NAME MD TVD Well tested? ❑ Yes Q No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 1242' 1204' needed,and submit detailed test information per 20 AAC 25 071. C-37 5122' 4201' Iceberg 5419' 4380' Top Bermuda 6767' 5220' Base Bermuda 6994' 5368' Top Purple 7041' 5398' Base Purple 7131' 5458' N/A Formation at total depth: Bermuda 31 LIST OF ATTACHMENTS Summary of Daily Operations, schematic,final Directional survey,cement detail sheets 32 I hereby certify that the foregoing is true and correct to the best of my knowledge Contact: Scott Brunswick @ 263-4249 Email: Scott.Brunswickaconocophillios.com '.l Printed Name G. L.Alvord Title Alaska Drilling Manager 4 ..(ak..Signature Phone 265-6120 Date 124(4 ./INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. 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. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other. 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 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level 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 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: 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 26: Method of Operation: Flowing,Gas Lift,Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 Tarn 2N-319A Rotary Sideti. fopset Conventional Slant Producer ConoeoPhillips Completed Wellbore Schematic -FMC Gen V 3-1/2"TREE Updated 11/26/14 16" Existing Cemented Conductor: 16"62.5#H-40 108' MD 3 W Camco i DS Nipple 2.875" 519.57'MD 3'A"x 1"Cameo KBG2-9 w/DK-1A Dummy Valve Existing Surface Casing: at 2,698' 7-5/8"29.7#L-80 BTCM 2,439' MD/2,308'TVD @ 41° 3'A"x 1"Camco KBG2-9 w/ DK-1A Dummy Valve at "__-- Sidetrack KOP off cement plug©—42 degrees in open hole @ 2,465-2,485'MD 4,235' \\ 1 Campanian Top 2N-319Awp04 2746'MD 2528'TVD Tubing: 3 M"x 1"Camco KBG2-9 el 0 3-1/2"9.3#L-80 EU E M 8RD w/DK-1A Dummy Valve at 5,468' a TOC 15.8 ppg©+/-4,500'MD 3'A"x 1"Camco KBG2- 9 w/DCK-3 Shear Valve at 6,252' IceBerg Top 2N-319Awp04 5420'MD 4363'TVD Baker CM\II'a lve a ��5 sleeve(cloKBH-22 Anchor Seal Assy with 3-1/2' 2.812"DS 6311' EUE Box Up e 3-14"X 5-%"SABL-3 Permanent �� . Packer w/2.78"ID at 6,364' 2.75"XLanding : 1>f •w/2.635ZXP Liner Top Packer 200'+ inside 5-14"Csg No-go at0,lHR ZXP/Flex Lock IV Liner Hangerw/6'Tieback @ 3 - "B-i'",., <4 � :- •.pe Wrellne .�',! Intermediate Casino Topset: de end at V; 5-1/2"15.5#L-80 Hydril 563 to-6,072.55' s 5-1/2"15.5#TN110ss Hydril 563 connections to I5d < 6,570'/5,094'TVD 51° ® 6-'4"Hole TD 6,580'MD/5,100'TVD. ... .......': .i RA tag at. 'E E ,: :. : -6,828'.. LSND -;. . . 9.8-10.0 PPG ' ore Perfs Bermuda P Pressure .\ • 11.6PPg EMW proposed- I 6,965 to J:xietlna Production Casma 6,990 MD \ is 55'x35 L80155#&93#LTC-M H H.: I•: 7,018'MD/5,585'TVD Base Bermuda 2N-319Awp04 7,029'MD 5,365' TVD Cemented Production Liner: 3-1/2"9.3#L-80 Hydril 511 7,290' MD/5,562'TVD @ 49° ConocoPhiIIips Time Log & Summary Wellview Web Reporting Report Well Name: 2N-319 Rig Name: NABORS 9ES Job Type: DRILLING SIDETRACK Rig Accept: 10/25/2014 6:00:00 PM Rig Release: 11/27/2014 12:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10/24/2014 24 hr Summary . Moving Rig to 2N-319A. 15:00 00:00 9.00 MIRU MOVE MOB P Move rig f/@N350A to 2N319A 10/25/2014 Move Rig over 2N-319A, Rig accepted 1800 hrs 10/25/2014. R/U surface lines to the annulus and test the annulus,tubing and BPV to 2000 psi. R/U Lubricator to pull BPV. Note: Pumping @ 1/2 bbl/min @ 1500 psi-Tbg possible not cut all the way-Talked w/drilling Engineer and Halliburton E line to recut tbg 00:00 18:00 18.00 0 0 MIRU MOVE MOB P Move Rig over 2N-319A 18:00 22:00 4.00 0 0 MIRU WELCTL RURD P R/U surface lines to Annulus and pressure test to 2500 psi. 22:00 23:00 1.00 0 0 MIRU WELCTL PRTS P Test IA, TBG and BPV to 2000 psi for 10 minutes. Good Test 23:00 00:00 1.00 0 0 MIRU WELCTL RURD P R/U to test Lubricator 250/2000 psi, 10/26/2014 Displace well with 150 bbls of Seawater, pump.5 bpm @ 1550 psi. Pump 30 bbl Hi Vis Sweep and chase with 60 bbls of 9.8 ppg Brine. Run E Line with RCT and cut the TBG©2802'. N/D Tree-Set blanking plug and N/U BOPE. 00:00 02:00 2.00 0 0 MIRU WELCTL SEQP P R/U Lubricator,test to 2000 psi and pull BPV. 02:00 07:00 5.00 0 0 MIRU WELCTL DISP P Displace well with hot seawater, 150 bbls @.50 bpm, 1550 psi. Determined TBG has partial cut, called out Haliburton with E Line and RCT 07:00 12:00 5.00 0 0 MIRU WELCTL DISP P Pump 30 bbls Hi Vis Sweep, chase with 60 bbls of 9.98 ppg Brine @ 5 bpm, 1500 psi. 12:00 12:30 0.50 0 0 MIRU WELCTL OWFF P Observe well for flow for 30 minutes. (Well Static) 12:30 13:00 0.50 0 0 MIRU WELCTL SEQP P Test surface lines to Tiger Tank, bleed OA to Tinger Tank, 380 psi. 13:00 19:00 6.00 0 0 MIRU WELCTL ELNE X Run E line in the hole with RCT and cut @ 2802', pump 11 bbls, 9.8 ppg Brine @ 3 bbpm, 1300 psi. 19:00 20:30 1.50 0 0 MIRU WHDBO MPSP P Set TWC and test to 2000 psi for 10 minutes. 20:30 22:30 2.00 0 0 MIRU WHDBO NUND P Nipple down Tree 22:30 00:00 1.50 0 0 MIRU WHDBO NUND P Nipple up BOPE 10/27/2014 Test BOPE-RU to pull 3 1/2"tbg-MU landing jt-Back out LDS-Pulled hanger to rig floor(55 k PU wt)LD hanger-Circ 2X btms up w/9.8 ppg brine-Flow Ck well static-Pulled&laid down 47 jts 3 1/2"tbg 00:00 04:00 4.00 0 0 MIRU WHDBO NUND P Nipple Up BOPE, RKB Lower LDS= 27.64, Upper LDS=25.43 Page 1 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:00 16:00 12.00 0 0 MIRU WHDBO BOPE P Test BOPE 250 low/3500 psi high. Test Blinds, Choke Manifold, Demco Kill, HCR Kill, Super Choke, Manual Kill. P/U 3 1/2"test joint and test Top Rams, Dart Valve,TIW, !BOP, HCR Choke,TD TIW, Manual Choke. Koomey pressure 2900 psi, Manifold pressure 1600 psi,Annular pressure 1250 psi, 6 NO2 bottles 1950 psi, 185 sec to full pressure,44 sec to 200 psi. Conoco draw down, 190 sec to 2500 psi with air pumps,67 sec to 3000 psi with electric pump. 16:00 18:00 2.00 0 0 SLOT RPCOM RURD P Pull TWC, R/U to lay down Hanger and TBG. 18:00 18:30 0.50 0 0 SLOT RPCOM SVRG P Service Rig,grease TD, Drawworks. 18:30 00:00 5.50 0 0 SLOT RPCOM PULL P Back out LDS-Unseat tbg hanger& pull to rig floor(PU wt 55 K)-LCD hanger-Circ 2X btms up-flow ck static-Pulled&Ld 87 jts 3 1/2"9.3# EUE 8RD tbg 10/28/2014 Finish POOH&LD 3 1/2"tbg-RU&test pipe rams&annular w/4"&5 1/2"test jts.-PU&stand back 4" DP in derrick 00:00 04:30 4.50 0 0 SLOT RPCOM PULL P Cont.pulling and layind down 3 1/2" tbg. Laid down Camco DS nipple-41 jts tbg-Camco GLM assembly& cut-off jt(14.41")total lenght of fish 2779.30'-top of tbg stub f/RKB 2804.73'-RD tongs-Clean up rig floor.-Calc fill 9.6 bbls-Actual fill 11.2 bbls 04:30 05:00 0.50 0 0 SLOT PLUG BOPE P Set test plug-RU to test BOPE w/ 4"&5 1/2"test jts. 05:00 07:00 2.00 0 0 SLOT PLUG BOPE P Test Annular-upper VBR-Lower VBR w/4"&5 1/2"test jts.to 250 psi low&3500 psi high 07:00 08:00 1.00 0 0 SLOT PLUG BOPE P Pull test plug-Blow down choke manifold-choke&kill lines-Set wear bushing- 10 3/4"OD-9"ID 08:00 12:00 4.00 0 0 SLOT PLUG RURD P Perform"Norm"check on 3 1/2"tbg in pipe shed-unload tbg f/shed- Load 4"DP in shed&strap-change elevators to 4" 12:00 18:00 6.00 0 0 SLOT PLUG PULD P PU 4"DP f/shed&stand back in derrick via mouse hole 18:00 18:30 0.50 0 0 SLOT PLUG SVRG P Service rig-Draw works-TD& crown 18:30 22:00 3.50 0 0 SLOT PLUG PULD P Cont. PU 4"DP f/shed&stand back in derrick-stood back 192 jts(64 stds)-PU&stood back 12 jts 4" HWDP(4 stds) 22:00 23:00 1.00 0 0 SLOT PLUG RURD P MU kelly hose to TD&pressure test to 2500 psi(Note hose removed to PU DP) 23:00 00:00 1.00 0 0 SLOT PLUG ELNE P RU"Dutch riser"for E line work Page 2 of 30 • Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 10/29/2014 24 hr Summary Service rig while waiting on HES E line crew-RU E Line run 4.77"guage ring/junk bskt to 2791'-Ran&set CIBP on E line@ 2614'-RIH w/Jet cutter&cut 5 1/2"csg @ 2591'-RD E line-MU landing jt. &pull csg hanger to rig floor-broke over @ 112 k-Attempt to gain circulation-Worked pipe gained circulation- Displace well w/9.8 ppg brine 00:00 05:00 5.00 0 0 SLOT PLUG SVRG T Service rig -TD,blocks,crown,draw works,torque tube,-MU irculating hose to Dutch Riser While waiting on HES E-line crew 05:00 06:00 1.00 0 0 SLOT PLUG ELNE P PJSM on RU E line-RU HES E line 06:00 13:30 7.50 0 0 SLOT PLUG ELNE P PJSM-Pressure test dutch riser to 1000 psi for 5 mins.-Ran gauge ring (4.77"OD)&junk bskt to 2791'- POOH w/tools&change tools-MU Baker Modle K-1 CIBP&RIH w/CCL &GR- Coralate to get on depth- Set plug @ 2614.44'-POOH w/E line&tools 13:30 14:00 0.50 0 0 SLOT PLUG PRTS P RU&pressure test CIBP to 2500 psi for 10 mins. -(Good Test)RD& blow down lines 14:00 17:00 3.00 0 0 SLOT PLUG ELNE P MU HES Jet cutter-RIH&get on depth-Jet cut 5 1/2"csg @ 2591'- POOH w/E line&RD 17:00 18:30 1.50 0 0 SLOT PLUG RURD P Pull wear bushing-MU pack-off running tool-RIH&engage pack-off -pull pack-off-LD pack-off& ruinning tool 18:30 19:00 0.50 0 0 SLOT PLUG RURD P PU landing jt&MU to csg hanger 19:00 22:00 3.00 0 0 SLOT PLUG PULL P Unseat csg hanger PU wt 112 k-45 k over calc. string wt.-PU wt dropped off to 75 k-worked pipe up[ &attempted to circ-@ 250 to 350 psi-No returns-pipe free PU wt 80 k SO wt.49 k-worked pipe up 65' serveral times attempting to break circulation-No returns 22:00 23:00 1.00 0 0 SLOT PLUG RURD P LD landing jt.-RU long bales-XO w/TIW valve&power tongs 23:00 23:30 0.50 0 0 SLOT PLUG PULL P MU landing jt. -Pull csg hnager back to rig floor-PU wt 70 k w/450 psi pump pressure-no returns--W/ hanger just below floor-gained circulation 23:30 00:00 0.50 0 0 SLOT PLUG CIRC P Closed annular- lined up to pump to Tiger tank-Circ out freeze protect W/9.8 ppg brine @ 2 bbls/min @ 100 psi 10/30/2014 Finish displacing well to 9.8 ppg brine-monitor well(static)-RU&Pull 5 1/2"csg-Circ @ 2301' -Gas break out @ btms up-Monitor well-Wash down to 2591'w./DP-Circ&displace 9.8 ppg brine to 10.0 ppg LSND-Pump out of hole to 2336'-Circ hole clean-Pump out to 2301'&std back DP- RU to Pull&LD 5 1/2"cs -Pump outw/5 1/2"csg f/2301'to 1912' 00:00 00:30 0.50 2,589 2,589 SLOT PLUG CIRC P Cont. displacing well to 9.8 ppg brine -taking returns to Tiger tank- Pumped 76 bbls Page 3 of 30 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 00:30 01:00 0.50 2,589 2,589 SLOT PLUG OWFF P Monitor well for 30 mins. @ Tiger tank-Open HCR kill No pressure- Open Hydril-fill hole-monitor for 15 mins-well static 01:00 02:30 1.50 2,589 2,561 SLOT PLUG RURD P Pulled&LA csg hanger-Change bales MU XO's to FSV 02:30 03:30 1.00 2,561 2,301 SLOT PLUG PULL P Pull&LD 5 1/2"csg f/2561'to 2301' (6jts)-PUwt67k SOwt60k- hole began to swab 03:30 04:00 0.50 2,301 2,301 SLOT PLUG CIRC P RU&circ btms up-observed gas break out @ btms up 04:00 04:30 0.50 2,301 23,012 SLOT PLUG OWFF P Monitor well for 30 mins.-Observed slight oozing after 30 mins. 04:30 11:00 6.50 2,301 2,301 SLOT PLUG CIRC T Circ btms up Observed gas break out @ btm up-Cont.to circ while taking on LSND mud&weighting up to 10.0 ppg 11:00 12:00 1.00 2,301 2,589 SLOT PLUG WASH T MU OX f/5 1/2"LT&C to HT-40 -MU 4"HWDP to XO-wash down w/5 1/2"csg&4"HWDP f 2301'to 2589' @ 6 bbls/min© 100 psi-PU wt 71 k SO wt62k 12:00 13:00 1.00 2,589 2,589 SLOT PLUG CIRC T Circ holw clean @ 4 bbls/min @ 250 psi 13:00 14:00 1.00 2,589 2,589 SLOT PLUG CIRC T Change well over f/9.8 ppg brine to 10.0 ppg LSND mud @ 3 1/2 bbls/min @ 210 psi-taking returns to Tiger tank 14:00 15:00 1.00 2,589 2,589 SLOT PLUG CIRC T Switch totake returnes to shakers- Continue to circ hole clean @ 4 bbls/min @ 190 psi-Observed large amiunt of cuttings @ shakers(Mud logger checked samples(Mud stone)-flow ck well static 15:00 18:00 3.00 2,589 2,301 SLOT PLUG PULL T POOH w/pump f/2589'to 2301'@ 4 bbls/min @ 190 psi-LD 1 jt.4"DP- Std back 3 stds 4"HWDP 18:00 19:00 1.00 2,301 2,301 SLOT PLUG RURD P Change elevator f/DP to casing- change to long bales-RU csg tongs 19:00 00:00 5.00 2,301 1,912 SLOT PLUG PULL P POOH&LD 5 1/2"csg f/2301'to 1912'-pumping @ 5 bbls/min @ 245 psi-LD9jts. 10/31/2014 Finished POOH w/5 1/2"csg w/pump-RU&run 3 1/2"cmt stringer to 902'-RIH w/tbg stringer on 4"DP to 2042' 00:00 06:00 6.00 1,912 973 SLOT PLUG PULL P POOH w/5 1/2"csg f/1912'to 1868' w/pump @ 5 bbls/min200 psi- Pulled f/1868'to 1825'w/no pump- hole swabbing-RIH f/1825'to 1843' took wt. unable to work down past 1843'pulled back to 1825'-LD jt# 17-Cont POOH w/pump f/1825'to 973'(38 jts laid down) @ 5 bbls/min @ 200 psi- 06:00 09:00 3.00 973 941 SLOT PLUG PULL P POOH w/pump f/973"to 941'w/ various pump rates-12 bbls/min @ 330 psi- 11 bbls/min @ 270 psi (attempting to clean hole) Page 4of30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 09:30 0.50 941 941 SLOT PLUG CIRC P Pumped Hi-Vis sweep @ 10 bbls/min @ 285 psi-Observed no cuttings @ shakers 09:30 17:00 7.50 941 0 SLOT PLUG PULL P Cont.to POOH w/pump f/941'to cut jt. @ 6 bbls/min @ 117 psi-Laid down total of 60 jts-(2552.28')Cut jt 7.70'-Top of 5 1/2"sutb @ 2589.63' RKB- Bottom of cut jt was flared out to just under 6.875"(ID of 75/8"29.7#) 17:00 20:30 3.50 0 0 SLOT PLUG RURD P Clean up rig floor-blow down mud lines-Set wear bushing-change bales f/long to shortRU to run 3 1/2" tbg stinger 20:30 22:30 2.00 0 902 SLOT PLUG PULD P RIH w/Mule shoe&29 jts 3 1/2" 9.3#EUE 8 rd tbg to 902' 22:30 00:00 1.50 902 2,042 SLOT PLUG TRIP P RIH w/3 1/2"cmt stinger on 4"DP to 2042' 11/01/2014 Finish RIH w/cmt stinger-Circ-Set KOP w/25 bbls17.0 ppg-POOH to 2228'-Circ(Observed mud push& appox.2 bbls cmt)POOH LD 3 1/2"stinger- 00:00 00:30 0.50 2,042 2,613 SLOT PLUG TRIP P Cont. RIH w/3 1/2"cmt stinger on 4" DP f/2042'to 2518'-Wash down @ 5 bbls/min @ 260 psi f/2518'to 2613"(tagged CIBP-set 5 k down to confirm)-PU wt 55 k SO wt 55 k 00:30 02:30 2.00 2,613 2,613 SLOT PLUG CIRC P Circ&condition for cement job-@ 5 bbls/min @ 200 psi-Held PJSM w/ crew&Dowell-Closed Annular& establish circ rate through choke manifold to pits-5 bbl/s @ 315 psi 02:30 03:00 0.50 2,613 2,613 SLOT PLUG CMNT P Set KOp as follows: Dowell pumped 5 bbls. 12.5 ppg MudPush-Tested lines to 4000 psi-Pumped 10 bbls MudPush @ 12.5 ppg @ 5 bbls/min @ 250 psi-Shutdown closed HCR choke-Loaded foam nerf ball into DP-Opened HCR choke-Pumped 25 bbls. 17.0 ppg cmt @ 5 bbls/min @ 250 psi-Pumped 5 bbls 12.5 ppg MuPush behind-Switched to rig pumps&displaced w/12.8 bbls 10.0 ppg LSND mud @ 5 bbls/min @ 225 psi-CIP @)300 hrs. 03:00 03:15 0.25 2,613 2,613 SLOT PLUG RURD P Open Annular-RD cmt line and head pin 03:15 04:00 0.75 2,613 2,232 SLOT PLUG TRIP P POOH f/2613'to 2232'-PU wt 55 k 04:00 04:30 0.50 2,232 2,232 SLOT PLUG CIRC P Loaded foam Nerf ball-Pump ball through string to clean pipe-Circ @ 2232'@ 8 bbls/min @ 430 psi- Observed MudPush&2 bbls of cement @ btms up 04:30 05:30 1.00 2,232 902 SLOT PLUG TRIP P POOH f/2232' w/4"DP to top of 3 1/2"cmt stinger @ 902' 05:30 08:00 2.50 902 0 SLOT PLUG PULD P Pull and LD 3 1/2:tbg stinger(29 jts +mule shoe) 08:00 09:00 1.00 0 0 SLOT PLUG RURD P RD tbg tongs&LD f/f rig floor Page 5 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 12:00 3.00 0 0 SLOT PLUG ELNE P PJSM-RU Dutch riser-RU HES- M U tools-Test pack off to 500 psi 12:00 14:30 2.50 0 0 SLOT PLUG ELNE P Ran Mutlifinger caliper log in 7 5/8" surface casing 14:30 15:30 1.00 0 0 SLOT PLUG ELNE P RDE line-blow down lines-RD Dutch riser 15:30 17:00 1.50 0 0 SLOT WHDBO RURD P RU to test BOPE-MU TIW/Dart valves-Pull wear bushing-Set Test plugw/4"test jt. Fill stack&choke manifold w/water 17:00 22:30 5.50 0 0 SLOT WHDBO BOPE P Test BOPE-Tested Annular, Upper &Lower VBR rams, Choke&kill line valves, Choke manifold valves, floor safety&dart valves,TD IBOP's Blind rams to 250&3500 psi-Tested Hyd &manual chokes for positive pressure-Performed accumulator recovery test.Accumulator staring pressure 2900 psi- functioned rams &HRC's-pressure @ 1700 psi- regained 200 psi in 36 secs.w/ electric pump opened valve for air pumps back to full charge in 155 secs.-Performed ConocoPhillips accumulator test Air pump 4 min 40 sec. (closed Hydril)Electric pump 65 secs.-LD 4"test jt&PU 5 1/2" testjt-Tested Annular, Upper& Lower VBR to 250 psi low&3500 psi high- Witnessing of test waived by Chuck Scheve AOGCC 22:30 23:00 0.50 0 0 SLOT WHDBO RURD P Piull test plug&LD 5 1/2"testjt.- RD test equipment&blow down lines&choke manifold-Set wear bushing 23:00 00:00 1.00 0 0 INTRM1 DRILL PULD P PU BHA components to rig floor- Prep handling tools to MU BHA 11/02/2014 Finish MU BHA#1 -RIH to 2045'-Test tools-Change hole over to 9.6 ppg LSND mud- Slip&cut drill line- Wash down @ tag cmt @ 2232'-CO to 2236' -circ hole clean-Test casing to 2500 psi for 30 mins.-Co cmt to 2331'-Lost 190 psi pump pressure&MWD tool stopped pulsing-Check surface equipment-Drop tags&ck UR-Trouble shoot MWD-POOH-test UR(OK)LD BHA-Down load MWD 00:00 01:00 1.00 0 0 INTRMI DRILL SFTY T Clear ice build up in derrick(Safety- Drops) 01:00 04:00 3.00 0 132 INTRM1 DRILL PULD P PJSM-MU BHA#1 -Roatry Steerable-6 3/4"PDC bit-Power Drive-Impulse-VPWD-adn VISION-NM pony DC-NM stab- Rip Tide UR 04:00 05:00 1.00 132 132 INTRMI DRILL DHEQ P Surface test Rip Tide UR @ 40 spm @ 250 psi, 50 spm @ 360 psi , 60 spm @ 515 psi- Observed tool open &close-Changed out blank test jets to(3)5/32 jets-Blow down TD 05:00 06:00 1.00 132 132 INTRMI DRILL PULD P Pull up&LD Ripe Tide UR , NM stab&Pony DC-Install RA source i adn VISION tool-PU Pony DC, NM Stab&Rip Tide UR Page 6 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 07:00 1.00 132 620 INTRM1 DRILL PULD P Cont. MU BHA#1 -(1) NM flex DC, XO sub-6jts4" HWDP-Jars-8jts 4"HWDP to 619.84' 07:00 07:30 0.50 620 2,045 INTRM1 DRILL TRIP P Trip in hole w/BHA# 1 on 4" Dp f/ 620'to 2045' -PU wt 45 k SO wt 45 k 07:30 09:00 1.50 2,045 2,045 INTRM1 DRILL DISP P Displace well f/ 10.0 ppg LSND mud to 9.6 ppg LSND mud @ 4.8 bbls/min @ 850 psi- 09:00 09:30 0.50 2,045 2,045 INTRM1 DRILL SFTY P PJSM on slip&cut drill line 09:30 12:00 2.50 2,045 2,045 INTRM1 DRILL SLPC P Slip&cut 76'drill line-Service& inspect TD&draw works-Calibbrate block height-Reset Crown Saver 12:00 12:30 0.50 2,045 2,045 INTRM1 DRILL DHEQ P Shallow test MWD tools @ 250 gpm @ 1357 psi(Test OK) 12:30 14:00 1.50 2,045 2,236 INTRM1 DRILL COCF P Wash&ream down f/2045'to 2236' (tag top of cmt @ 2232')Circ btms up @ 250 gpm @ 1300 psi w/40 rpm's @ 2.1 k torque-ROT wt. 76 k 14:00 15:30 1.50 2,236 2,236 INTRM1 DRILL PRTS P RU&test 7 5/8"casing to 2500 psi for 30 mins. (Good Test)RD 15:30 16:30 1.00 2,236 2,331 INTRM1 DRILL DRLG P Drilled cmt f/2236'to 2331' MD- ADT 1 hr WOB 5 k RPM 40 GPM 290 @ 1495 psi PUwt73k SOwt68k ROTwt. 70 k Torque on/off btm.-3.5 k/1.6 k 16:30 17:00 0.50 2,331 2,331 INTRM1 DRILL CIRC T Lost 190 psi pump pressure&MWD tool stopped pulsing-Circ and test tool 17:00 19:00 2.00 2,331 2,045 INTRM1 DRILL TRIP T POOH f/2331'to 2045'-Drop tags and pump down to check UR-Cont. to trouble shoot MWD-Blow down TD 19:00 19:30 0.50 2,045 619 INTRM1 DRILL TRIP T POOH f/2045'to 619'(top of BHA) PU wt 70 k SO wt 65-Flow ck (Static) 19:30 00:00 4.50 619 0 INTRM1 DRILL PULD T Stand back HWDP&Jars-LD Xo& Flex DC-LD UR/stab-pony DC- Remove RA source-PU UR&Test- UR functioned properly-LD UR/Sttab/Pony DC/VisionNPWD/ & Impulse-Down load MWD 7 cont. to trouble shoot 11/03/2014 MU BHA#2- RIH to 2045' Shallow test MWD tools- RIH to 2331'-Drill cmt to 2436'- Begin side track-Off plug @ 2465'-Drill to 2485' (New hole)Circ hole clean- RU&perform LOT to 14.2 ppg EWM-Drilled 6 3/4" hole to 2568'-Opened Rip Tide UR @ 2570'-Pulled back to 2558' (blades 117'behind bit 2441"beginning of 7 1/2" hole Drilled 6 3/4"x 7 1/2" hole w/RSS& Rip tide UR to 3284' Page 7 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 03:00 3.00 I 0 619 INTRM1 DRILL PULD T PJSM-MU BHA#2- Roatry Steerable-6 3/4" PDC bit-Power Drive-Impulse-VPWD-adn VISION-Load RA source-MU NM pony DC-NM stab-Rip Tide UR- NM flex DC-XO-6 jts HWDP-Jars -8 jts HWDP to 619'-PU wt 45 k SO wt 45 k Only change to BHA#2-New Impulse tool 03:00 03:30 0.50 619 2,045 INTRM1 DRILL TRIP T RIH w/BHA#2 f/619'to 2045'-PU wt 65 k SO wt 60 k 03:30 05:30 2.00 2,045 2,045 INTRM1 DRILL DHEQ T Shallow pulse MWD tools-Stage pump up to 225 gpm @ 1095 psi- Good test-Work on computer to read&record data in MWD shack 05:30 06:00 0.50 2,045 2,331 INTRM1 DRILL TRIP T RIH f/2045'to 2236'-Wash down to 2331'-@ 220 gpm@ 1080 psi -PU wt 72 k SO wt 65 k 06:00 08:00 2.00 2,331 2,436 INTRM1 DRILL COCF P Drilled cmt f/2331'to 2436' MD 2310' TVD ADT.75 hrs. WOB 5/8 k RPM 50 GPM 217 @ 1075 psi Torque on/off btm.-3.5 k/1.5 k SPR @ 2436' MD 2310'TVD @ 0800 hrs. #1 2 bbls/min @ 210 psi 3 bbls/min @ 370 psi #2 2 bbls/min @ 220 psi 3 bbls/min @ 370 psi 08:00 10:30 2.50 2,436 2,485 INTRM1 DRILL DDRL P Drill f/2436'to 2440'-Begin side track-Drilled to 2465' (Off of plug) Drilled 20' new hole to 2485' MD 2332'TVD ADT.75 hr WOB 5 k RPM 50 GPM 265 @ 1500 psi String wt. PU 75 SO 65 ROT 73 Torque on/off btm.-3.5 k/1.5 k Samples confirmed drilling formation 10:30 11:30 1.00 2,485 2,485 INTRM1 DRILL CIRC P Circ hole clean for FIT @ 265 gpm @ 11490 psi-Pulled 1 std back to 2426'(for FIT) 11:30 12:30 1.00 2,485 2,485 INTRM1 DRILL FIT P RU&perform FIT/LOT @ 7 5/8"csg shoe @ 2441' MD 2310'TVD- Pumped 1/2 bbl observed LOT @ 550 psi w/9.6 ppm= 14.2 ppg EMW -Blow down lines&rig down Page 8 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:30 18:00 5.50 2,426 2,807 INTRM1 DRILL DDRL P Directionally Drilled 6 3/4"x 7 1/2" hole f/2485'to 2807'MD 2578'TVD ADT 5.17 hrs. WOB 7 k RPM 120 GPM 330 @ 1500 psi String wt. PU 81 k SO 71 k ROT 74 k Torque on/off btm.4.5 k/1.7 k Opened Rip Tide @ 2570'bit depth- Pulled back to 2558' 117'f/bit to UR blades-Start of 7 1/2"hole @ 2441" SPR @ 2420' MD 2332'TVD @ 1550 hrs #1 2 bbls/min @ 220 psi 3 bbls/min @ 380 psi #2 2 bbls/min @ 220 psi 3 bbls/min @ 370 psi 18:00 00:00 6.00 2,807 3,284 INTRM1 DRILL DDRL P Directionally Drilled 6 3/4"x 7 1/2" hole w/RSS&UR f/2807'to 3284' MT 2925; TVD ADT-4.52 hrs. Footage-477' WOB7k RPM 120 GPM 328@ 1875 psi String wt PU 90 k SO 75 k ROT 80 k Torque on/off btm 3 k/2 k SPR @ 3189' MD 2857'TVD @ 2200 hrs #1 2 bbls/min @ 220 psi 3 bbls/min @ 350 psi #2 2 bbls/min @ 230 psi 3 bbls/min @ 360 psi 11/04/2014 Drilled 6 3/4"x 7 1/2"hole f/3284'to 4428'-Circ hole clean-Close Rip Tide-Wper trip f/4428'to 2426' Page 9 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 3,284 3,761 INTRM1 DRILL DDRL P Drilled 6 3/4"x 7 1/2"hole f/3284'to 3761'MD 3274'TVD ADT-4.2 hrs. Footage 477' WOB 5 k RPM 120 GPM 325 @ 1910 psi String wt. PU 88 k SO 75 k ROT 78 k Torque on/off btm.-4.3 k/2.8 k SPR©0430 hrs 3665' MD 3198' TVD #1 2 bbls/min©240 psi 3 bbls/min @ 370 psi #2 2 bbls/min @ 240 psi 3 bbls/min @ 370 psi Pumped Hi-Vis sweep every 300' 06:00 12:00 6.00 3,761 4,170 INTRM1 DRILL DDRL P Drilled 6 3/4"x 7 1/2"hole f/3761'to 4170' MD 3586'TVD ADT-3.8 hrs. Footage-409' WOB 5 k RPM 120 GPM 328 @ 1998 psi String wt. PU 95 k SO 80 k ROT 85 k Torque on/off btm.-4.8 k/3.8 k SRP @ 11:15 hrs @ 4143' MD 3559'TVD #1 2 bbls/min @ 240 psi 3 bbls/min @ 380 psi #2 2 bbls/min©240 psi 3 bbls/min ©390 psi Pumped Hi-Vis sweep every 300' 12:00 15:00 3.00 4,170 4,358 INTRM1 DRILL DDRL P Drilled 6 3/4"x 7 1/2"hole f/4170'to 4358' MD WOB-6.5 k RPM 120 GPM 328 @ 2000 psi String wt. PU 105 k SO 83 k ROT 88 k Torque on/off btm.-5/3.7 k 15:00 16:00 1.00 4,358 4,358 INTRM1 DRILL EQRP T Trouble shoot CanRig Rig Watch system Page 10 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 17:00 1.00 4,358 4,428 INTRM1 DRILL DDRL P Drilled 6 3/4"x 7 1/2"hole f/4358'to 4428'MD 3764'TVD ADT-2.99 hrs Footage-258' Time&footage since noon) WOB 7 k RPM 120 GPM 330 @ 2020 psi String wt. PU 108 k SO 83 k ROT 89 k Torque on/off btm.-6.9/4 k SPR @ 1725' @ 4428'MD 3764' TVD #1 2 bbls/min @ 250 psi 3 bbls/min @ 390 psi #2 2 bbls/min @ 260 psi 3 bbls/min @ 390 psi 17:00 19:00 2.00 4,428 4,428 INTRM1 DRILL CIRC P Pumped Hi-Vis sweep-Dropped tag&closed Rip Tide-Monitor well (Static) 19:00 00:00 5.00 4,428 2,426 INTRM1 DRILL WPRT P Made wiper trip f/4428'to 2426'-w/ pump @ 247 gpm @ 1640 psi w/120 rpm's-pulling @ 1200'/hr.- Observed slight pull when Rip Tide came into casing 11/05/2014 Circ btms up-Flow ck-RIH f/2426'to 4332'-Drop&pump down tags to open Rip Tide-Circ btms up- Drilled 6 3/4"x 7 1/2"hole f/4428'to 5729' 00:00 01:00 1.00 2,522 2,426 INTRM1 DRILL WPRT P Cont.with wiper trip-f/2522'to 2426'@ 250 gpm @ 1485 psi PU wt 65 k- Circ btms up @ 2426'to clean up casing 01:00 01:30 0.50 2,426 2,426 INTRM1 DRILL OWFF P Blow down TD-Monitor well(Static) 01:30 03:00 1.50 2,426 4,332 INTRM1 DRILL TRIP P RIH f/2426'to 4332'-PU wt 78 SO wt 65-Hole in good condition no tight spots-Calc displacement 12.6 bbls-Actual- 17.2 bbls 03:00 03:30 0.50 4,332 4,428 INTRM1 DRILL WASH P Wash down f/4332'to 4428'@ 250 gpm @ 1660 psi w/50 rpm w/3.8 k torque-ROT wt 90 k PU wt 100 k SO wt 85 k-Circ btms up @ 4428' 03:30 04:00 0.50 4,428 4,428 INTRM1 DRILL CIRC P Drop 4 RFID tags&pumped down to open RiP Tide UR @ 250 gpm @ 1632 psi w/50 rpms w/3.8 k torque @ 505 stroks pressure dropped to 1344 psi&torque increased to 4.2 k to confirm under reamer is open- Down link w/MWD Page 11 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:00 12:00 8.00 4,428 4,999 INTRM1 DRILL DDRL P Drilled 6 3/4"x 7 1/2"hole f/4428'to 4999'MD 4112'TVD ADT-5.36 hrs Footage-571' WOB 6 k RPM 100 GPM 328 @ 2140 psi String wt. PU 105 k SO wt 85 k ROT wt 93 k Torque on/off btm.-5.6/3.8 k Pumping Hi-Vis sweeps every 300' sweeps still bringing good amount of cuttings back) SPR @ 1040 hrs. @ 4904' MD 4066' TVD # 1 2 bbls/min @ 270 psi 3 bbls/min @ 410 psi #2 2 bbls/min @ 260 psi 3 bbls/min @ 410 psi 12:00 18:00 6.00 4,999 5,379 INTRM1 DRILL DDRL P Drilled 6 3/4"x 7 1/2"hole f/4999'to 5379' MD 4350'TVD ADT-4.2 hrs. Footage-380' WOB 5 k RPM 100 GPM 325 @ 2140 psi String wt. PU 114 k SO 93 k ROT 98 k Torque on/off btm.-6.3/5.3 k SPR @ 1730 hrs. @ 5379'MD 4350 'TVD # 1 2 bbls/min @ 290 psi 3 bbls/min @ 430 psi #2 2 bbls/min @ 290 psi 3 bbls/min @ 43 psi 18:00 00:00 6.00 5,379 5,729 INTRM1 DRILL DDRL P Drilled 6 3/4"x 7 1/2"hole f/5379'to 5729' MD 4584'TVD ADT-4.55 hrs Footage-350' WOB 5/10 k RPM 120 GPM 328 @ 2230 psi String wt. PU 120 SO 92 ROT 101 Torque on/off btm.-7.8/6.5 k Pumping Hi-vis sweeps every 300' 11/06/2014 Drilled 6 3/4"x 7 1/2"hole f/5729'to 6580'TD of section-Circ&close UR-Circ 3X btms up std back 1 std DP every 30 mins. f/6580'to 6235'-BROOH f/6235'to 4522' Page 12 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 5,729 6,138 INTRM1 DRILL DDRL P Drilled 6 3/4"x 7 1/2"hole f/5729'to 6138'MD 4826'TVD ADT-4.15 hrs Footage-409' WOB 5/10 k RPM 120 GPM 328 @ 2280 psi String wt. PU 118 SO 90 ROT 100 Torque on/off btm.-7.6/5.3 k Pumping Hi-vis sweeps every 300' 06:00 12:00 6.00 6,138 6,520 INTRM1 DRILL DDRL P Drilled 6 3/4"x 7 1/2"hole f/6138'to 6520'MD 5049'TVD ADT-4.15 hrs Footage-382' WOB 5/10 k RPM 100 GPM 330 ©2500 psi String wt. PU 120 SO 93 ROT 103 Torque on/off btm.-7.8/4.8 k Pumping Hi-vis sweeps every 300' 12:00 13:00 1.00 6,520 6,580 INTRM1 DRILL DDRL P Drilled 6 3/4"x 7 1/2"hole f/6520'to 6580' MD 5100'TVD ADT- .8 hrs. Footage-60' WOB 8 k RPM 100 GPM 330 @ 2475 psi String wt PU 135 SO 97 ROT 100 Torque on/off btm.-7.3/6.3 k SPR @ 1330 hrs. 6580' MD 5100' TVD #1 2 bbls/min @ 300 psi 3 bbls/min @ 500 psi #2 2 bbls/min @ 330 psi 3 bbls/min @ 500 psi 13:00 15:30 2.50 6,580 6,580 INTRM1 CASING CIRC P Drop&pump tags down to close Rip Tide UR-Observed pressure increase-Pumped Hi Vis sweep- Monitor well (static 15:30 18:30 3.00 6,580 6,235 INTRM1 CASING CIRC P Circ 3X btms up @ 240 gpm @ 1525 psi w/110 rpm's-standing back 1 std every 30 min f/6580'to 6235' 18:30 00:00 5.50 6,235 4,522 INTRM1 CASING WPRT P POOH f/6235'to 4522'W pump @ 240 gpm @ 1400 psi w/110 rpms- PU wt 107 SO wt 84 ROT wt 88 11/07/2014 Continue BROOH f/4522't/2426' ( Pump sweep&circ csg clean-Flow ck(well static) POOH& LD 4" DP f/ 2426'to 619'-Flow ck Well static-LD BHA-Pull WB-Made dummy run w/hanger-RU to run 5 1/2"csg- _ Held PJSM on running csg-Begin to run 5 1/2"csg to 126'(FS, 2 jts, FC, 1 jt) 00:00 05:15 5.25 4,522 2,426 INTRM1 CASING REAM P Continue BROOH f/4522'V 2426' 120 rpm 250 gpm 1250 psi 05:15 05:30 0.25 2,426 2,426 INTRM1 CASING OWFF P Observe well for flow well static Page 13 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:30 06:30 1.00 2,426 2,426 INTRM1 CASING CIRC P Circulate and clean out surface casing, pump hi vis sweep 243 gpm 1040 psi, continue circulating until shakers cleaned up. 50 rpm reciprocate pipe while circulating. 06:30 07:00 0.50 2,426 2,426 INTRM1 CASING OWFF P Observe well for flow well static, blow down top drive. 07:00 09:30 2.50 2,426 619 INTRM1 CASING PULD P POOH L/D 4" DP f/2426't/619' 09:30 09:45 0.25 619 619 INTRM1 CASING OWFF P Observe well for flow well static 09:45 15:45 6.00 619 0 INTRM1 CASING PULD P L/D BHA as per MWD/DD& weatherford, L/D RipTide reamer, Unload sources,finish L/D BHA components, Break bit. 15:45 16:45 1.00 0 0 INTRM1 CASING RURD P Clean and clear rig floor, Prep t/pull wear ring, P/U stack washer t/rig floor 16:45 17:15 0.50 0 0 INTRM1 CASING WWWH P Flush BOP stack w/stacke washer 17:15 18:15 1.00 0 0 INTRM1 CASING RURD P MU 5 1/2"hanger on landing jt& make dummy run -LD landing jt. & hanger 18:15 23:00 4.75 0 0 INTRM1 CASING RURD P RU to run 5 1/2"csg-Remove DP elevators-change TD saver sub to 4 1/2 IF-Test saver sub break&TIW valve to 250&3500 psi-Change bales f/short to long-MU Volant tool-MU 5 1/2"elevators 23:00 23:30 0.50 0 0 INTRM1 CASING SFTY P Held PJSM w/crew&service hands on running 5 1/2"csg 23:30 00:00 0.50 0 126 INTRM1 CASING PUTB P Ran 5 1/2"15.5#TN-110 csg as follows: Float shoe(Ray Oil Tools- silver bullet) 2 jts.TN-110 csg- Float collar(Ray Oil Tools) 1 jt. TN-110 csg to 126'-All connections made up w/BakerLoc-Tesco Hydro Form centralizers on each jt. 11/08/2014 Ran 5 1/2" 15.5#Hyd 563 TN-110&L-80 casing to 6537'-Circulated @ 2423'&4490'-MU hanger&landing jt&wash casing down to 6570'-Circ& condition for cmt job 00:00 07:30 7.50 126 2,423 INTRM1 CASING PUTB P Cont. Running 5 1/2" 15.5#HYD 563 TN 110& L-80 csg as follows: Ran 1 jt. TN-110(#4)to 168' Fill pipe and ck floats(OK)jt #4 made -up w/BakerLoc-Continue running 5 1/2" TN-110 f/168' to 497.61'(total of 12 jts TN-110)Began to run L-80 f/ 497.61'to 2423'(total of 58 jts in hole)PU wt 55 SO wt 50-Installed Hydro-Form centralizers on first 50 jts. 07:30 08:00 0.50 2,423 2,423 INTRM1 CASING CIRC P Establish circ&stage pump up f/2 bbls/min @ 350 spi to 6 bbls/min @ 1163 psi &circ btms up 08:00 12:00 4.00 2,423 3,954 INTRM1 CASING PUTB P Continue RIH w/5 1/2" 15.5#Hyd. 563 L-80 csg f/2423'to 3954'(95 jts total in hole) PU wt 83 SO wt 60 Page 14 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 14:00 2.00 3,954 4,490 INTRM1 CASING PUTB P Continue RIH w/5 1/2" 15.5#Hyd 563 L-80 csg f/3954'to 4490'( 108 total jts. in hole) PU wt 90 SO wt 78 14:00 14:30 0.50 4,490 4,490 INTRM1 CASING CIRC P Establish circ&stage pump up to 6 bbls/min @ 1110 psi&circ btms up 14:30 21:30 7.00 4,490 6,537 INTRMI CASING PUTB P Continue RIH w/5 1/2" 15.5#Hyd 563 L-80 csg f/4490'to 6537'(157 jts total in hole)PU wt 125 SO wt 75 k Installed straight blade centralizers f/ jt#100 to#156 on every other jt 29 total 21:30 22:00 0.50 6,537 6,537 INTRM1 CASING PUTB P PU&MU FMC 5 1/2"fluted hanger w/pups_PU&MU landing jt 22:00 00:00 2.00 6,537 6,570 INTRMI CASING CIRC P Establish circ&wash down f/6537'- hole packing off-slowly stage pump up f/2 bbls/min 370 psi to 5 bbls/min @ 950 psi working casing down to land hanger in wellhead w/shoe @ 6570'-FC @ 6485'-Continue circ btms up and working pipe @ 15' stroke-good returns 11/09/2014 Circ&condition for cmt job-Cmt w/75 bbls 12.0 ppg LiteCrete GasBlok slurry-Displaced w/144 bbls 9.6 ppg LSND mud-Bumped plug CIP @ 0500 hrs-RD cmt equipment-Set&tes pack-off-Pumped freeze protect 37 bbls. Iso Therm-LD 4" DP f/derrick-RU to pick up 2 7/8"DP-Flow ck well for 30 mins(Static) 00:00 00:30 0.50 6,570 6,570 INTRM1 CEMEN-CIRCP Cont. circ for cmt job @ 4.5 bbls/min @ 900 psi-working casing w/15' stroke-PUwt110 SOwt75 00:30 01:00 0.50 6,570 6,570 INTRM1 CEMEN-RURD P RD Volant CRT-Blow down TD-RU Dowell cmt head&lines 01:00 03:00 2.00 6,570 6,570 INTRM1 CEMEN"CIRC P Circulate for cmt job-staging pump up f/3 bbls/min @ 394 psi,4 bbls/min @ 545 psi&5 bbls/min @ 725 psi-working pipe w/15'stroke- PUwt110 SOwt70 Held PJSm w/rig crew&Dowell cementers(while circ)Cont.to circ while Dowell batched up MudPush& cmt. 03:00 04:00 1.00 6,570 6,570 INTRM1 CEMEN-CMNT P Cemented 5 1/2"csg as follows; Dowell pumped 5 bbls water-Tested lines to 4000 psi (Good Test)- Dowell pumped 30 bbls CW-100 @ 5 bbls/min @ 980 psi followed by 30 bbls 10.5 ppg MudPush @ 5 bbls/min @ 650 psi-Shut down& lined up valves on cmt head to pump out btm. plug-Dowell pumped 75 bbls 12.0 ppg LiteCrete GasBloc slurry @ 5 bbls/min @ 690 psi-Shut down&lined up valves to drop top plug-Dowell pumped 10 bbls water behind top plug Page 15 of 30 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:00 05:00 1.00 6,570 6,570 INTRM1 CEMEN'CMNT P Switch over to rig pump and displaced cmt.w/9.6 ppg LSND mud @ 5 bbls/min @ 950 psi-w/86 bbls of displacement pumped(18 bbls of cmt out shoe)Obsreved hole packing off&pipe hydraulicing up w/ pressure spike @ 2000 psi&flow dropped f 22%to 7% slowed pump to 4 bbls/min @ 1000 psi-Land hanger-had to continue to reduce pump rate to keep pressure below 2000 psi-final rate was 1.2 bbls/min and bumped plug w/2200 psi-held pressure for 3 mins. bled off to check floats-OK-CIP @ 0455 hrs. Had returns throughout job-final pit strap showed no losses. 05:00 08:00 3.00 6,570 6,570 INTRM1 CEMEN'RURD P Blow down lines-RD cmt lines& cmt head-LD landing jt&drain stack-change bales f/long to short to run pack-off 08:00 10:00 2.00 6,570 6,570 INTRM1 CEMEN'WWSP P MU pack-off running tool and std of DP-RIH&set pack-off-Run in lock down screws-Test pack-off to 5000 psi for 15 mins.-POOH&LD _ running tool 10:00 12:00 2.00 6,570 6,570 INTRM1 CEMEN-PULD P LD GBR Volant CRT-elevators- long bales-remove blower hose& _ kelly hose-clean up rig floor 12:00 13:30 1.50 6,570 6,570 INTRM1 CEMEN-RURD P RU floor to LD 4"DP f/derrick-PU 2 7/8"tools to rig floor 13:30 15:30 2.00 6,570 6,570 INTRM1 CEMEN-FRZP P RU cellar to freeze protect 7 5/8"x 5 1/2"annulus-Pumped 44 bbls water @ 3 bbls/min @ 610 psi-broke over @ 580 psi-Shut down&lined up Little Red pumped 37 bbls Isotherm @ 1.5 to 1.8 bbls/min ©800 psi- Shut down&RD 15:30 20:30 5.00 6,570 6,570 INTRM1 CEMEN'PULD P LD 4"DP f/derrick via mouse hole 93 jts. 20:30 23:30 3.00 6,570 6,570 INTRM1 CEMEN'RURD P RU to PU 2 7/8"DP-Change saver sub/die block/stabbing guide for 2 7/8"pipe-Install elevators-Install pull back rope in derrick for 2 7/8" DP 23:30 00:00 0.50 6,570 6,570 INTRM1 CEMEN-OWFF P Flow check for 30 mins.for kill wt fluid barrier RU cellar for casing test 11/10/2014 Pressure test 5 1/2"csg to 1000 psi for 10 mins-Changed pipe rams(U&L)to 2 7/8"x 5"-RU&test BOPE-Unable to get test on annular-Changed element in annular-RU&test annular w/3 1/2"test jt 250 &3500 psi(Good test) 00:00 01:30 1.50 0 0 INTRM1 CEMEN-PRTS P Cont.to flow ck well for kill wt fluid barrier(Weel Staic)Pressure test 5 1/2"cgs to 1000 psi for 10 mins for test casing barrier-Good test- Page 16 of 30 , Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:30 03:00 1.50 0 0 INTRM1 CEMEN-BOPE P Close blind rams-Change upper pipe rams f/3 1/2"x 6"to 2 7/8"x 5' VBR-clean&inspect door seals 03:00 04:00 1.00 0 0 INTRM1 WHDBO RURD P Pull wear bushing-set test plug 04:00 07:00 3.00 0 0 INTRM1 CEMEN-RURD P Change lower pipe rams f/3 1/2"x 6" to 2 7/8"x 5"VBR-clean&inspect door seals -Check for any tools left from job on rams bodies(OK) 07:00 10:30 3.50 0 0 INTRM1 WHDBO RURD P RU test equipmnet-Fill stack& choke manifold w/water- 10:30 17:00 6.50 0 0 INTRM1 WHDBO BOPE P Test BOPE-tested choke manifold valves, choke&kill line valves,4" Demco on kill line, IBOP's on TD- Blind rams- Upper&lower pipe rams-2 7/8"floor&dart valves to 250&3500 psi- Annular test failed- All tests done w/2 7/8"test jt. - Performed accumulator recovery test -31 secs to 200 psi& 140 secs to full charge-N@ bottles average 2025 psi-LD 2 7/8"test jt. PU 3 1/2"test jt.Tested upper&lower pipe rams to 250&3500 psi- Annualr test failed -LD 3 1/2"test jt -RU test equipment-Witnessing of test waived by Bob Noble AOGCC 17:00 23:30 6.50 0 0 INTRM1 WHDBO BOPE T Remove riser-Remove Dutch riser flange f/top of Annular-LD mouse hole-Remove stabbing guide-MU XO for TD quill to HT-40-MU potatoe masher to top of Annular-Break cap on annular&unscrew&pick up- removed old element&installed new element-RD spud masker-Install Dutch riser flange-Install riser 23:30 00:00 0.50 0 INTRM1 WHDBO BOPE T RU testing equipment fill stack w/ water-Install 3 1/2"test jt.test annular to 250&3500 psi(Good test) 11/11/2014 Test Annular w/2 7/8"TJ-MU 4 3/4"BHA-RIH w/2 7/8" PAC DP f/shed to 5,779-ft. 00:00 02:00 2.00 I INTRM1 WHDBO BOPE P Test annular, inner and outer test spool valve @ 250/3,500 psi with 2-7/8 test joint-Good test 02:00 02:30 0.50 INTRM1 WHDBO RURD P Pull FMC test plug and reinstall wear ring as per FMC rep. 02:30 04:30 2.00 INTRM1 WHDBO RURD P Rig down test equipment and blow down lines. Set up for normal drilling operations and prep floor for MU of BHA. 04:30 08:30 4.00 0 115 INTRM1 CEMEN'PULD P PU, MU and RIH w/4-3/4"Drlg BHA to 115-ft 08:30 09:30 1.00 115 115 INTRM1 CEMEN-SFTY P Held safety stand down with crew on tour regarding Nabors 245 incident findings. Discuss proper Pre-job planning and mitigation. Page 17 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:30 16:30 7.00 115 1,500 INTRM1 CEMEN-PULD P Continue to RIH w/4-3/4 Drlg BHA from 115-ft to 1,500-ft(Note-Rigged up Doyon Casing service power tongs at 304-ft)with 2-7/8 HT drill pipe drifting to 1.37". Calculated hole fill=4.4 bbls and actual hole fill =4.4 bbls. 49k up wt,46k dn wt. 16:30 17:30 1.00 1,500 1,500 INTRM1 CEMEN-DHEQ P Fill drill pipe and conduct shallow test on Schlumberger MWD tools circulating 42 spm(125 gpm)@ 1,520 psi-good test. Blow down TD. 17:30 00:00 6.50 1,500 5,779 INTRM1 CEMEN-PULD P Continue to RIH w/4-3/4 Drlg BHA from 1,500-ft to 5,779-ft with 2-7/8 HT drill pipe drifting to 1.37". fill pipe at 3,500 and 5,500-ft Calculated hole fill =20.0 bbls and actual hole fill=25.3 bbls. 94k up wt,63k dn wt. 11/12/2014 Continue to RIH w/2 7/8"PAC DP f/shed to 6,390-ft,tag TOC. Circ and wash to 6,408-ft. CBU. Slip and cut Drill line. PT 5-1/2 Casing @ 3,000 psi for 30 minutes. Drill out shoe track to 6,600-ft. Circulate and condition for FIT. Conduct FIT w/9.8 ppg MW to 1,600 psi, EMW 15.8 ppg result. Continue to drill open hole to 6,691-ft MD/5,160-ft TVD 00:00 02:00 2.00 5,779 6,390 INTRM1 CEMEN PULD P Continue to RIH picking 2-7/8 HT Drill pipe from 5,779-ft to 6,390-ft. Tag TOC. 02:00 04:30 2.50 6,390 6,408 INTRM1 CEMEN-COCF P Wash down from 6,390-ft to 6,408-ft MD at 130 GPM @ 2,750 psi. CBU and condition mud. 95k up wt, 60k dn wt. Blow down TD. 04:30 06:30 2.00 6,408 6,408 INTRMI CEMEN'SLPC P Slip and cut 98-ft of 1-1/8"Drill line. Service draw works,top drive and crown. Calibrate Canrig block- check and set crown saver. MU blower hose. 06:30 08:30 2.00 6,408 6,408 INTRM1 CEMEN'PRTS P Pressure test casing shoe @ 3,000 psi and hold for 30 minutes. RD test equipment, blow down lines and rig down Doyon power tongs for RIH w/ 2-7/8 DP. 08:30 11:00 2.50 6,408 6,484 INTRM1 CEMEN'COCF P Wash down from 6,408-ft to 6,484-ft @ 130 gpm @ 2,750 psi w/30 rpm's w/2.4k torque. Obtain SPR's @ 6,408-ft/4,993-ft TVD w/9.8 ppg mw. 100k up wt, 60k dn wt. Pump#1 1 bpm @ 600 psi; 2 bpm @ 1,500 psi. Pump#2 1 bpm @ 560 psi; 2 bpm @ 1,490 psi. 11:00 13:30 2.50 6,484 6,572 INTRMI CEMEN'DRLG P Drill out cement from 6,484-ft to 6,572-ft @ 130 gpm©2,500 psi rotating @ 30 rpm's w/2k tq. 3-6k WOB, 100k up wt, 60k do wt, 75k ROT wt. Drill out shoe @ 6,568-ft and broke free @ 6,572-ft. Page 18 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 17:00 3.50 6,572 6,600 INTRM1 CEMEN-DDRL P DrIg ahead from 6,572-ft to 6,600-ft w/5-10k WOB, 57 spm, (136 gpm), PSI On=2,950, PSI Off=2,650. 35 to 60 rpm's,w/2-2.3k TQ, on/off. 95k up wt, 71k sow, 74k ROT. CBU for LOT and blow down TD. 17:00 18:00 1.00 6,600 6,600 INTRM1 CEMEN'LOT P Perform FIT-7 spm and pressure up to 1,600 psi and broke over @ 22 stks w/9.8 ppg MW, EQ MW= 15.8 ppg. 18:00 00:00 6.00 6,600 6,691 PROD1 DRILL DDRL P Drlg ahead from 6,600-ft to 6,691-ft/ 5,160-ft TVD w/5-10k WOB, 57 spm, (136 gpm), PSI On=2,525, PSI Off=2,500. 70 rpm's,w/2-2.3k TQ,on/off. 93k up wt, 72k sow, 78k ROT. ART=5.08 hrs,AST=0 hrs, Total Bit hrs=5.08,Total Jar hrs= 5.08 hrs Obtain SPR's @ 18:00 hrs @ 6,600 ft MD/5,090-ft TVD w/9.8 ppg MW Pump#1 1 bpm @ 570 psi, 2 bpm @ 1,680 psi Pump#2 1 bpm @ 560 psi, 2 bpm @ 1,660 psi 11/13/2014 Continue to drill open hole from 6,691-ft MD/5,160-ft TVD to 6,879-ft MD/5,283-ft TVD 00:00 05:30 5.50 6,691 6,753 PROD1 DRILL DDRL P Drlg ahead from 6,691-ft to 6,753-ft/ 5,206-ft TVD w/5-10k WOB, 55 spm, (130 gpm), PSI On=2,390, PSI Off=2,350. 70 rpm's,w/2-2.3k TQ, on/off. 90k up wt, 70k sow, 74k ROT. ART=2.02 hrs,ADT=3.77, AST= 1.75 hrs, Total Bit hrs=8.86, Total Jar hrs=8.86 hrs 05:30 06:30 1.00 6,753 6,555 PROD1 DRILL REAM T Back ream to shoe for rig repair from 6,753-ft to 6,555-ft laying down joints. 90k up wt, 70k SOW and 74k ROT wt. Circulating at 130 gpm at 2,2oo psi rotating @ 40 rpm w/1.6k TQ Note shoe @ 6,586-ft. 06:30 13:00 6.50 6,555 6,754 PROD1 DRILL RGRP T Change out Blower motor on draw works while circulating @ 2 bpm @ 1,220 psi @ 6,555-ft. Trip back to 6,754-ft Page 19 of 30 ..__.._._.._._. , Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:00 19:00 6.00 6,754 6,857 PROD1 DRILL DDRL P Drlg ahead from 6,753-ft to 6,857-ft/ 5,269-ft TVD(Top of Bermuda formation)w/ 10-15k WOB, 145 gpm, PSI On=2,750, PSI Off=2,715. 85 rpm's,w/2-2.2k TQ on/1.8-2.0 TQ off. 91k up wt, 73k sow, 78k ROT. ART=2.15 hrs,ADT=3.47,AST= 1.32 hrs, Total Bit hrs= 12.33, Total Jar hrs= 12.33 hrs. Obtain SPR's @ 18:00 hrs at 6,650-ft MD/5,090-ft TVD w/9.8 ppg MW Pump#1 1 bpm @ 570 psi, 2 bpm @ 1680 psi Pump#2 1 bpm @ 570 psi, 2 bpm @ 1660 psi Seen 2,581 units of gas at BU. 19:00 21:00 2.00 6,857 6,857 PROD1 DRILL CIRC T Discuss with Town engr -Decission was made to increase MW from 9.8 to 10.0 ppg to hold back gas. Increase and coindition MW while reciprocating f/6,857-ft to 6,825-ft at 147 gpm @ 2,695 psi. NFT-no flow, CBU and connection gas back down 21:00 23:30 2.50 6,857 6,879 PROD1 DRILL DDRL P Drlg ahead from 6,857-ft to 6,879-ft/ 5,283-ft TVD(Top of Bermuda formation)w/10-15k WOB, 145 gpm, PSI On=2,750, PSI Off=2,715. 85 rpm's,w/2-2.2k TQ on/ 1.8-2.0 TQ off. 91k up wt, 73k sow, 78k ROT. ART=2.15 hrs,ADT=3.47,AST= 1.32 hrs, Total Bit hrs= 13.43, Total Jar hrs= 13.43 hrs. Seen 1,501 units of gas at BU. 23:30 00:00 0.50 6,879 6,879 PROD1 DRILL CIRC T Seen small increase, discuss with management and conclude to increase MW from 10.0 to 10.3 ppg and condition well surface to surface. 11/14/2014 Continue to drill open hole from 6,879-ft MD/5,283-ft TVD to 7,101-ft MD/5,437-ft TVD 00:00 03:00 3.00 6,879 6,879 PROD1 DRILL CIRC T Continue increase,MW from 10.2 to10.3 ppg and condition well surface to surface. @ 114 gpm @ 1,885 psi. Obtain SPR's @ 6,879-ft MD/ 5,293-ft TVD w/12.3 ppg MW. Pump#1 1 bpm @ 650 psi, 2 bpm @ 1,200 psi Pump#2 1 bpm @ 630 psi, 2 bpm @ 1,210 psi Page 20 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:00 04:00 l 1.00 6,879 6,910 PROD1 DRILL DDRL P Drlg ahead from 6,879-ft to 6,910-ft/ 5,301-ft TVD w/6-10k WOB, 144 gpm, PSI On=2,835, PSI Off= 2,780. 85 rpm's,w/1.8k TQ on/ 1.6k TQ off. 90k up wt, 70k sow, 73k ROT. ART=.78 hrs,ADT=.78 hrs,Total Bit hrs= 14.21,Total Jar hrs= 14.21 hrs. 04:00 06:00 2.00 6,910 6,910 PROD1 DRILL CIRC T Continue increase,MW from 10.4 ppg and condition well surface to surface. @ 140 gpm @ 2,880 psi. Obtain SPR's @ 6,905-ft MD/5,301-ft TVD w/12.4 ppg MW. Pump#1 1 bpm @ 720 psi, 2 bpm @ 1,240 psi Pump#2 1 bpm @ 730 psi, 2 bpm @ 1,220 psi 06:00 12:00 6.00 6,910 6,975 PROD1 DRILL DDRL P Drlg ahead from 6,910-ft to 6,975-ft/ 5,356-ft TVD w/6-12k WOB, 140 gpm, PSI On=2,835, PSI Off= 2,780. 85 rpm's,w/1.8-2.1k TQ on /1.6- 1.8k TQ off. 91k up wt, 72k sow, 72k ROT. ART=.56 hrs,ADT = 1.66 hrs, Total Bit hrs= 15.87, Total Jar hrs= 15.87 hrs. 12:00 00:00 12.00 6,975 7,101 PROD1 DRILL DDRL P Drlg ahead from 6,975-ft to 7,101-ft/ 5,437-ft TVD w/10-12k WOB, 140 gpm, PSI On=2,850, PSI Off= 2,800. 90 rpm's,w/2-2.3k TQ on/ 2k TQ off. 92k up wt, 73k sow, 79k ROT. ART=3.34 hrs,ADT=5.55 hrs,Total Bit hrs=21.42,Total Jar hrs=21.42 hrs. Monitor gas @ BU, Flow Check @ connection. D/D 290 bbls to help with gas cut mud. Weight up system to 10.8 ppg Obtained SPR's @ 22:30 hrs Pump#1 1 bpm @ 630 psi,2 bpm @ 1,180 psi Pump#2 1 bpm @ 730 psi,2 bpm @ 1,140 psi 11/15/2014 Continue to drill open hole from 7,101-ft MD/5,437-ft TVD to 7,360-ft MD/5,572-ft TVD. Condition hole, NFT -Static 00:00 06:00 6.00 7,101 7,227 PROD1 DRILL DDRL P Drlg ahead from 7,101-ft to 7,227-ft/ 5,514-ft TVD w/14k WOB, 153 gpm, PSI On=3,072, PSI Off= 2,994. 90 rpm's,w/2k TQ on/2k TQ off. 89k up wt, 70k sow, 77k ROT. ART=4.72 hrs,ADT=4.72 hrs,AST=0 hrs, Total Bit hrs= 26.14,Total Jar hrs=26.14 hrs. MW= 10.8 ppg. Page 21 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 12:00 6.00 7,227 7,300 PROD1 DRILL DDRL P Drlg ahead from 7,227-ft to 7,300-ft/ 5,568-ft TVD w/10k WOB, 150 gpm, PSI On=3,063, PSI Off= 3,025. 90 rpm's,w/2k TQ on/2k TQ off. 95k up wt,73k sow,77k ROT. ART=2 hrs,ADT=2 hrs, AST=0.46 hrs,Total Bit hrs= 28.60,Total Jar hrs=28.60 hrs. MW= 10.8 ppg. 12:00 15:30 3.50 7,300 7,300 PROD1 CASING CIRC T Weight up circulating system from 10.8 ppg to 11.0 ppg while reciprocating and rotating from 7,300-ft to 7,260-ft @ 145 gpm @ 2,800 psi rotating @ 89 rpm's w/2.2 top 2.5k TQ. 95k up wt, 75k SOW and 80k Rot wt. showing 1000 to 2000 gas unit at BU. 15:30 16:00 0.50 7,300 7,290 PROD1 CASING OWFF T Lay down jt#229, blow down TD. Monitor well for flow for 30 minutes- minimal flow-.5 bbl gain over 30 minutes. 16:00 17:00 1.00 7,290 7,290 PROD1 CASING CIRC T Circulate bottoms up @ 134 gpm @ 2,800 psi rotating @ 50 rpm's w/2.2 top 2.5k TQ. 94k up wt, 74k SOW and 80k Rot wt. showing 2800 gas unit at BU with no pit gain. 17:00 19:30 2.50 7,290 7,260 PROD1 CASING CIRC T Weight up circulating system from 11.0 ppg to 11.3 ppg while reciprocating and rotating from 7,290-ft to 7,260-ft @ 135 gpm @ 2,620 psi rotating @ 55 rpm's w/1.8 top 2.1k TQ. 95k up wt, 75k SOW and 80k Rot wt. showing 300 to 1,085 gas unit at BU. Attempted to get survey--Signal lost. BDTD 19:30 20:00 0.50 7,300 7,290 PROD1 CASING OWFF T Monitor well for flow for 30 minutes- minimal flow-1.0 bbl gain over 30 minutes. 20:00 23:30 3.50 7,290 7,260 PROD1 CASING CIRC T CBU @ 125 gpm @ 2,350 psi rotating @ 50 rpm's w/2.0 to 2.2k TQ. 94k up wt,74k SOW and 80k Rot wt. seen1,085 gas unit at BU.- no pit gain. Circulate another 3 bottoms up-#1 =375 units,#2= 378 Units, and#3=380 units. BDTD. 23:30 00:00 0.50 7,300 7,290 PROD1 CASING OWFF T Monitor well for flow for 30 minutes- static for 30 minutes. 11/16/2014 Pump out of the hole, laying down 2-7/8 DP to 6,534-ft-30-ft inside shoe. NFT-well flowing. CBU and RIH to 7,280-ft. CBU, raise MW to to 11.6 ppg from 11.3 ppg. Pump out of the hole to 6.565-ft. Page 22 of 30 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 00:00 01:30 1.50 7,280 7,280 PROD1 CASING OWFF T Monitor well for flow. Attempt to gather surveys while bringing MP's back on line-no luck. Obtain SPR's @ 7,280-ft MD/ 5,554-ft TVD w/11.3 ppg MW Pump#1 1 bpm @ 700 psi,2 bpm @ 1,340 psi Pump#2 1 bpm @ 670 psi,2 bpm @ 1,310 psi 01:30 05:30 4.00 7,280 6,534 PROD1 CASING CIRC T Wash out from 7,280-ft MD to 6,534-ft MD circulating @ 125 gpm @ 2,267 psi. 90 Up wt, 72k do wt. Calculated displacement=2.97 bbls Actual=3.9 bbls. 05:30 07:00 1.50 6,534 6,534 PROD1 CASING OWFF T Monitor well for flow for 30 minutes.-- well flowing, 07:00 07:30 0.50 6,534 6,534 PROD1 CASING CIRC T CBU @ 125 gpm @ 2,230 psi. BDTD 07:30 08:00 0.50 6,534 6,534 PROD1 CASING OWFF T Monitor well for flow 08:00 09:30 1.50 6,534 6,534 PROD1 CASING CIRC T CBU x 2 @ 120 gpm @ 2,041 psi. BDTD 09:30 11:30 2.00 6,534 7,290 PROD1 CASING PULD T RIH from 6,534-ft to 7,290-ft PU 2-7/8 DP from pipe shed. Calculated displacement=6.2 bbls and Actual =6.1 bbls. 11:30 18:00 6.50 7,290 7,290 PROD1 CASING CIRC T Weight up circulating system from 11.3 ppg to 11.6 ppg while reciprocating and rotating from 7,290-ft to 7,260-ft @ 125 gpm @ 2,494 psi rotating @ 40 rpm's w/2- 2.2k TQ ROT wt=80k, 91k up wt, 72k SOW and 78k Rot wt. showing 300 to 215 gas unit at BU. 18:00 18:30 0.50 7,290 7,290 PROD1 CASING OWFF P BDTD, Conduct NFT-- Static. 18:30 00:00 5.50 7,290 6,565 PROD1 CASING PULD P PJSM on Pumping out of the hole. Pump out of the hole laying down 23 joints to 6,565-ft @ 95 gpm rotating @ 20 rpm's w/1.9-2.2k TQ ROT wt =80k,90k Up wt, and 72k Dn wt. Monitoring gas at BU stks=435 units. Obtain SPR's @ 18:30 hrs @ 7,280-ft MD/5,555-ft TVD w/11.6 ppg MW Pump#1 1 bpm @ 760 psi,2 bpm 1,370 psi Pump#2 1 bpm @ 740 psi,2 bpm 1,390 psi 11/17/2014 NFT. POOH laying down drlg assy, RU e line 00:00 00:30 0.50 6,565 6,565 PROD1 CASING OWFF P NFT at casing shoe @ 6,568-ft-No flow Page 23 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:30 05:00 4.50 6,565 5,623 PROD1 CASING PULD P Continue to pump out of the hole laying 2-7/8 DP from 6,534-ft MD to 5,623-ft MD @ 100 gpm @ 1,603 psi w/87k up wt, 71k do wt. Calculated displacement=4 bbls,Actual displ. =3.72 bbls 05:00 06:00 1.00 5,623 5,623 PROD1 CASING OWFF P 15 minute NFT-Static. Pump 20 bbl dry job and blow down Top drive 06:00 10:00 4.00 5,623 4,300 PROD1 CASING PULD P PJSM on laying down 2-7/8 DP. POOH laying down 2-7/8 DP from 5,623-ft MD to 4,300-ft 81k Up wt, 65k Dn wt. 10:00 10:30 0.50 4,300 4,300 PROD1 CASING SVRG P Service rig 10:30 20:00 9.50 4,300 115 PROD1 CASING PULD P POOH laying down 2-7/8 DP from 4,300-ft MD to 115-ft MD 20:00 20:30 0.50 115 115 PROD1 CASING OWFF P Monitor well for flow @ BHA -- Static. RD Doyon Tong service while monitoring the well. 20:30 22:00 1.50 115 0 PROD1 CASING PULD P PJSM on laying down Drlg BHA. POOH and lay down Drlg BHA. 22:00 00:00 2.00 0 0 PROD1 EVALFN ELOG P PJSM with Halliburton E-line crew. PU/RU and hang sheeves. MU Triple Combo Tools, hang in wellbore fluid to warm up prior before function testing. 11/18/2014 Rih to TD and Log out of the hole. RD E-line. RIH picking up w/production liner and 3-1/2 PH-6 work string as per run order to 4,300-ft. Cement liner in place. 00:00 03:30 3.50 0 0 PROD1 EVALFN ELOG P RIH w/Triple Combo tools to TD 7,304-ft ELM and log out to 6,550-ft ELM. Tool dimensions=4.75"OD x 53.41-ft long weighing 500.13 lbs. 03:30 05:00 1.50 0 0 PROD1 EVALFN ELOG P RD a-line and offload the same. 05:00 08:00 3.00 0 0 COMPZ RPCOM RURD P Prepare liner equipment to RIH and RU GBR Casing tongs. 08:00 09:00 1.00 0 90 COMPZ RPCOM PUTB P PU, MU and RIH w/3 joints of 3-1/2, 9.3#Hydril 511 Shoe track-check floats-Good. 09:00 11:30 2.50 90 90 COMPZ RPCOM OTHR T Circulate across the top while waiting for 3-1/2 hydril 511 cross over to arrive. The one delivered to location was 3-1/2 Hydril 563. Mu cross over to floor safety valve. Page 24 of 30 �•Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:30 16:30 5.00 90 897 COMPZ RPCOM PUTB P Continue to RIH picking up and making up 3-1/2, 9.3#, L-80, Hydril 511 liner from pipe shed 1,400 ft/lbs. Install 27--3-1/2 x 4-1/2 Straight bladed centralizers w/stop rings above and below in the middle of every joint. Centralizer with RA Tag is in the middle of joint 15 @ 6,828-ft ±. PU Baker 3.5"x 5.5"ZXP Liner top packer and Flex lock Hanger assembly and install PH-6 Cross over. Calculated hole fill=2.8 bbls and Actual hole fill=2.5 bbls. 40 Up wt,40k Dn wt. Install Baker mix Pal and allow 30 minutes to set ulp before continuing to RIH. 16:30 22:00 5.50 897 2,800 COMPZ RPCOM PULD P RIH w/3-1/2 Liner while picking up and making up to 7,200 ft/lbs TQ. with 3-1/2, 12.95#, P-110 work string from 897-ft to 2,800-ft and stop to fill hole. 58k Up wt, 52k Dn wt. Calculated hole fill=8.4 bbls and Actual= 10.0 bbls. Noticed gas units rise to 660 units. 22:00 23:00 1.00 2,800 2,800 COMPZ RPCOM CIRC P Circulate 2 bottoms up @ 29 spm (72 gpm)@ 450 psi. 200 units of gas @ BU and Monitor for flow-no signs while circulating. Dump trip tank due to fact of gas cut. Blow down top drive. 23:00 00:00 1.00 2,800 3,400 COMPZ RPCOM PULD P Continue to RIH at 90 ft/min. running speed w/3-1/2 Liner while picking up and making up to 7,200 ft/Ibs TQ. with 3-1/2, 12.95#, P-110 work string from 2,800-ft to 3,400-ft. 65k Up wt, 57k Dn wt. Calculated hole fill=2.8 bbls and Actual=3.0 bbls. Noticed gas units rise to 660 units. 11/19/2014 Continue to RIH w/production liner while picking up 3-1/2 PH-6 work string as per run order from 3,400 to 7,290-ft. Cement liner in place. LT @ 6,405-ft. Change hole over to 11.6 KCL Brine. POOH to 6,281-ft with tail. Suspend operations to Phase III Conditions. 00:00 06:00 6.00 3,400 6,537 COMPZ CASING PULD P Continue to RIH at 90 ft/min. running speed w/3-1/2 Liner while picking up and making up to 7,200 ft/lbs TQ. with 3-1/2, 12.95#, P-110 work string from 3,400-ft to 6,537-ft. 06:00 08:00 2.00 6,537 6,537 COMPZ CASING CIRC P CBU at 6,537-ft @ 120 gpm @ 1,259 psi 97k Up wt,67K Dn wt w/11.5 ppg MW 08:00 09:00 1.00 6,537 7,290 COMPZ CASING PULD P Continue to RIH at 90 ft/min. running speed w/3-1/2 Liner while picking up and making up to 7,200 ft/lbs TQ. with 3-1/2, 12.95#, P-110 work string from 6,537-ft to 7,290-ft. 96k Up wt, 66k Dn wt Page 25 of 30 'Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 13:30 4.50 7,290 7,290 COMPZ CASING CIRC P Circulate @ 90 gpm @ 1,055 psi to condition well for cement job,and prep cement head for install. 106k Up wt, 74k Dn wt. 13:30 14:00 0.50 7,290 7,290 COMPZ CEMEN-SFTY P Conduct Pre-Job safety for cement job with rig crew, Schlumberger and vac truck drivers 14:00 15:30 1.50 7,290 6,405 COMPZ CEMEN-CMNT P Fill lines w/5 bbls of Mud Push, PT lines @ 4,500 psi. Continue to pump with remaining 7 bbls of mud push. Mix and pump 15 bbls of 12 ppg Lite crete. Close in TIW valve,flush lines. Drop dart and displace with 11.6 ppg @3 bpm @1,300 psi decrease PR to 2 bpm after @ 1,020 psi,seen latch up @ 794 stks. Bump plug @ 904 stks and pressure up to 4,200 psi. Set Baker Flex lock Liner Hanger w/shear set for 2,650 psi. Release setting tool and apply 500 psi, Pull out of pack off. 15:30 17:00 1.50 6,405 6,405 COMPZ WELLPF CIRC P Circulate off of the top of the liner hanger @ 5 bpm @ 1,500 psi. Displace well w/30 bbl high visc sweep,followed by 11.6 ppg KCL Brine @ 5 bpm @ 1,500 psi. Blow down top drive. 17:00 21:00 4.00 6,405 6,281 COMPZ WELLPF RURD P Cement in place at 15:00 hrs. Blow down treating lines and rig down same. POOH to 6281-ft. Clean and clear rig floor. Clean out trip tankand under shakers. RU GBR Tubing tongs in preparation for POOH. 21:00 00:00 3.00 6,281 6,281 COMPZ WELLPF OTHR T Suspend operations do to deteriorating weather conditions through out the field. 11/20/2014 Suspend operations to Phase III Conditions. CBU @ 1 bpm to prevent well bore freeze up, Circulating from 6,281-ft. 00:00 21:00 21.00 6,281 6,281 COMPZ WELLPF OTHR T Suspend operations do to deteriorating weather conditions through out the field. Update Nabors rig SOP and hold stand down with Tour Pusher. The entire field went phase III as of 8:49 hrs 21:00 22:00 1.00 6,281 6,281 COMPZ WELLPF CIRC T CBU @ 1 bpm @ 202 psi to prevent wellbore freezing up. 22:00 00:00 2.00 6,281 6,281 COMPZ WELLPF OTHR T Suspend operations do to deteriorating weather conditions through out the field. Update Nabors rig SOP and hold stand down with Tour Pusher. The entire field went phase III as of 8:49 hrs 11/21/2014 Suspend operations to Phase III Conditions Page 26 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:00 24.00 6,281 6,281 COMPZ WELLPF OTHR 'T Suspend operations do to deteriorating weather conditions through out the field. Update Nabors rig SOP and hold stand down with Tour Pusher. The CPF II is phase III. 11/22/2014 Suspend operations to Phase III Conditions. Phase III lift as of 08:00hrs, Begin to dig out and open up well. CBU-all good. POOH w/HR setting tool. PU and RIH w/csg scraper and 4-3/4 bit to 3,315-ft 68k up wt, 60kdnwt. 00:00 08:00 8.00 6,281 6,281 COMPZ WELLPF OTHR T Suspend operations do to deteriorating weather conditions through out the field. Update Nabors rig SOP. The CPF II is phase III. 08:00 12:00 4.00 6,281 6,281 COMPZ WELLPF OTHR T Phase conditions lifted-Crew cleaned and cleared exterior pad walk ways. Blow down Top Drive, 12:00 13:00 1.00 6,281 6,281 COMPZ WELLPF CIRC T Circulate BU from 6,281-ft, 99k Up wt, 78k Dn wt. Circulating 11.6 ppg WBM ©217 gpm @ 1,335 psi. Blow down Top drive. 13:00 20:00 7.00 6,281 0 COMPZ WELLPF TRIP P POOH with 3-1/2, 12.95 ft/lb, P-110 PH-6 workstring and Baker"HR" Liner Running tool assy. 20:00 20:30 0.50 0 38 COMPZ WELLPF PULD P PU, MU and RIH w/5-1/2 15.%3 Casing scraper assy w/4-3/4"Tri cone bit. 20:30 00:00 3.50 38 3,315 COMPZ WELLPF TRIP P RIH w/BHA#4 from 38-ft to 3,315-ft (35 Stds)68k Up wt, 60K Dn wt. Calculated hole fill= 15.4,Actual= 17.2 bbls. 11/23/2014 Continue to RIH w/csg scraper and 4-3/4 bit from 3,315-ft to 6,405-ft Liner Top. Circulate 3 surface to surface @ 336 gpm. Monitor well for flow 15 minutes, POOH L/D 3 1/2"DP and BHA. R/U and run 3 1/2"9#L-80 EUE TBG, Mule Shoe,XN nipple and Seal assy, 0.0'to 115'. 00:00 04:30 4.50 3,315 6,405 COMPZ WELLPF TRIP P Continue to RIH w/BHA#4 from 3,315-ft(35 Stds)to 6,405-ft(68) 04:30 10:30 6.00 6,405 6,405 COMPZ WELLPF CIRC P Circulate @ 6 bpm @ 2,400 psi (AV=504 ft/min.) 10:30 11:00 0.50 6,405 6,405 COMPZ WELLPF OWFF P Monitor well for flow, 15 minutes,well static. 11:00 15:00 4.00 6,405 3,474 COMPZ WELLPF PULD P L/D 3 1/2"DP f/6405't/3474'. PUW 99K, SOW 68K. 15:00 15:30 0.50 3,474 3,474 COMPZ WELLPF SVRG P Service Rig, Drawworks and Pipe Skate. 15:30 22:00 6.50 3,474 0 COMPZ WELLPF PULD P L/D 3 1/2"DP and BHA f/3474' t/0.0'. 22:00 23:30 1.50 0 0 COMPZ WELLPF RURD P Pull ware bushing, R/U to run 3 1/2" 9.3#L-80 EUE TBG. 23:30 00:00 0.50 0 115 COMPZ RPCOM PUTB P P/U TBG, Mule Shoe,XN nipple, Seal assy. PUW 35K, SOW 35K, 0.0 t/115'. 11/24/2014 run 3 1/2"TBG f/115't/6415', Space out, pump 10 bbls of Corosion Inhibitor, and land TBG Hanger. Run slick line with 2.69 gauge ring to verify XN profile is correct. No Go 2.635 00:00 12:00 12.00 115 5,761 COMPZ RPCOM PUTB P P/U 3 1/2"9.3#L-80 TBG f/115' t/5761'. PUW 78K, SOW 58K, calulated fill 19.7 bbls, actual fill 19.2 bbls. Page 27 of 30 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 13:30 1.50 5,761 6,403 COMPZ RPCOM PUTB P P/U 3 1/2"TBG f/5761 t/6403'. PUW 83K, SOW 60K, calculated fill 1.6 bbls, actual fill 2.3 bbls. 13:30 15:30 2.00 6,403 6,403 COMPZ RPCOM PRTS P Pressure test casing liner t/2500 psi for 30 minutes 15:30 17:00 1.50 6,403 6,415 COMPZ RPCOM HOSO P P/U TBG f/6403't/6415',tag and space out, PUW 83K, SOW 62K. L/D JTS 201, 200, and 199. P/U Pup JTS 2.28'and 10.25', M/U JT 199 on the hanger and R/U to spot inhibitor. 17:00 18:00 1.00 6,415 6,415 COMPZ RPCOM CRIH P Pump 10 bbls of corrosion inhibitor, followed with 56 bbls of brine. SPM 52, GPM 125, PSI 755. 18:00 19:00 1.00 6,415 6,415 COMPZ RPCOM THGR P Land TBG Hanger, run in LDS @ 25.43', clear and clean floor. 19:00 00:00 5.00 6,415 0 COMPZ RPCOM SLKL T R/U Slick Line--Run in hole, get RCH body out, double check, size is correct. Forward action—run gauge ring (gauge of 2.69") if it passes/drifts with no resistance we've confirmed wrong XN profile, if it lands/does not drift that tells us it is a 2.635" No-GO. Theory behind this is the wrong XN profile is 2.75"so should drift the 2.69"gauge ring, and the correct XN profile is 2.635" No-Go so should not drift that size gauge ring. Forward action—Run the 2.75" RCH plug body back or set it with a redressed or a backup one. Continue running tubing as procedure. Request tool—Redress kit for 2.75" RHC plug body or a backup 2.75" RHC plug body; 2.75" RHC plug pulling and running tool. 11/25/2014 Pull RHC plug w/slick line-Run gage ring-Run&set RHC plug-Drop rod&ball assembly&chase w/slick line blind box-RD SL-Set packer&test tbg to 4500 psi-Test IA to 3500 psi-Shear SOV-Set TWC& test in direction of flow-Clean under pipe racks on rig floor-ND BOP-NU Tree 00:00 06:30 6.50 0 0 COMPZ RPCOM SLKL T Continue to POOH w/RCH body, double check,XN Nipple size 2.75" is correct. RIH w/2.73"Gauge ring and was unable to pass thru the 2.635" NO-GO XN profile. POOH and RIH w/Redressed RHC Plug body and set in profile nipple. POOH,drop ball and rod,chase to bottom with Blind box-verify on seat. POOH and RD slick line. 06:30 08:30 2.00 0 0 COMPZ RPCOM PACK P RU and PT treating lines to 4,500 psi, Pressure up to 4,500 psi and set packer, 08:30 09:00 0.50 0 COMPZ RPCOM PRTS Hold pressure for 30 minutes for TBG integrity, bleed back to 2,000 psi. Page 28 of 30 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 10:00 1.00 0 0 COMPZ RPCOM PRTS P Pressure up on the Casing to 3,500 psi and hold for 30 minutes-Good test. Bleed back casing pressure to zero,then follow with the TBG to zero. Ramp up on the casing to 1,200 psi and seen SOV shear. continue to circulate for 2 bbls. Shut down and close in TBG and pressure up on casing,TBG pressure followed casing pressure to 2,500 psi, bleed back to zero thru the casing valve and TBG pressure followed. 10:00 11:00 1.00 0 0 COMPZ RPCOM RURD P Rig down TBG test equipment, Landing joint and pull fluid from BOP stack. 11:00 12:00 1.00 0 0 COMPZ WHDBO MPSP P Install TWC, pump down casing and pressure up on bottom side of TWC to(test in direction of flow)for barrier test. -Good Test, bleed off pressure. 12:00 17:30 5.50 0 0 COMPZ WHDBO OTHR P Clean out mud residue from under Rotary table, flow lines, and clean and flush pits. Blow down all mud surface lines. 17:30 20:00 2.50 0 0 COMPZ WHDBO RURD P PJSM-Change top pipe rams f/2 7/8"x 5"to 3 1/2"x 6"VBR 20:00 22:00 2.00 0 0 COMPZ WHDBO NUND P ND BOP stack&adaptor flange 22:00 23:30 1.50 0 0 COMPZ WHDBO NUND P PJSM-NU tree and adaptor-test adaptor flange to 5000 psi for 10 mins. 23:30 00:00 0.50 0 0 COMPZ WHDBO PRTS P Test adaptor flange to 5000 psi for 10 mins. 11/26/2014 Tested adaptor flange&tree-Pull TWC-Pumped 43 bbls diesel for freeze portect and U tube f/IA to tbg- Set BPV-Dress&secure tree-LD 13 stds DP f/derrick via mouse hole-Prep rig floor for move-Set up divertersystem on 2 N 336 and wait on pad preprtion for rig move Released rig @ 0000 hrs-for move to 2N 337C 00:00 01:00 1.00 0 0 COMPZ WHDBO PRTS P Test Adapor flange to 5000 psi for 10 mins.-Test tree to 250&5000 psi Good Tests) 01:00 02:30 1.50 0 0 COMPZ WHDBO FRZP P RU lines in cellar for freeze protect 02:30 03:00 0.50 0 0 COMPZ WHDBO MPSP P RU&Pull TWC 03:00 05:30 2.50 0 0 COMPZ WHDBO FRZP P PJSM-RU lines to tbg&IA for freeze protect- Pressure test line to 3500 psi-Pumped 43 bbls diesel w/ LRS down IA taking brine returns from the tbg to pit#2-@ 1.5 to 1.6 bbls/min @ 1900 to 2000 psi-RD LRS-Line up to U tube diesel f/IA to tbg-let fluid U tube 05:30 08:00 2.50 0 0 COMPZ WHDBO RURD P Prep to LD DP f/derrick-Remove kelly hose 7 Install roughneck mouse _ hole 08:00 09:00 1.00 0 0 COMPZ WHDBO MPSP P Set BPV in tbg hanger-Dress and secure tree Page 29 of 30 • Time Logs Date From To Dur S. Depth E. 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Continue to pump with remaining 7 bbls of mud push. Mix and pump 15 bbls of 12 ppg Lite crete. Close in TIW valve,flush lines. Drop dart and displace with 11.6 ppg @ 3 bpm @ 1,300 psi decrease PR to 2 bpm after @ 1,020 psi,seen latch up @ 794 stks. Bump plug @ 904 stks and pressure up to 4,200 psi. Set Baker Flex lock Liner Hanger w/shear set for 2,650 psi. Release setting tool and apply 500 psi,Pull out of pack off. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Liner Cement • 6,405.2 7,300.0 No No No Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl!... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 5 2 1,020.0 4,200.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Fill lines w/5 bbls of Mud Push, PT lines @ 4,500 psi. Continue to pump with remaining 7 bbls of mud push. Mix and pump 15 bbls of 12 ppg Lite crete. Close in TIW valve,flush lines. Drop dart and displace with 11.6 ppg @ 3 bpm @ 1,300 psi decrease PR to 2 bpm after @ 1,020 psi,seen latch up @ 794 stks. Bump plug @ 904 stks and pressure up to 4,200 psi. Set Baker Flex lock Liner Hanger w/shear set for 2,650 psi. Release setting tool and apply 500 psi, Pull out of pack off. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Production Cement 6,405.0 7,300.0 51 Lite Crete 15.0 Yield(fP/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.64 3.46 12.00 6.25 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 12/10/2014 ��` Cement Detail Report 0 g t 2N-319 Ca nocoPhil lips String: Production Casing Cement Job: DRILLING SIDETRACK, 10/24/2014 15:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Production Casing Cement 11/9/2014 03:00 11/9/2014 05:00 2N-319A Comment Cemented 5 1/2"csg as follows;Dowell pumped 5 bbls water-Tested lines to 4000 psi(Good Test)-Dowell pumped 30 bbls CW-100 @ 5 bbls/min @ 980 psi followed by 30 bbls 10.5 ppg MudPush @ 5 bbls/min @ 650 psi-Shut down&lined up valves on cmt head to pump out btm. plug-Dowell pumped 75 bbls 12.0 ppg LiteCrete GasBloc slurry @ 5 bbls/min @ 690 psi-Shut down&lined up valves to drop top plug-Dowell pumped 10 bbls water behind top plug Switch over to rig pump and displaced cmt.w/9.6 ppg LSND mud @ 5 bbls/min @ 950 psi-w/86 bbls of displacement pumped(18 bbls of cmt out shoe)Obsreved hole packing off&pipe hydraulicing up w/pressure spike @ 2000 psi&flow dropped f 22%to 7% slowed pump to 4 bbls/min @ 1000 psi-Land hanger-had to continue to reduce pump rate to keep pressure below 2000 psi-final rate was 1.2 bbls/min and bumped plug w/2200 psi-held pressure for 3 mins. bled off to check floats-OK-CIP @ 0455 hrs. Had returns throughout job-final pit strap showed no losses. Cement Stages Stage#<Stage Number?> Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Production Casing 27.6 6,570.0 Yes Yes Yes Cement Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 5 2 5 2,200.0 2,200.0 Yes 15.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids I&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Pre Flush 2,160.0 3,330.0 30.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 8.30 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) MudPush 3,330.0 4,500.0 30.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(Ib/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 10.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 4,500.0 6,570.0 259 G 75.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.64 3.46 12.00 Additives Additive Type Concentration Conc Unit label D047 Anitfoam Additive Type Concentration Conc Unit label D046 Antifoam Additive Type Concentration Conc Unit label D065 Dispersant Additive Type Concentration Conc Unit label D600G GasBlok Page 1/1 Report Printed: 12/10/2014 252G°1 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. January 12, 2015 Attn.: Makana Bender DATA LOGGED 333 West 7th Avenue, Suite 100 +na/2015 K BENDER Anchorage, Alaska 99501 RECEIVED RE: Radial Cement Bond Log &Perf. Record &Jewelry Log: 2N-319, JAN 1 5 2015 Run Date: 12/17/2014 40GCC 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 2N-319A Data in LAS format, Digital Log Image files 1 CD Rom 50-103-20271-01 Radial Cement Bond Log 1 Color Log 50-103-20271-01 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: ' " ! 6.-eiteett 2_, -��9 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. � December 8, 2014 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 �' � iS DATA OGG D Anchorage, Alaska 99501 �� M K ENDER RE: Triple Combo - Open Hole: 2N-319A0. Run Date: 11/18/2014 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 2N-319A Triple Combo Data in LAS format and Digital Log Image files 1 CD Rom 50-103-20271-01 Triple Combo Log 1 Color Log 50-103-20271-01 Borehole Volume Plot 1 Color Log 50-103-20271-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE A'ITENTION OF: Halliburton Wireline & Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Date: Signed: ,,aL' �E:�N 21 41 19 2511; 4 ConocoPhillips REcc.civiED TRANSMITTAL DEC i1 2014 FROM: Sandra D. Lemke,ATO3-0340 TO: Makana Bender AOGCC i ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7th Ave., suite 100 Anchorage AK 99510-0360 Anchorage,Alaska 99501 DATA LOGGED RE: 2N-350A ,2.h$/201' DATE: 12/11/2014 ;vi.K.BENDER Transmitted: —, liKuparuk River Unit, Alaska l il 112N-319A 1 CD and 1 hardcopy report CANRIG Final well report mud logging data for 2N-319A; 1215/2014; table of contents, mud logging equipment; 11 ii general well details, geologic data, pressure/formation strength, drilling data, show reports, daily reports and formation I logs; color log presentations, one set each for wellbore n ii n Formation log MD&TVD :Gas ratio MD&TVD l! Combo log MD&TVD II1 Drilling dynamics MD&TVD JCD contains daily reports, DML data,final well report, LAS files, Log PDF files, remarks, TIFF files,show report n p Il IT Please promptly sign, scan and return electronically to Sandra.D.LemkenaCOP.coni CC: 2N-319A transmittal folder, production well files, eSearch Receipt�44-42•414v O.-ell-eater (/) ��: ;,. GIS-Technical Data Management I ConocoPhillips I Anchorage,Alaska I Ph: 907.265.6947 21 41 19 REL. Vii/ ... 25139 DEC 0 9 2014 Schlumberger Transmittal #: 09DEC14-NG01 Drilling & Measurements MWD/LWD Log Product Delivery DATA%°GGy M.K.BENDER Customer: ConocoPhillips Alaska Dispatched To: Makana Bender Well No: 2N-319A Date Dispatched: 9-Dec-14 Job#: 14AKA0131 Dispatched By: Nathan Green Well / Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: Contents on CD N/A VISION* Resistivil 2" MD x x VISION* Resistivil 2"TVD x x VISION* Resistivil 5" MD x x VISION* Resistivil 5"TVD x x LAS Digital Data N/A Contents on CD N/A x Directional Data 1 Contents on CD N/A Nad27 x x EOW CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics: PDF, TIFF x Survey: txt,pdf x Please sign and email a copy to: Please sign and email/fax a copy to: catherine.Roso(c�Conocophilips.com AlaskaPTSPrintCenter(a�slb.com Catherine Roso Attn: Nathan Green 12'lL4tcz.4$zL; 5p� 7 Received By: C71st W. 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P. Ng N N N N N N ru N N N N N N N N N N N N N N N N N N N N N CO N N N N N N N N N N MOON F3 RI 1NV N N Fl l4V N N N Q 0 0 CO Q Vl01 0 0 04'0120,2 et 0 O m-Y O 7 M r 20..4-03 mf03-05 nm m 0et 05 a 0 N N O I4-.14-.00-:0..1`(mV 20n0 0 N 0so 'l C N co ap 20101 W a 01 ri 6 •- •- aavva(47nva<�a a x0100 N N1N01No co..co`2 22 22 22 2 22200 0000 a s 103(1 a s a<a: d TIt Y 22 U g ra14.d 12-20 NN 00-1 p8�8248 382 C-pp 10288 r-yN Nm 223 P.223222.2 00p 20033243I. 10-1�8324:22 1p c.o00o 8 ui •ON a.-§S01SMO(C1C2a0gIsCINC70N0g4Si 0,5000141-m0050Ni010 W_02 O Coal(O NN8 (p N lrl t7 C'l.(O. Qd Q..832.322.28.332.3.22 CD000000001�I-0r 1- N p to Y W va N H2 Z1 w 8 F„ o H ii W a C 01 & C 2 T ,..>. C E C Q 2 >? C 64 U (4 (1 0. CO V1 2 a o i et ea D | -0 12 ` co In } ` /\ .. # § CD W & k� ® E§ \§ate n C aaoo{ El § Z.1( d f z :i3 r, .mora ° < 3 2 �"■, ' k \ C ƒ(// � � a.8 , r\,\\\¥0ig ii / \ 712 2 ? :\ �t: #; A (1). <1 a \ ° % k { \ 2 - < k G T\ ° f k ))@§ 2 \ \ \ 2® ! 8-. } // <> k §° m c)6 8820 § % . & < | z § / Co > Z k) ' § '\\g §v wir ; , \k` «■ \\ am gik/ k) @ ¢a § k2 ./ :1- .g. 2.-N4 \-9 \���v • THE STATE Alaska Oil and Gas °fALASJ A Conservation Commission GOVERNOR BILL WALKER 333 West Seventh Avenue pp , �, Anchorage,Alaska 99501-3572 ALAS" Main:907.279.1433 Fax:907.276.7542 Xueqin Yang Sr. Completions Engineer ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage,AK 99510 Re: Kuparuk River Field, Tarn Oil Pool, KRU 2N-319A Sundry Number: 314-649 Dear Mr. Yang: 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 Pi Foerster Chair DATED this day of December, 2014. End. RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION LI L( 0 1 2014 py APPLICATION FOR SUNDRY APPROVALS 0.7-fL2 2//4-- 20 AAC 25.280 ' 0(1C C., 1.Type of Request. Abandon D Plug for Redrill ❑ Perforate New Pool ❑ Repair Well❑ Change Approved Program ❑ Suspend❑ Plug Perforations ❑ Perforate ❑' .. Pull Tubing ❑ Time Extension Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate Q • Alter Casing E] Other r�'4� re 0-)ww/a 2.Operator Name. 4 Current Well Class: 5.Permit to Drill Number: ConocoPhillips,Alaska,Inc Exploratory ❑ Development ❑✓ 214-119 3.Address. Stratigraphic ❑ Service ❑ 6.API Number. P.O.Box 100360,Anchorage,Alaska 99510 50-10320271-01 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool' Will planned perforations require a spacing exception? Yes ❑ No Q KRU 2N-319A' 9.Property Designation(Lease Number): 10.Field/Pool(s). ADL 375074/380054 s Kuraruk River Field/Tarn Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft). Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft). Plugs(measured)* Junk(measured)* 7,288 - 5,562 ' 6,990 - 5,220 , None None Casing Length Size MD TVD Burst Collapse Structural ' Conductor 79' 16" 108' 108' Surface 2,410' 7-5/8" 2,439' 2,308' Intermediate 6,541' 5-1/2" 6,570' 5,094' Production Liner 883' 3-112" 7,288' 5,562' Perforation Depth MD(ft): Perforation Depth TVD(ft). Tubing Size: Tubing Grade* Tubing MD(ft): 6,965-6,990 5,200-5,216 3-1/2" L80 6,416 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 3-1/2"X 5-1/2"Production Packer 6,364 MD, 4,818 TVD 12 Attachments. Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑✓ ' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 12/8/2014 Oil Q . Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval. Date: WINJ ❑ GINJ ❑ WAG 0 Abandoned ❑ Commission Representative* GSTOR 0 SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Contact Xueqin Yang @ 265-6342 Email xueain.vanq(c�conocophillips.com Printed Name Xueqin Yang Title Sr.Completions Engineer Signature Phone 265-6342 Date la,,,,Lsiouyt.cfr, >Z lu ) l 20 l COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: 1'O ifl{tir1A- 1O ret ; u (ec +kFO Chc'.Nti(rc.( Disc (Os-)te kist wives. 4'r0,s-oc,,..,S . o CS Spacing Exception Required? Yes ❑ No i Subsequent Form Required. 10 - 4-0 /i) ,9 •-. APPROVED BY (-14// Approved by* � / / COMMISSIONER(/ /4 THE COMMISSION Date: r` - y —/`i 1' I 41.1 Submit Form and ABC ��For �4g3(5eyii /2012) VcR Adt 12 mon from the date of approval. Attachments in Duplicate iYi1 (� ( r-L z�z - ,� y cam/..) l ra12//q- 2N-319A Sundry Application TARN Bermuda Frac PTD #: 214-119 TARN producer 2N-319A was started drilling in October of 2014 and just completed in November 26, 2014. 2N-319A was completed with 3.5" liner in Bermuda sand. After completion, the plan forward is to perforate and frac the Bermuda sand. Proposed Procedure: Halliburton E-line Perforation (Tarn Bermuda-sand Perforation) Perforate Bermuda Sand at 6,965 - 6,990' MD (25') (5,200' - 5,216' TVD) with Halliburton 2.0" 6spf 60deg phase gun. Charge is 2" 6 spf HMX BH, average hoe size is 0.48", average penetration is 3.3". Schlumberger Pumping Services: (Tarn Bermuda-sand Frac) 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre-existing conditions. 2. Ensure all Pre-frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 2,000' TVD. 3. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 4. MIRU 7 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10%. Load tanks with 100° F seawater (approx. 2,883 bbls are required for the treatment with breakdown, maximum pad; and 450 bbls usable volume per tank). 5. Ensure lift plan is reviewed and signed prior to RU of Frac equipment requiring lifts. 6. MIRU Stinger Tree Saver Equipment and SLB Frac Equipment. 7. PT Surface lines to 5,000 psi using a Pressure test fluid. 8. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 9. Pump the Frac job by following schedule @ 20 bpm with a maximum expected treating pressure of 4,000 psi. • 500 bbls Schlumberger fluid Pad • 160 bbls Schlumberger fluid w/ 1 ppa • 180 bbl Schlumberger fluid w/2 ppa • 200 bbls Schlumberger fluid w/ 3 ppa • 230 bbls Schlumberger fluid w/4 ppa • 240 bbls Schlumberger fluid w/ 5 ppa • 250 bbls Schlumberger fluid w/6 ppa • 260 bbls Schlumberger fluid w/ 7 ppa • 300 bbls Schlumberger fluid w/ 8 ppa • Flush with 38 bbls of linear fluid and 19 bbls of freeze protect • Total Sand: Approx. 302,000 lbs of 16/20 CarboLite • 10. Monitor the surface pressure fall-off at the end of the job for 30 minutes, if the well does not screen out. 11. RDMO SLB Equipment. Freeze Protect the tubing and wellhead if not able to complete following the flush. 12. Well is ready for Post Frac well prep for flowback (Slickline and possibly CTU). Cement Evaluation of 2N-319A and wells within 1/4 mile of 2N-319A 2N-319A: 3-1/2" liner cement job was pumped on 11/19/2014 as designed, indicating competent cement operations. The cement pumped was 12ppg Lite Crete, displaced by 11.6 ppg brine. The plug was bumped at 4,200psi and the liner hanger was set. The packer was set and pressure tested to 2,500psi. No other wells within 1/4 mile of 2N-319A. Summary Based on an engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successfully fractured within its design limits. It has also been determined that the frac will not adversely affect wells within a 1/4 mile radius or any other nearby well. 2N-319A Schematic: Tarn 2N-319A Rotary Sidetrack Topeet Convontionai Slant Producer Completed Wellbore Schematic ConocoPhillips — lififf G•n 3-11. - 16'Existing Cemented Conductor: 1e"62.5#H43 A les,AID Ili 1:-c XX MI IOW* 311}Y env oo p 0 1 3 W.r Can=AtA17.7-3 oo o1114I-IA 0.61.1Tre Yaw Fxisting Surface Casing- NI 219111S 7- B 29.7#L-80 BTCM 2,43g'MD.'2,308'TVD g 41' I;A•IA arm,Woo id &dee=KCP a?ernere du2 jp-s2 degrees In open roe a:46.E.-.:.4es-MC A:mh• Carrier a,7,:,c.2`.1-..7 i....,:.:4:744 P. .:s29.r,::: k ...„ ..„.,_.,_„....„._._•, 3-W g.at#L-80 EiJEM BRD *C-TA:).rtort".'w o•• h 4ea- TOC 15.8 ig tip.,64,5co IAD :Jr.,txr-7!-,...• Ice-Berg Co.2N-E19,41.1:04 54:C.`D ogre DIU mkt ,..:k a awe leloas21 W.. ...er,,.::.2 Awarn.-how Paso wItIt 3-'4' '-'4"AihOXL-3 NrtwolluM1 hick&ow'.3 7r ID of 6.984' 2 t5"A. Wilt :antra - 10 ..21.11'Et , „ .2X.Lter Tdp Passer JCO- node E-VCeg II.,-cro At a la. 4 --R zx=.Per Lca tv Lam,Havarti?G.Tetacs a 3-N A 'Boor :,''' .0.- intermediate Casing Topset Stow htrea- ,,,, [dry- w 4r,a 5-1,•2"/5.54 L-80 1-trIll 563 b,6,072.55' 6.113' 5-1:2"t 5.5 -rNi 1 cissi-ryirII 563 COrrleCtIOCS tO _ 41/ ' 6,E70.'5,7-94T.0D El' 6-,4"Hole TD 6,580101136.100-TVD. 1 RA te4 b'% .tst,14.,--.:3 1 PPG „ . —,-- fieernikda Pore Peft: - I'Ep* E"..^N propo:.ec- - 5.90 to E Octir.3 P,oduciton Car.,113 LT6390 MC • C-..' ,. ' .. ... . , . , Ilk ' Edee Eerrucia2N-319knah 7.832?!.150 E 3E E T.'D Cemented Production Liner: 3-1Z£1.3#L-80 Hydril 511 7,20'MD i 5.5C2'TVD @ 49' Stimulation Surface Rig-Up: Bleed!Tattle Tale Tar* 1C11 2 11 t1 �/ _ d 1:1 g * • Minimum pressure rating on all surface treating lines 10,000 psi • Main treating line PRV is set to 95%of max PO treating pressure • IA parallel PRV set to 3500 psi • Frac pump trip pressure setting are staggered and mTo C set below main treating line PRV • Tree saver used on all fracs rated for 15,000 psi. cp S n g �a c It a 2 it LY 104 10. • ° d cul dwed U Pop-0f Tar Pop-Off Tank t Pump Trude aN gja ♦ " 1 J Frac Pump Frac Pump Frac Pump H - FracPunp 5 Frac Pump -N-4)8(1— Frac Pump Stimulation Tree Saver OPEN POSITION CLOSED POSITION (PRIOR TO MANDREL INSERTION) (MANDREL INSERTED) ffl FRAC IRON /CONNECTION 11 i. /REMOTE OPERATED • 7 �� MASTER VALVE mommess IIIIIMIMMINMI .1111111111 te bilsi +; IsWIUAL OPERATED • MASTER VALVE Aieryo® Stinger \\ f Stinger I 1 �` �'•'.. �� VENT „I 0 I..—VALVE 111.; \\ , 1 OPEN J 11111 gill T \i ilk.: 1 FLOW TEE AND / ^ -- '•���`[• VENT VALVE WELLHEAD :.: Ili 1111 VALVES ._....' v 'O/ilk����A OPEN .. !0 — —Y4 WELLHEAD VALVES CLOSED —./'•.I" 41 /.01. ,. • . OUAD PACKOFF • VA at * --....„0. ASSEMBLY IN *' PUCE IN TUBING i ..."N....• v.z. ,s."1-51 -_ TUBING /z, •/ 4 • The universal tool is rated for 15,000 psi and has 84" of stroke. • Tool ID 2.25" down 4 '/2 tubing and 1.75" down 3 '/2 tubing. • Max rate with 2.25"mandrel is 60 bpm and with 1.75"mandrel 36 bpm TD -o0 20 (B L u_ Q ci)N- CO M Z N Q- Li Q0 0 0 0 0 0 0 0 0 0 o v a_ 0 0 0 0 0 0 0 0 0 0 a V o c\i C) 4 (fl cf d .c 0 0 0 0 0 0 0 0 CO N N N N N N N N 4) CO CO CO CO (0 CO CO CO 2 a) 4) 4) a) 4) Q) a) 4) C J : J J J J J J Q N _o _o _o sp _o o A c6 c6 c6 c6 c6 c6 c6 (6 CL F- a a a a a a a a C 01) • U p) co O co O O O O O O O 001.1.... N N N N N N N N N N ■ • U f Cl) _fl o RS0 0 o. 0 a E 0 0 0 0 0 0 0 00 L-0- - N . .Q N L.L o Q O co - N N N N N Lc) co CO CD \/ N y1 CD 0 0") CO a CO CO CD to N CO CO o 4., UH. HHHHHF- HH o �O Cn (n (n (n (n (- N- (n N. N (N ,.13 a) r (N N. N. (N (N N. (N a) N N_ N_ N_ N N_ N_ N_ N_ S- LL LL LL LL LL LL LL LL LL LLL C6 >- >- >- >- >- >- >- >- ›- 1-,':Z NI I I I _ LL - a_LL Q aey . }' N C o 0 0 0 0 0 0 0 0 0 CI_ ix C N N N N N N N N N N O V— /�L < /1 N". J N (o a_ a. a_ a. CL EL CL a_ S N N 0 o_ 0- 0 0 0 0 00CD 0 L N -e z'''' ci CO v 0 r m r L L.L. LL 0 W= ocp Li_ O A 4 (n p (i) W cC5 L y. y.. •- }, o m o !+-- NI` cr. zr. M CZ (1) -c • OD N (n }, M M r �—' >' .. .. N co tod' NO cW Tz .(LT:5 .Rc u) 22 E ▪ Q. -= L (n 1 1 1 I 1 c to U u) cn 4— O C6 U ICD _c C.) b- CD- 0 .A=, = I2 +61 s= n > w = OV f C 0 in (6 a) > E "-I 71) --r:', O (O ▪ O CI• (6 73Q C = .1_, L � U -O (n N O N O 0 m L - 0 . . ICS CC3 uj O 2 I' E.' 45 cm 5-,_ • V 46 Lt • (t5 Q. 0 Es i -0 -0 w Z 0 0 — 4O LL LL C� >+ to Q (6 c -0 = L TD }+ }' 0O > E Oc 'p (-n0 L_ _ __ r_ LuI ._ a) -F-, ca) a) co (nomo = •- oo — 1E o (n (n N O O u F— E EE ._ . � . . . ,-0 --C\7177 -%\s,��\ THE STATE f=.,.i_ , << a ( r�., ut t ___ y_ 333 Svcs �e cn,li A cnue �`; - -, PAAnchaiace, Ala ka 99501 3572 �\,y/ Moro 907 2i9 1433 Graham L. Alvord Drilling Manager ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Tarn Oil Pool, 2N-319A ConocoPhillips Alaska, Inc. Permit No: 214-119 Surface Location: 55' FNL, 734' FEL, Sec. 3, TOO9N, R7E, UM Bottomhole Location: 1057' FNL, 4162' FEL, Sec. 3, TOO9N, R7E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to re-drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, a /077,6(44/L_____ Cathy v Foerster Chair DATED this !Stay of August, 2014. STATE OF ALASKA I A OIL AND GAS CONSERVATION COMr JN U() 1 2 2014 PERMIT TO DRILL 20 AAC 25 005 AOGCC la Type of Work: lb.Proposed Well Class: Development-Oil ❑✓ • Service- Winj ❑ Single Zone Q . lc.Specify if well is proposed for: Drill ❑ Lateral 0 Stratigraphic Test 0 Development-Gas❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas 0 Gas Hydrates 0 Redril 0• Reentry ❑ Exploratory D Service- WAG 0 Service-Disp ❑ Geothermal 0 Shale Gas 0 2.Operator Name: 5. Bond: Blanket O , Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska Inc. Bond No. 59-52-180 , 2N-319A 3.Address. 6.Proposed Depth. 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 7249.99', TVD: 5508.8' 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number). Kuparuk River Field Surface: 54.2'FNL,733 8'FEL,Sec 3,TOO9N,R7E,UM• ADL 380054/375074 , Tarn Oil Pool • Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 813.9'FNL,3862'FEL,Sec3,TOO9N,R7E,UM• 4602 9/21/2014 Total Depth• 9.Acres in Property: ?K8 14 Distance to Nearest Property: 1056.4'FNL,4161.2'FEL,Sec3,TOO9N,R7E,UM • sI D 269 1035' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: •148.9 feet 15.Distance to Nearest Well Open Surface: x-460,859.3' y-5,911,953.41' Zone-4 • GL Elevation above MSL: .120 9 feet to Same Pool: 256'to 2N-349A 16.Deviated wells: Kickoff depth: 2550 feet - ?kb 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: S).Y&151 degrees Downhole: 2635. Surface: 2124-- 18. 18.Casing Program. Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 16" 62.58# H-40 Welded 79' 29' 29' 108' 108' Existing 9-7/8" 7-5/8" 29.7# L-80 BTCM 2409.8' 29' 29' 2438.8' 2308.1' Existing 6-1/2x7-1/2 5-1/2" 15.5# L-80 HYD563 6582.56' 26' 26' 6608.56' 5108.8' 363 sx 15.8 ppg Class G, 4-3/4" 3-1/2" 9.3# L-80 HYD511 849.99' 6400' 4978.75' 7249.99' 5508.8' 59 sx 15.8 ppg Class G 3-1/2" 9.3# L-80 EUE 6376.3' 23.7 23.7 6400' 4978.75' 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): 7018.6' 5585.3' CA-2 6311.5'MD 7018.6' 5585.3' N/A Casing Length Size Cement Volume MD TVD Conductor/Structural 79' 16" 108' Surface 2409.8' 7-5/8" 265 bbl Total(2 stage job)15.8 ppg C 2438.8' 2308.1' Intermediate Production 6992.6' 5-1/2"x3-1/2" 47 bbl 15.8 ppg Class G 7018.6' 5585.3' Liner 6336.3' 3-1/2" N/A-Tubing 6336.3' 5090.8' Perforation Depth MD(ft): 6605'-6625' Perforation Depth TVD(ft): 5288.4'-5302.9' 20. Attachments: Property Plat ❑ BOP Sketch❑ Drilling Program ❑✓ Time v.Depth Plot ❑ Shallow Hazard AnalysisE Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 8/11/2014 22. I hereby certify that the foregoing is true and correct. Scott Brunswick 263-4249 Contact di scott.a.brunswick• co•.'om \ Email Printed Name L-� t_ 1�lrrlr-.�l Title Vn•l,(. ' ^„ c Signature / (- 0j.� Phone 265-4 It.. Date l(I to 14- jjj Commission Use Only Permit to Drill u API Number: Permit ApprovalI J 5 l, See cover letter for other Number: DM - I l 50-10,3-a0 2�1- 0/-00 Date: 1 f requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: d Other: Samples req'd: Yes❑ Non Mud log req'd:Yes❑ No12/ @op tesi' tD 3s"0 ps ; HZS measures: Yes Pf No❑/ Directional svy req'd:Yes[r No❑ Spacing exception req'd: Yes❑ No Q Inclination-only svy req'd:Yes❑ No APPROVED BY Approved by: /� COMMISSIONER THE COMMISSION Date• R-/S-/V i'M sh"]it Submit Form and Form 10-401( evised 10/2012) This permit is vjIiRort2��o�ttKir i t e date of approval(20 AAC 25.005(g)) Attachments in Duplicate L'L FB/!3/1`}' ,/ ��I \\\ �f , n frK ' ConocoPhillips Alaska, Inc. ' nr '40 'i Post Office Box 100360 Anchorage,Alaska 99510-0360 'AUG 12 7014 ConocoPhillips Telephone 907-276-1215 AOGCC cc August 11,2014 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 Re: Application for Permit to Drill 2N-319A Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill for the onshore production well 2N-319A from the Tarn 2N drilling pad. The intended spud date for this well is September 21st, 2014 using Nabors Rig 9ES. 2N-319A is planned to be a slant Bermuda sand producer. The existing well 2N-319 will be plugged and abandoned before the rig moves on. The rig will pull the tubing,then perform a cut&pull of the production casing to sidetrack&re-drill the well to a new bottom hole location. The intermediate hole section will be drilled with a 6-3/4" bit opening the hole to 7-1/2"with use of an under-reamer for casing connection clearance and a 5-1/2"casing long string will be top set above the Bermuda sand and cemented in place. The production section will be drilled with a 4-3/4" bit,with a 3-1/2"liner run and cemented to the liner top. 3-1/2"tubing will be run and tied back to surface. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005(a). 2. A proposed drilling program 3. A drilling fluids program summary. 4. Proposed completion diagram 5. Pressure information as required by 20 ACC 25.035(d)(2). 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050(b). Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035(a)and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Scott Brunswick at 263-4249 or Chip Alvord at 265-6120. Sincerely, • Scott Brunswick Drilling Engineer Attachments cc: 2N-319A Well File/Sharon Allsup-Drake ATO 1530 Chip Alvord ATO 1570 Liz Jolley ATO 1568 A 'ion for Permit to Drill,Well 2N-319A Saved: 11-Aug-14 2N-319A Application for Permit to Drill Document 0: 1:4,,i,,t wx ConocoPhillips Table of Contents 1. Well Name (Requirements of 20 AAC 25.005 (f)) 3 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) 3 Requirements of 20 AAC 25.050(b) 4 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) 4 4. Drilling Hazards Information (Requirements of 20 AAC 25.005 (c)(4)) 4 ASP CALCULATIONS 4 5. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005(c)(5)) 5 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) 5 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) 6 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) 6 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) 7 10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) 7 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) 7 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) 7 13. Proposed Drilling Program (Requirements of 20 AAC 25.005 (c)(13)) 7 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 8 (Requirements of 20 AAC 25.005 (c)(14)) Error! Bookmark not defined. 2N-319A APD Page 1 of 14 Printed: 11-Aug-14 ORIGINAL A' `ion for Permit to Drill,Well 2N-319A Saved: 11-Aug-14 15. Attachments 8 Attachment 1 Directional Plan 8 Attachment 2 Drilling Hazards Summary 8 Attachment 3 Proposed Well Schematic 8 2N-319A APD Page 2 of 14 Printed: 11-Aug-14 ORIGINAL A ion for Permit to Drill,Well 2N-319A Saved: 11-Aug-14 1. Well Name (Requirements of 20 AAC 25.005(f)) The well for which this application is submitted will be designated as 2N-319A. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) This well is planned as a slant producer to improve Bermuda oil recovery and pattern sweep efficiency at Tarn. The rig will move onto the 2N-319 well after a pre-rig abandonment operation has been performed, refer to previous sundry to abandon. Once rigged up & prepared for operations the existing pre-cut tubing will be pulled from the well and laid down. A cut& pull operation of the production casing will be performed, followed by pumping cement into the open hole & into the existing surface casing for sidetracking &drilling the well to a new bottom hole location. The intermediate hole section will be sidetracked drilled using a 6-3/4" bit, opening the section with use of an under-reamer to 7-1/2" for 5-1/2" casing connection OD clearance. The intermediate casing will be 5-1/2"top set above the Bermuda sand &cemented in place. The production section will be drilled using a 4-3/4" bit, & run a 3-1/2" liner with cement placed to the liner top. 3-1/2" tubing will be run &tied back to surface. Location at Surface 54.2' FNL, 733.78' FEL, Sec 03, T09N, R7E, UM NAD 1927 RKB Elevation 148.8' AMSL Northings: 5,911,9453.41 Eastings: 460,859.30 Pad Elevation 120.9' AMSL Location of existing 7 5/8" Surface 5028.64' FNL, 1154.32' FEL, Sec 34, T10N, R7E, UM Csg shoe Nad 1927 Measured Depth, RKB: 2,439' Northings: 5,912,261.09 Eastings: 460,439.93 Total Vertical Depth, RKB: 2,308', Total Vertical Depth, SS: 2,159' Location of existing 5 1/2" 740.45' FNL, 3371.31' FEL, Sec 03, T09N, R7E, UM Intermediate Csg shoe Nad 1927 Measured Depth, RKB: 6,608.56' Northings: 5,911,283.56 Eastings: 457,819.58 Total Vertical Depth, RKB: 5,108.80' Total Vertical Depth, SS: 4,960.00' Location at Top of Productive 813.92' FNL, 3861.98' FEL, Sec 03, T09N, R7E, UM Interval (Bermuda) Nad 1927 Measured Depth, RKB: 6,757.69' Northings: 5,911,210.61 Eastings:457,728.66 Total Vertical Depth, RKB: 5,201.80' Total Vertical Depth, SS: 5,053.00' Location at Total Depth 1056.4' FNL, 4161.24' FEL, Sec 03, T09N, R7E, UM (Toe) Nad 1927 Measured Depth, RKB: 7,249.99' Northings: 5,910,969.78 Eastings: 457,428.53 Total Vertical Depth, RKB: 5,508.80' Total Vertical Depth, SS: 5,360.00' 2N-319A APD Page 3 of 14 Printed: 11-Aug-14 ORIGINAL A ion for Permit to Drill,Well 2N-319A Saved: 11-Aug-14 Requirements of 20 AAC 25.050(b) Please see Attachment 1: Directional Plan The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) Please reference BOP schematics on file for Nabors 9ES. 4. Drilling Hazards Information (Requirements of20AAC 25.005(c)(4)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Csg Setting Fracture Pore ASP Casing Size Depth Gradient pressure Drilling (in) MD/TVD(ft) (lbs. /gal) (psi) (psi) 16 108/ 108 10.9 N/A N/A 7-5/8 2438.8/2307.8 14.5 N/A N/A 5-1/2 6608.6/5108.8 15 2364** 2,124 3-1/2 7250.0/5508.8 15 2635** N/A • NOTE: The Nabors 9ES 5000 psi BOP equipment is adequate. Test BOP to 3500 psi. • ** NOTE: Pore pressure is estimated reservoir pressure. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) (A)ASP is determined as the lesser of 1)surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2)formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052)—0.1]D Where: ASP =Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb/gal 0.052 = Conversion from lb. /gal to psi/ft 0.1 = Gas gradient in psi/ft D =true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP—(0.1 x D) Where; FPP = Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. Drilling below surface casing (7-518") ASP = [(FG x 0.052)—0.1] D = [(14.5 x 0.052)—0.1] x 2,308' = 1,509 psi OR 2N-319A APD Page 4 of 14 Printed: 11-Aug-14 ORIGINAL A 'ion for Permit to Drill,Well 2N-319A Saved: 11-Aug-14 ASP = FPP—(0.1 x D) =(0.052*5109*8.9)—(0.1 x 2,308') = 2,134 psi 2. Drilling below intermediate casing (5-1/2") ASP = Reservoir Pressure—(0.1 x D) = (0.052*5509*9.2)—(0.1*5109) =2124 psi (B)Data on potential gas zones; The well bore is not expected to penetrate any gas zones. (C)Data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; The bottom-hole pressures from the 2N-319A's offset wells are: Well Pressure @ Date SI time prior to Comments datum (psi) Measured measurement (days) 2N-349A 3,208 7/26/2011 9,412 Injector, SI since Sep 09 2N-339 1,229 6/23/2012 222 2N-327 1,157 4/14/2014 370 2N-319 2,617 10/1/2009 3,100 Located along the same conduit as 2N-349A, SI since Jul 09 2N-325 3,141 3/19/2014 1,890 Injector 2N-345 3,288 12/24/2003 9,144 SI since Jan 2003. Due to the history of the Tarn field being unpredictable for formation pressures as the result of fractures ut emanating from existing injection wells, the Bermuda formation is assumed to be over pressured and the / 5-1/2" intermediate casing will be top set above the Bermuda, but below the Iceberg formation. Please see Attachment 2—Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005(c)(5)) Drill out from casing shoes and perform LOT or FIT in accordance with the Kuparuk LOT/FIT procedure that ConocoPhillips, Alaska has on file with the Commission. 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) Casing and Cementing Program Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) (lb/ft) Grade Conn. (ft) (ft) (ft) Cement Program 16 24 62.58 H-40 Welded 79' 29' 108'/108' Driven Existing Cemented to Surface 7-5/8 9-7/8 29.7 L-80 BTCM 2409.8' 29' 2438.8/2307.8 6- Hydril Cemented to 500 ft MD above C37 top 5-1/2 3/4x7- 15.5 L-80 563 6580' 29' 6608.6/5108.8 w/363 sx class G @ 15.8 ppg 1/2 H drilCemented to liner top w/59 sx class G @ 3-1/2 4-3/4 9.3 L-80 511 850' 6400' 7250/5509 15.8 ppg 2N-319A APD Page 5 of 14 Printed: 11-Aug-14 ORIGINAL A' ion for Permit to Drill,Well 2N-319A Saved: 11-Aug-14 Casing / Liner Design: The 85% collapse and burst ratings are listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 7-5/8" 29.7 L-80 3 BTCM 4790 4071 6890 5856 5-1/2" 15.5 L-80 3 Hyd563 4990 4241 7000 5950 3-1/2" 9.3 L-80 3 Hyd511 10530 8950 10160 8636 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Please reference diverter schematic on file for Nabors 9ES. 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) Drilling will be done using Fresh water and water-based LSND mud system having the following properties: Intermediate Production 6-3/4" hole 4-3/4" hole V 5-1/2" Casing 3-1/2" Liner Density 9.6— 10.0 ppg 9.6— 10.0 ppg YP 18-22 18-22 PV 12 - 16 14- 18 Initial Gels 4—8 4 -6 10 minute gels <18 <8 API Filtrate 4-12cc/30 min <10 cc/30 min HPHT Fluid Loss at 160 <12 <5 PH 9.5- 10.5 9.5- 10.5 Intermediate Hole Section: LSND mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity through the sticky upper clays. There is potential for lost circulation, particularly after the Campanian and Iceberg zones are penetrated. Maintain mud weight at or below 10.6 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required)will all be important in maintaining wellbore stability. Production Hole Section: LSND mud system. Ensure good hole cleaning by maintaining low end rheology and pumping of regular sweeps. Maximize fluid annular velocity. There is potential for lost circulation in the target Bermuda reservoir. Maintain minimum mud weight at or above 9.6 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids will all be important in maintaining wellbore stability. Diagram of Nabors 9ES Mud System is on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 2N-319A APD Page 6 of 14 ORIGINAL Printed: 11-Aug-14 A, ion for Permit to Drill,Well 2N-319A Saved: 11-Aug-14 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is not for an offshore well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) The proposed drilling program is listed below. Please refer to Attachment 3: Well Schematic. 1. End Sundry to abandon previously submitted 2. Begin new permit to drill after the FIT/LOT has been performed. 3. Drill 6-3/4"x 7-1/2" intermediate as per approved directional plan. Proposed hole section TD of wp03 is 6608.59 ft MD &5108.8 ft TVD. Ensure based on real time logs & mud logging data that the intermediate shoe is set in shale and above the Bermuda formation. Perform wiper trips every +/- 1500 ft MD. 4. Circulate bottoms up to clean hole, POOH and lay down 4" drill pipe 5. RU and run 5-1/2", 15.5#, L-80 with Hydril 563 connections on the intermediate casing to 6,608' MD/ 5,108' TVD and cement in place. 6. PU 2-7/8" DP required to drill the production section. 7. MU 4-3/4" bit on a 3-1/8" BHA and RIH. 8. Drill the 4-3/4" hole to a proposed TD of 7,250' MD/5,509' TVD. Run MWD/LWD logging tools in drill string as required for navigational monitoring and formation data gathering. (LWD: GR minimum, global availability of RES tool extremely limited, may not have access at time of drilling) a. Once 20 ft of new formation has been cut stop & perform FIT/LOT. Achieve minimum of 12.5 ppg EMW for drilling ahead. 9. POOH laying down the 2-7/8" drill pipe 10. RU casing crew and cementers. 11. MU and run the 3 %" HYD 511 liner on a 3-1/2" PH6 tubing work string. 12. Once liner is on depth, pump sufficient cement to place cement to the top of the liner. 13. Pressure up and set liner hanger, continue to pressure up and release liner hanger from running tool 14. Flush DP of cement, POOH laying down 3-1/2" PH6 tubing work string. 15. Run 3-1/2" completion tubing &sting seals into liner top SBE. 16. Land on depth&pressure test. 17. Set TWC&test in direction of flow. 18. ND BOPE&NU Tree 2N-319A APD Page 7 of 14 ORIGINAL Printed: 11-Aug-14 A `ion for Permit to Drill,Well 2N-319A Saved: 11-Aug-14 19. Remove TWC. 20. Pump diesel freeze protect. 21. Set BPV&test in direction of flow. 22. Rig down and move rig to 2N-337C. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill music be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; • All solid waste will be transported to the grind and inject facility at DS-4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1R-18 or DS 1B disposal facilities)or Prudhoe DS-4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. Contact Kuparuk Environmental Coordinator for questions regarding waste classification.(659-7212). 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Proposed Well Schematic 2N-319A APD Page 8 of 14 R i G ! N A L Printed:11-Aug-14 Ai 'ion for Permit to Drill,Well 2N-319A Saved: 11-Aug-14 Attachment 1 — Directional Plan 2N-319A APD Page 9 of 14 OIGINAL Printed.' 11-Aug-14 2N-31 9AwpO3 5D793 Plan Summary SURVEY PROGRAM Depth From Depth To Survey/Plan Tool r. 245.29 2550.00 2N-319 (2N-319) MWD 2550.00 2900.00 2N-319Awp03(Plan:2N-319A) INC+TREND ,....`. i v 2900.00 4400.00 2N-319Awp03(Plan:2N-319A) MWD 2900.00 6608.59 2N-319Awp03(Plan:2N-319A) MWD+IFR-AK-CAZ-SC _ �1r a"' 2900.00 - 6608.59 7250.02 2N-319Aw.03 Plan:2N-319A MWD -- /� CASING DETAILS ��® ,--- TVD MD Name Size 2308.24 2439.00 7 5/8" 7-5/8 5108.80 6608.59 5 1/2" 5-1/2 5508.80 7250.02 3-1/2"x4-3/4" 3-1/2 0 - Base Berm - 0° 7 5/8" Purple 7 5/8" 5- 5 1/2" Top Berm Se -ts 1 5 10p /0 0°o0 A° _ i. _ U 1 3-1/2"x6-3/4" Base Purple o - O 0000 O 5 1/2" - -- �, 1\ HJ IllibI ti 0 'T-� 0 2000 4000 6000 0 550 1100 1650 2200 2750 3300 3850 Measured Depth Horizontal Departure 0 �" 330 ..o - m 60- ` 2N-3 19 •' mo 3,m d ___._ __ ! 300 . 60 moo ,.m Cs t mm - 4200 .� .mo m % .am mm 8 30 ( 270 so mm .. • `7� �m o .m „m WOO 6.ra, _ 240 - 120 - U I8 0 I I I ) I I I I I I I I I I I I I I I I I I I I ill iii _ _. . 0 700 1400 2100 2800 3500 4200 4900 5600 6300 210 1sa 180 _ 7200 SECTION DETAILS ,zm - 7250 Sec MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLeg TFace VSec Target 1 2550.00 42.84 306.39 2391.03 2242.23 348.97 -480.80 5912053.80 1600414.47 0.00 0.00 154.04 -5208.8 2 2670.00 45.40 300.55 2477.21 2328.41 394.92 -550.48 5912100.10 1600345.04 4.00 300.00 179.27 3 4701.96 51.42 230.96 3919.91 3771.11 252.91 -1878.58 5911965.04 1599016.35 2.50-109.01 1300.77 TopBerm 4 6608.38 51.42 230.96 5108.67 4959.87 -685.74 -3036.26 5911032.55 1597853.90 0.00 0.00 2791.17 5 6608.59 51.42 230.96 5108.80 4960.00 -685.85 -3036.39 5911032.44 1597853.77 2.50-134.22 2791.33 6 6768.95 51.42 230.96 5208.80 5060.00 -764.81 -3133.75 5910954.00 1597756.00 0.00 0.00 2916.69 2N-319A DB 28Jan14 -5248.8 7 7250.02 51.42 230.96 5508.80 5360.00 -1001.68 -3425.85 5910718.68 1597462.70 0.00 0.00 3292.77 Top Berm Seis -5378.8 Base Berm -5416.8 Purple -5468.8 Base Purple -5413 395 Surface Location Geodetic Datum: North American Datum 1983 Magnetic Model: BGGM2013 TM Depth Reference: Plan:120.9+27.9 @ 148.80ft(Nabors 9ES) Magnetic Model Date: 29-Apr-14 A System(SS)Reference: Mean Sea Level Magnetic Declination: 19.10° e North /Y: 5911702.36 Ground Level/Mud Line: 120.90 To convert a Magnetic Direction to a True Direction,Add 19.10°East of East/X: 1600893.40 Rig: Nabors 9ES NO GLOBAL FILTER:Using user defined selection&filtering criteria ORIGINAL 0 co cks •...,. q co P as — M E= O m a < 0 > Z r- N M M a Y Y C = = a) N N = N L L aac? a ca Y Y N a a a o OflGINAL a z z 3 x ^ m 3 z o to v Mo N o (0 U) ) ,- .4. 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V (O (O (O N N V Z Y Y N d N eL to N N C 0 V c m a o M a et . a rn c €o a, w r, ORIGINAL COO 0 co � 00 W W ` 0) � N CO 0 0 a N wAili gO*,z z �t4o = 0 0 co m (0ro NI- v 0 N (3) C) ' O is N N 0 d 6) O Y co Uco M O O E m 0 N N q Q N N N 6 S C C) g. 41 U .8 . O y L w 0) a) 2 K L N O O V Ci C _ y "O O U d V C ` ud ) U m IR `(O- H CO is Ce � .0 m .0 • >> w J F r2 Z (O Q o g 0 0 CI) co (O CO N E F O (O 6) E O co co 0 O^ 0 (O Q K r 7 O .0 J 0 6 N l6 CO H O 'O U a C O L L .0 O )O ,_ O" N V M O W m CV ai 0 COo N U) co 0 "O La N N y0 O. O CO CO Q) (O CO N- CI Q n W O;0 3 OV aV Ou] Ma0 N O Nr (AmON � ri to CO• W m C a `0 0 O N- N V M 0) CO 0 C) C O CO l6 V O cc; V M CO V 0 0000 0 J C? ^. M M N (O N- O Z N co O O O O N I- 00 W 00 Iii L N: 6 cc; O 00 C.)'• O.0 0) V 0) 0 N (00 .0 > 0 N N M (6 N (O C D 12m O N 'CU 61. � M O M 0 03 C Y Y Z < 'O 0 0 (O CO) N C) CD O = ` O N Cr) 0 t o O O7 07 O U 0 O. O.ci< nnZSN r) W N N (0 O I,- (O co N Z Y Y N d N y Q a N N V co- (O N- w 2 C Q O T . 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N O r N 0 U C O U) r (0 u) C) N O _ lC _ a (u!/09Z)Jo;oe j uo!;eaedes Q U ORIGINAL MD Inc Azi TVD +N/-S +E/-W DLeg TFac Sec Target 550.00 42.84 306.39 2391.03 348.97 -480.80 0.00 0.0 .04 0 2550 2N-319Aw 03 =670.00 45.40 300.55 2477.21 394.92 -550.48 4.00 300.0. e.27 p 3 4701.96 51.42 230.96 3919.91 252.91 -1878.58 2.50 -109.01 x00.77 2550 2800 4 6608.38 51.42 230.96 5108.67 -685.74 -303626 0.00 0.00 2791.17 2550.00 To 7250.02 5 6608.59 51.42 230.96 5108.80 -685.85 -3036.39 2.50 -134.22 2791.33 6 6768.95 51.42 230.96 5208.80 -764.81 -3133.75 0.00 0.00 2916.69 2N-319A DB 28Jan14 2800 3100 7 7250.02 51.42 230.96 5508.80 -1001.68 -3425.85 0.00 0.00 3292.77 10:05,January 30 2014- ' 3100 3400 3400 3700 OBAL FILTER APPLIED: A 3700 3900 3900 4200 Depth From Depth To Survey:Plan Tool 245.29 2550.00 226319(2P-319) MWD 4200 4500 2550.00 2900.00 216319200p031Plan:2143194) PIC,TNEND 2900.00 4400.00 236319404603(P727:29.319*) MWD 2900.00 6600.59 2263196vp03(POe:29.3(94) MWD.IFn-Ao.CAZSC 4500 4800 6600.59 7250.02 21-319A05p03(Plan:2143194) MWD 660059 775002 216319Aw901)Plan:22281981 MWO.IFN-AE-CAZSC 4800 5000 TVD MD Name Size 2308.24 2439.00 7 5/8" 7-5/8 5000 5300 5108.80 6608.59 51/2" 5-1/2 5508.80 7250.02 3-1/2"x4-3/4" 3-1/2 5300 5600 5600 5800 5800 -- 6100 6100 6300 0/360 IN-31� 6300 6609 1c.- __-�__ ,' 6609 6700 150 6700 6800 30/330 �' 140 417 \ ' .\ .30 6800 6800 130 6800 6900 N....-,, , NN 6900 7000 120 --•-• 110 7000 7100 � ,100 'N \ 7100 7200 N\ \-r�9# 7200 7250 90 -�r N V \ I� a , _60/300 3Y3 \ Y � 60 / ,.. 70 • 60 3.340. � �t�� ���, ///�� 50 / . ll/! , v, x,t1A0‘01.4 15, , \ \//t4 ' ki4ltriiitrillr6 I //lilt lift !� �'ii,,,,i, ;?'. i- ' l+t!�az.� 9�'e.� 1212 -90/270 Ik\\.\' 7 �i't, 1 •, .� a.; 190 p 4 t/ , , vittAtriti , 41+ #441 •,101100, -ilit, 1,0 % \ ii./ , /le 1 p,,4 V Ot foi/ / /,•, y fr-fil.4 \\ . 60 '' V° ' if. : / i% ffr V/ ifi'1 \\N. „ , ___,- _-A 1 . , '0,f9ftr/P1 120/240 80 I,} � 120 90 0 1 / / 10,.107/' \:::444:\\46 ,, -, -' - 100 1._.. �t�I� ,fir 110 ��'',E�/ •0, 7/ 5 phi, ,, ,/y 130 ' -150/210 140 .. 1 . 150 150 -180/180 ▪ 29 -- 21 92 -tr 0,74 0»3645,2 -X- 2N 815.29 3218214235 62 -X- 1 212 4- 2. 93:92 - -e. 29 NV -e- -e- v3 00x962592 4. 2N '9,M2 90 -e- 2N »326:403.9095 4E- 29 24050.2N445m3040 ÷ 2N 21226.2N.0209 -I-- 22 $ .a 2220.94.71,.2.222.212222",0790 $ . + 2N �- N P 222,�.Nn,.2N222P.1.2N222P.",07V2 P nen 2N,;;::n 2»�;:.'»217.,011 W .e- 2N � Nan29»6309240 -fr N + 29 922„.02199 -� P .29242 "fr 29 0064.254375445 2922(P004292z29 -1e 24210.2.210 26 4329 -$e- o 21 MOa(o �:M 3`. 202;90 ▪ 21251,.2.014 271-3110 1x7 j(- 292x1.2N 221,2N Y1 V2 fl ' \ I -1V4 $ 06299629402996n40929,0371:29 elmilm WELLBL .GET DETAILS(MAP CO-ORDINATES) ,6:44,July o92o,4 2N_319Awp03 Name TVDSS +N/-5 +E/-W Northing Easling Shape Temp 4010.00 64.28 -2111.22 5911777.65 1598782.75 Circle(Radius:1: 2N-319A DB 28Jan14 5060.00 -764.81 -3133.75 5910954.00 1597756.00 Circle(RS us.1: Quarter Mile View 14000 10500 �62 q, .. 2 3 5 2N 3og 2N 32 5A N! 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IN 41'911 411.11184 -cD MI WI _ ••ri•U•BI[iiI•I•Ma1Ia1► •rnUiRUIAIa•LunurURI _e ■ 11111111111111EMMEMIMML z MNIIN•L1!I•UUPLIIU ■, 11111111111111111111101111•111M-21 ff ■■■■■■■1151■■■■■■ ■iIIFiL1IUip �i =q ■ ■■■ ■■■, r ■■■■ _... _ I■■■■■■■■ ■■■■■■■■■ I■■■■■■■■ ■■■■I..I. ■■ ■ i.._ _ ■■■ ■■■ _ • ME Wm](+}INoNK-)flnoS ORIGINAL 2N-319A wp03 Surface Location 7 ,_ ti CPA:Coordinate Converter - � From To: Datum (NAD27 .I Region: jalaska .1 Datum: [gp27 .1 Region: ralaska H Latitude/Longitude (Decimal Degrees 71 C Latitude/Longitude Decimal Degrees .1 UTM Zone.l --_ _ South C UTM Zone: True-- f South State Plane Zone.14 ,,I Units: Ius-ft .I C State Plane Zone:1 4 ,1 Units: jus-ft . C Legal De c npticn'NAP 27 rnlci C- Legal Description(NAD 27 only) Starting Coordinates: — — Legal Description ------------------ X: 1460859.30 Township: 1009 IN.J Range: 1007 IE _.1 Y: 15911953.41 Meridian IU J Section:13 IFNL . 154.213312 'FEL z1 1733.78076 Transform I Quit I Help 1 • 2N-319A wp03 Kick Off Point ttj CPAI Coordinate Converter From: To: Datum: Region: Datum: Region: s NAD 9 lalaska � i NAD27 .� Ialaska . t" Latitude/Longitude 'Decimal Degrees 4.7.1 ( Latitude/Longitude recimal Degrees . C UTM Zone:1 r South C UTM Zone:1True i South t: State Plane Zone:14 . mss: Ius-ft I C State Plane Zone: [4 , Units: Ius-ft .1 C Legal LesaIptrur,i'J`,D 27 only) ( Legal Description(NAD 27 only) -Starting Coordinates: Legal Description X 1460380.35 Township: 1010 IN.I Range: 1007 1E .1 Y: 15912304.83 Meridian IU Section:134 1-FN L .1 14985.2115 [FEL • 11214.0651 I— Transform 9 Quit I Help 1 -- __ ORIGINAL 2N-319A wp03 Intermediate Casing tf3, CPAI Coordinate Converter F,, From: i To:- ... Datum: (NAD27 .j Region: alaska iiii Datum: IN,41327 Region: ialaska j C Latitude/Longitude Decimal Degrees .I C' Latitude/Longitude !Decimal Degrees f UTM Zone: 1 i--- South C' UTM Zone: True South C• State Plane Zone: 4 ,Units: lus.k J C State Plane Zone: (4 J Un ::limit _._.1 1 C Legal De::cription(NAD27 only j a Legal Description(NAD27 only) Starting Coordinates: — Legal Description X: 1457819.58 Township: i0Q9 IN Range: 1007 1E .j Y: 15911283.56 Meridian: lu j Section:13 IFNL w 1740.44940 !FEL H 13771.3148 ii Transform I Quit I Help 2N-319A wp03 TD —i r. CPA'Coordinate Converter I o O 1., p From: To: Datum: 1NAD27 _ Region: alaska .j Datum: (NAD27 .j Region: {alaska ii. 1 r Latitude/Longitude !Decimal Degrees . C Latitude/Longitude Decimal Degrees .J UTM Zone: I— South C UTM Zone:'True r Sctdh t: State Plane Zone: 4 ( Units: lus-ft . C State Plane Zone: (4 =i Link jus* J .._1.-,:,71 L._ cxipuur,0.`.LL7 enly) C: Legal Description(NAD27 only) Starting Coordinates: — Legal Description X: 1457428.53 Township: 1809 IN .I Range: 007 FE .j Y: 15910969.78 Meridian: IU J Section:13 FNL H1056.4396 IFEL .j 4161.2443 Transform J Quit I Help a ...<. --. —� ORIGINAL 2N-319A wp03 7-5/8" Casing Shoe CPAI Coordinate Converter 1 o (:0 I From: M –To:-- Datum 1NAD27 v Region: Ialaska ..1 Datum: 'NAD27 Region: Ialaska ' Latitude/Longitude !Decimal Degrees C Latitude/Longitude Decimal Degrees . r" UTM Zone: I l.-- South C UTM Zone: True r South .% State Plane Zone:14 .'.1 Units: us-ft _II t_ State Plane Zone: 14 .1 Units: fus-ft C Legal Description(NAD27 only) ti" Legal Description[NAD27 only) Starting Coordinates: Legal Description __...._._.__. X: 1460439.93 Township: 1010 IN Range: 007 E Y: 15912261.09 Meridian: U Section IFNL zi 15028.6452 (FEL • 1154.3209 Transform 1 1 Quit I Help 1 L. 2N-319A wp03 Top Bermuda Q CPAICoordinate Converter ..v �' lig 1`" .j� –From: - –To:— Datum: NAD27 .I Region: Ialaska Datum: NAD27 . Region: Ialaska vl C Latitude/Longitude Decimal Degrees ±J (- Latitude/Longitude Decimal Degrees .11 C UTM Zone: I E South C UTM Zone: True E South t. State Plane Zone: [4 .j Units: 'us-ft . C State Plane Zone:1`4 .I Units: urs-ft . I C Legal Description 1NAD2?only) 6- Legal Description(NAD27 only) Starting Coordinates: –Legal Description X: 1457728.66 Township: 1009 IN . Range: 1007 lE . Y: (5911210.61 Meridian: IU j Section:113 1FNL jj 1813.91555 IFEL __.f 13861.9781 1,_-- Transform_......___ Qtat Help i @ 1,Ri 11G10 NAL A 'ion for Permit to Drill,Well 2N-319A Saved' 11-Aug-14 Attachment 2— Drilling Hazards Summary (To be posted in Rig Floor Doghouse Prior to Spud) 2N-319A Drilling Hazards Summary 6-3/4" x 7-1/2" Hole / 5-1/2" Casing Interval Event Risk Mitigation Strategy Level Campanian/Iceberg Sands Low Control with higher MW and proper drilling practices. High ECD and swabbing with Moderate Condition mud prior to trips. Monitor ECD's with higher MW's required PWD tool while drilling across pay interval. Pump and rotate out on trips as a last resort. Abnormal Reservoir Pressure Low Follow mud weight schedule and do not fall behind. Stripping Drills, Shut-in Drills, PWD Tools, and Increased mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Lost Circulation Low Use PWD to monitor hole cleaning. Reduced pump rates, Mud rheology, LCM. Use GKA LC decision tree. 4-3/4" Hole / 3-1/2" Liner Interval Event Risk Mitigation Strategy Level Plan mud weight according to expected Abnormal pressure pressure. Flow check immediately upon encountered Moderate entering Bermuda, and again —50' into Bermuda. Have mud additives ready and prepared to weight up if needed. Condition mud &clean hole prior to trips. High ECD/Tight hole on Monitor ECDs with PWD tool while drilling trips/Swabbing Moderate across reservoir interval. Hole cleaning best practices. Backream out on trips as a last resort, proper hole filling (use of trip sheets) Keep hole clean—use PWD to monitor hole Lost circulation Moderate cleaning. If losses occur—reduce pump rates and mud rheology, use LCM Well Proximity Risks: Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b) is provided in the attachments. In general, no significant clearance issues exist with the 2N-319A well plan. The closest well in is 2N-347 with a separation factor of 1.36. The well is 68.41' distance between centers at a depth of 5075' MD. Drilling Area Risks: Reservoir Pressure: Offset injection conduits have the potential to increase reservoir pressure over predicted, although this is unlikely, the rig will be prepared to weight up if required. Due to the greater degree of reservoir pressure uncertainty in the Bermuda targeted interval, the Bermuda will first be topset to keep the shallower unstable shale behind pipe prior to penetrating the Bermuda. 2N-319A APD Page 10 of 14 ORIGINAL Printed: 11-Aug-14 P tion for Permit to Drill,Well 2N-319A Saved: 11-Aug-14 Lower Shale Stability: Higher mud weights in the intermediate will require higher mud weights to stabilize. Standard LCM material and well bore strengthening pills are expected to be effective in dealing with lost circulation if needed. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. 2N-319A APD Page 11 of 14 0 .RIGINAL Printed: 11-Aug-14 P tion for Permit to Drill,Well 2N-319A Saved: 11-Aug-14 Attachment 3— Proposed Well Schematic Tarn 2N-319A Wasp(wp03) Rotary Sidetrack Tooset Conventional Slant Producer ConocoPhillips Proposed Wellbore Schematic _ -FMC Gen V 3-Y"TREE Brunswick 7/10/14 J 16"Existing Cemented Conductor: 16"62.5#H-40 108'MD 0 3 W Camco DS Nipple 2.875" 1,000 MD ND =PPG - 3WW x 1"Camco MMG Existing Surface Casino: 7-5/8"29.7#L-80 BTCM 2,439'MD/2,308'TVD @ 41° 3'/:'x 1"Camco MMG Sidetrack KOP off cement plug -42 degrees in open hole©-2,550'MD > arimpa�iari T42;742`IA(3:( 329'FVF)):: Ca rlpahtad To�2P13t9Av1p0327.4 '.MD.2527':TLD:::::: Tubina: 3Wx1"Camco MMG 3-%"9.3#L-80 EUE8RD SND 5 PPG up with TOC 15.8ppg�5/-4,500'MD 6-%"x 7-1/2" Intermediate lution Hole 4" DP 3%"x 1"Camco MMG 1: XXX'MD/XXX'TVD Ice6erg:Tpp:S,;t Op':W1D<41&$'?v,D>::::: .:;:aceeerg Top:zrr-3iBRwp03 sail ua aa's2':rvo:�:�:�:'1 sok ZXP Liner Top Packer-200'inside 5-W Csg Flex Lock SBE Liner Hanger "ID 20' Intermediate Casing Tooset: • 5-1/2"15.5# rie: otc 6,608. . . . . . :j=acistind C rodudion Chsina-••••:• ::•57:05181('3S'.r.0 S8S6S7Scp:vob 9: . .. :: : Base Bermuda 2N-319Awp03 7.041'MD 5,378' TVD Cemented Production Liner: 3-1/2"9.3#L-80 Hydril 511 7,250'MD/5,509'TVD @ 51° 2N-319A APD Page 12 of 14 Printed: 11-Aug-14 C E \ I G I N A L P tion for Permit to Drill,Well 2N-319A Saved: 11-Aug-14 Attachment 4-Cement Summary 5-1/2" Intermediate Casing Cement Job Cement 5-1/2" casing from shoe @ 6,609' MD to 4,500' MD (minimum of 500' above the top of the C37) with Class G + Adds @ 15.8 PPG. Assume 40% excess in the open hole volume. Assume under-reamer to bit distance of 100 ft. Lead Slurry: (6,609'-6,509') x 0.0834 ft3/ft x 1.40 (40% excess) = 11.7 ft3 in open hole (6,509'-4,500')x 0.1417 ft3/ft x 1.40 (40% excess) = 398.5 ft3 in open hole 80' shoe track x 0.1335 ft3/ft x 1.0 (0% excess) = 10.68 ft3 Total volume = 11.7 ft3 + 398.5 ft3+ 10.68 ft3=420.88 ft3=> 362.8 Sx @ 1.16 ft3/sk System: 363 Sx Class G @ 15.8 PPG 3-1/2" Liner Cement Job Cement 3-1/2" liner from TD @ 7,250' MD to liner top @ +/- 6,400' MD (200' inside the 5-1/2" 15.5# casing) with Class G + Adds @ 15.8 PPG. Assume 40% excess in the annular volume, 0% excess inside casing. Lead Slurry: (7,250'-6,609')x 0.0562 ft3/ft x 1.40 (40% excess) = 50.43 ft3 in open hole 200' inside 5-1/2" 15.5#casing x 0.0668 ft3/ft x 1.00 (0% excess) = 13.35 ft3 80' shoe track x 0.0488 ft3/ft x 1.0 (0% excess) = 3.90 ft3 Total volume= 50.43 ft3+ 13.35 ft3 + 3.90 ft3=> 67.68 ft3=> 59 Sx @ 1.16 ft3/sk System: 59 Sx Class G @ 15.8 PPG 2N-319A APD Page 13 of 14 ORIGINAL Printed: 11-Aug-14 PTD 214 -/[ Ferguson, Victoria L (DOA) From: Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com> Sent Wednesday,August 13,2014 12:39 PM To: Ferguson,Victoria L(DOA) Subject RE: KRU 2N-319A(PTD 214-119) Follow Up Flag: Follow up Flag Status: Completed With regards to the flow check procedure,yes, we will do the same drill in &flow check procedure to ensure safety. With regards to mud weight &expected pressure for 2N-319A, it is predicted to be at 2500 psi, given the 5249 ft TVD of the Bermuda in 2N-319A that equates to a 9.2 ppg reservoir. My plan is to penetrate the Bermuda with a 9.6 ppg mud weight, and have heavier 12.0 ppg fluid prepared as contingency as the highest prediction is 3200 psi or 11.7 ppg equivalent. I'm not sure the e-mail from Dan below states a reservoir pressure of 2500 psi equating to 11.0 ppg, perhaps a typo. From: Ferguson, Victoria L(DOA) [mailto:victoria.ferguson@alaska.gov] Sent: Wednesday, August 13, 2014 10:48 AM To: Brunswick, Scott A Subject: [EXTERNAL]KRU 2N-319A(PTD 214-119) Scott, Below is a response from Daniel that explains plans for mud weight upon penetration of the Bermuda. Are these plans the same for 2N-319A? If not please outline any differences or additions. Thanx, Victoria From: Bearden, 3 Daniel [mailto:J.Daniel.Bearden@conocophillips.com] Sent:Tuesday, August 12, 2014 2:23 PM To: Ferguson, Victoria L(DOA) Subject: RE: KRU 2N-350A(PTD 214-111) Hi Victoria, Our reservoir engineering group has done a good job so far in this year's Tarn drilling program to provide a range of expected pore pressures, with a most likely midpoint—which has been fairly accurate. In the case of 2N-350 rotary sidetrack,they have provided us a range of 2,400 (9.1 ppg)to 3,500 psi (13.2 ppg), but with a most likely midpoint of 2,500 psi (11.0 ppg). Additionally, offset injection has been SI which should reduce the maximum anticipated reservoir from 3,500 psi. Our plan is to weight up to 11.0 ppg and perform a 30-minute flowcheck immediately upon penetration of the Bermuda reservoir, then flowcheck during connections. Based on what we see, we will weight up accordingly. Also, MI will have tanks on location with KWF up to 13.4 ppg and have additional barite on location to cover any extra weight needed. Finally,the topset design we are using at Tarn mitigates the hazard of encountering high Bermuda pressure because the shallow weaker zones(Iceberg/Campanian) will be behind pipe prior to penetrating the Bermuda. 1 Thanks, Daniel Bearden Drilling Engineer ConocoPhillips, Alaska 907-263-4864 work 907-602-7068 cell From: Ferguson, Victoria L(DOA) [mailto:victoria.ferquson@ alaska.gov] Sent: Tuesday, August 12, 2014 1:56 PM To: Bearden,J Daniel Subject: [EXTERNAL]KRU 2N-350A(PTD 214-111) Daniel, The maximum BHP is 3500 psi at 5081'TVD(13.2 ppg EMW) but your plans are to drill with 11.0 ppg. Please explain your contingency plans if you encounter a 3500 psi BHP. Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W 7th Ave,Ste 100 Anchorage,AK 99501 Work (907)793-1247 victoria.ferouson(cilalaska nov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Ferguson at(907)793-1247 or Victoria.Ferguson@alaska.gov 2 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. WELL,WAMiE: 'K?() , �2 )Li Ili V bevel:C''-ile;'t Sa. price Exr' raccry Siratigr:,-oItie.TestRon-Conver,tiorai 14 < �vFf r: s t., ,rtA1< 2;VL5 Iou.in Check bcx for Appropriate Letwek./ Paragraphs. to be included in 1;rensmitta.i Levier :ECK OPTIONS TEXT I'OR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing well Permit (If last two digits No. , API No. 50- - - in API number are Production should continue to be reported as a function of the original between 60-69) API number stated above. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name Pilot Hole ( PH) and API number (50- - - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce / inject is contingent upon issuance of a Spacing Exception conservation order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 MC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. 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E a) �, ai J v E c •- a) a) a) •- 0 0 0 E E c a) 3 a) c -c' ,C H H H .N ate) a°) >_ _ a a p o g o E �; D; -(g c, >, a) iii 0 c = -0 a a 0 0 CO o 0 7 L; �' CO -0, m a a C O O, r O 0 a) m, a) 0. 0 0 U c a _1 D 5 5 u) V- 0 0 0_ a 0 5 ¢ a z o cn a U O; a s '- a "_ a co m U _ 2 a 0 (n co o W a O N M )f) co r `c) O) O N M N )L) CO N- CO 0) O (i",1 M A O CO r W m N COO COr CO O) N N N N N N N N N N M M M M M M M M M ✓ O U C V' V 0 a O C CD IC N (N " OCD 03 N U0 O Q N 0) 0 M O N p y w00 ro y J N- 'N 0 CD 0 c co c o co 0 > 0 E a2. s c) 0' > a6 o > a a W a O a Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. FINAL WELL REPORT MUDLOGGING DATA 2N-319A Provided by: Approved by: Kelly Umlauf Compiled by: Allen Odegaard Br i t t e n A d a m s Be n C a l o Distribution: 12/5/2014 T.D. Date: 11/15/2014 2N-319A 1 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW ................................................................................................2 1.1 Equipment Summary ......................................................................................................................2 1.2 Crew................................................................................................................................................2 2 WELL DETAILS .....................................................................................................................................3 2.1 Well Summary.................................................................................................................................3 2.2 Hole Data........................................................................................................................................3 2.3 Daily Activity Summary...................................................................................................................4 3 GEOLOGICAL DATA.............................................................................................................................6 3.1 Lithostratigraphy .............................................................................................................................6 3.2 Mudlog Summary............................................................................................................................7 3.2.1 KOP to C-80 ............................................................................................................................7 3.2.2 C-80.........................................................................................................................................7 3.2.3 Campanian Sand.....................................................................................................................7 3.2.4 C-50.......................................................................................................................................10 3.2.5 C-40.......................................................................................................................................11 3.2.6 C-37.......................................................................................................................................11 3.2.7 Iceberg...................................................................................................................................12 3.2.8 T-7 .........................................................................................................................................13 3.2.9 T-4.1 ......................................................................................................................................14 3.2.10 Bermuda Sand.......................................................................................................................14 3.2.11 Base Bermuda.......................................................................................................................16 3.2.12 Top Purple.............................................................................................................................16 3.2.13 Base Purple...........................................................................................................................17 3.2.14 C-35 to TD.............................................................................................................................17 3.3 Isotube Summary..........................................................................................................................18 3.4 Sampling Program / Sample Dispatch..........................................................................................19 4 PRESSURE / FORMATION STRENGTH DATA.................................................................................20 4.1 Pore Pressure Evaluation.............................................................................................................20 4.2 Pore Pressure Plot........................................................................................................................21 4.3 Quantitative Methods....................................................................................................................22 5 DRILLING DATA..................................................................................................................................23 5.1 Survey Data..................................................................................................................................23 5.2 Bit Record.....................................................................................................................................27 5.3 Mud Record ..................................................................................................................................28 6 SHOW REPORTS ...............................................................................................................................30 7 DAILY REPORTS ................................................................................................................................33 Enclosures: 2”/100’ Formation Log (MD/TVD) 2”/100’ Drilling Dynamics Log (MD/TVD) 2”/100’ LWD / Lithology Log ) MD/TVD) 2”/100’ Gas Ratio Log (MD/TVD) Final Data CD 2N-319A 2 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type / Position Total Downtime Comments Ditch gas QGM Agitator (Mounted in possum belly) Flame ionization total gas & chromatography. 0 — Effective Circulating Density (ECD) From Schlumberger 2,442’ to 6,519’ 0 BHA too small for ECD tool in Production Section Hook Load / Weight on bit From Schlumberger & Encoder from Canrig Drilling Technology LTD. 0 — Mud Flow In Derived from Strokes/Minute and Pump Output 0 — Mud Flow Out Nabors 9ES 0 — Mudlogging Unit Computer System HP Compaq Pentium 4 (X2, DML & Rigwatch) 0 — Mudlogging Unit DAC box In-unit data collection/distribution center 0 — Pit Volumes, Pit Gain/Loss Canrig Drilling Technology LTD pit sensors 3.0 Power Failure Pump Pressure Nabors 9ES 0 — Pump stroke counters Nabors 9ES (Stroke counter #1 & #2) 0 — Rate of Penetration Nabors 9ES 0 — RPM Nabors 9ES 0 — Torque Nabors 9ES 0 — 1.2 Crew Unit Type : Steel Arctic Unit Number : ML059 Mudloggers Years *1 Days *2 Sample Catchers Years Days *2 Technician Days Allen Odegaard 17 23 Jared McCleskey 1 17 Howard Lamp 2 Britten Adams 3 14 Ben Calo 1 13 Ben Calo 1 10 Dean Kekaulua 6 4 *1 Years experience as Mudlogger *2 Days at wellsite between spud and total depth of well 2N-319A 3 2 WELL DETAILS 2.1 Well Summary Well: 2N-319A API Index #: 50-103-20271-01-00 Field: Kuparuk River Field Surface Coordinates: 54.2' FNL, 733.8' FEL, Sec 3, T009N, R7E, UM Borough: North Slope Primary Target Depth: 6,765’ MD State: Alaska TD Depth: 5,568.62’ TVD Rig Name / Type: Nabors 9ES, Arctic Triple Suspension Date: N/A Primary Target: Tarn Bermuda Permit to Drill Number: 214-119 Spud Date: 11/3/2014 Ground Elevation: Pad 120.9’ MSL Completion Date: RT Elevation: RKB 148.8' MSL Completion Status: Completed Secondary Target & Depth: Purple – 7,051’ MD Classification: Sidetracked producer TD Date: 11/15/2014 TD Formation: C-35 Formation Days Drilling: 13 2.2 Hole Data Maximum Depth Shoe Depth Hole Section MD (ft) TVDSS (ft) TD Formation Mud Weight (ppg) Dev. (oinc) Casing/ Liner MD (ft) TVD SS (ft) FIT / LOT (ppg) Surface Casing — —— 9.6 39.83 7.625” 2,441 -2,154 14.2 7.5”/6.75” 6,580 -4,951 T-4.1 9.6 51.79 5.5” 6,570 -4,945 15.8 4.75” 7,300 -5,576 C-35 10.8 48.95 3.5” 7,290 -5,568 — 2N-319A 4 2.3 Daily Activity Summary 10/29/2014 Canrig began rigging up DML Unit 059 beginning at 17:00 hours. Rig began cutting and pulling casing. 10/30/14 Canrig continue to rig up DML Unit 059. Rig continued to cut and pull casing. 10/31/14 Canrig began monitoring gas. Rig finished cutting and pulling casing, and began rigging up to cement. Midnight depth was 2,802’ MD. 11/1/14 Canrig continued to monitor gas. Rig cemented well, logged well via wireline, and a blow-out preventer test. Midnight depth was 2,802’ MD. 11/2/14 Canrig continued to monitor gas. Rig attempted to drill out cement, encountered MWD issues, and pulled out of well to perform maintenance on MWD tools. Midnight depth was 2,331’ MD. 11/3/14 Canrig began logging gas and lithostratigraphy, with 50ft formation samples, and 500ft gas samples, collected through the Bermuda formation. 5’ formation samples were collected while determining wellbore placement. Rig finished drilling cement, performed a leak-off test/formation integrity test @ 14.2 ppg, began drilling Tarn 2N-319A at 2441’ MD at 08:10 hrs, with a sidetrack kickoff point of 2465’ MD, and continued drilling ahead. Midnight depth was 2,250’ MD. 11/4/14 Continued drilling ahead to 4,428’ MD, and pulled back to shoe. Midnight depth was 4,428’ MD. 11/5/14 Washed/reamed from the shoe to bottom, and continued drilling. Midnight depth was 5,764’ MD. 11/6/14 Continued drilling to 6,850’ MD, then tripped out of well. Midnight depth was 6,850’ MD. 11/7/14 Tripped out of well, removed bottom-hole assembly, and prepared to install 5.5” casing. Midnight depth was 6,850’ MD. 11/8/14 Continued installing casing to 6,570’ MD, and prepared to cement. Midnight depth was 6,850’ MD. 11/9/14 Cemented well, and rigged up for casing test. Midnight depth was 6,850’ MD. 11/10/14 Pressure tested casing/shoe, and performed a blow-out preventer test. Midnight depth was 6,850’ MD. 11/11/14 Continued testing blow-out preventers, picked up bottom hole assembly and began running in well. Midnight depth was 6,850’ MD. 2N-319A 5 11/12/14 Continued running into well, drilled out cement from 6,534’ to 6,568’ MD, performed LOT/FIT @ 15.8ppg, and continued drilling ahead. Began collecting 20’ formation samples and 30’ gas samples. Midnight depth was 6,674’ MD. 11/13/14 Continued drilling from 6,691’ to 6,753’ MD, pulled back to shoe to cool off draw works motor, drilled from 6,753’ to 6,857’ MD, increased mud density from 9.8 to 10 ppg to control gas, and continued drilling ahead. Midnight depth was 6,678’ MD. 11/14/14 Continued drilling from 6,879’ to 7103’ MD, increased mud density from 10.6 to 10.8 ppg to control gas, and continued drilling ahead. Midnight depth was 7,106’ MD. 11/15/14 Continued to drill until final depth was called, and mud density was increased from 10.8 to 11.3 ppg throughout the day to control fluid gains. Tarn 2N-319A was reached TD at 7,300’ MD. 11/16/14 Washed/reamed, increased mud density from 11.3 to 11.6 ppg to control gas, monitored the well before pulling out, and then proceeded to pulled out of the well. 11/17/14 Reamed/washed on the way out of the well, and began logging well via wireline. 11/18/14 Completed wireline logging, and began lining production section with 3.5“ casing. 11/19/14 Run liner to bottom. 11/20/14 Cement liner; release DML Unit 59—rig down. 2N-319A 6 3 GEOLOGICAL DATA 3.1 Lithostratigraphy LWD tops refer to provisional picks by the wellsite geologist. PROGNOSED LWD PICK FORMATION MD (ft) TVD (ft) MD (ft) TVD (ft) Kick Off Point to C-80 2,550 2,390 2,465 2,327 C-80 2,671 2,475 2,662 2,475 Campanian Sand 2,748 2,529 2,739 2,529 C-50 4,396 3,715 4,467 3,793 C-40 4,813 3,984 4,814 4,012 C-37 5,093 4,159 5,116 4,196 Iceberg 5,421 4,363 5,411 4,375 T-7 6,083 4,777 6,054 4,772 T-4.1 6,464 5,014 6,450 5,020 Top Bermuda 6,767 5,202 6,765 5,218 Seismic Bermuda 6,854 5,256 6,839 5,266 Base Bermuda 7,030 5,366 6,997 5,370 Top Purple 7,074 5,394 7,051 5,405 Base Purple 7,175 5,456 7,131 5,458 C-35 7,210 5,478 7,170 5,484 TD 7,360 5,572 7,300 5,576 2N-319A 7 3.2 Mudlog Summary 3.2.1 KOP to C-80 2441’ to 2,662' MD (-2159' to -2475' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 427 5 151 46 1 9 Claystone, Unconsolidated Sand (2441' - 2560') = medium dark gray to medium light gray; soft to barely consolidated; very poor to no induration; malleable to pulverulent; silty to clay texture; dull earthy luster; very adhesive, not very cohesive; pasty to tacky; no discernible fracture, cuttings habit or texture; no reaction to HCl; no evidence of hydro- carbon indicators; occasional loose sand grains. Claystone (2560' - 2630') = medium dark gray to medium light gray with some brownish gray colors; lumpy to clumpy consistency; malleable to pulverulent tenacity; earthy to clayey fracture; nodular to massive clotted cuttings habit; dull to earthy luster; colloidal to clayey texture; massive to thick structure; non- calcareous; no evidence of hydrocarbon indicators; occasional trace loose sand grains; trace to common white to light gray ash. Claystone, Unconsolidated Sand (2630' - 2680') = medium dark gray to dark gray; unconsolidated to soft; no to very poor induration; pulverulent; silty to gritty texture; dull luster; adhesive; very mushy; no discernible cuttings habit, fracture or structure; no HCl reaction; no hydrocarbon indicators; very common white to light gray ash scattered throughout sample. 3.2.2 C-80 2,662’ to 2,739' MD (-2,326' to -2,380' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 153 28 100 46 8 24 Claystone (2685' - 2740') = medium dark gray to dark gray with slight light olive hues colors; lumpy to clotted consistency; malleable to pulverulent tenacity; irregular to earthy fracture; massive to rounded cutting habits; waxy earthy luster when wet; clayey to slight smooth texture with occasional silty texture; massive to thick bedding structure; no hydrocarbon odor; yellowish orange fluorescence color; very weak HCl reaction in bulk sample. 3.2.3 Campanian Sand 2,739’ to 4,467' MD (-2,380' to -3,644' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 353 14 117 41 0 18 Claystone (2750' - 2805') = medium dark gray to dark gray with slight light olive hues colors; pasty to clotted consistency; malleable to pulverulent tenacity; irregular to earthy fracture; massive to rounded cutting habits; waxy earthy luster when wet; clayey to slight smooth texture with occasional silty texture; massive to thick bedding structure; no hydrocarbon odor; trace yellowish green fluorescence color; very weak HCl reaction in bulk sample. 2N-319A 8 Tuff (2815' - 2880') = very pale orange to grayish brown orange with occasional grayish yellow hues colors; mushy to clumpy consistency; malleable tenacity; earthy to irregular fracture; massive to rounded clotted cutting habits; waxy to earthy when wet luster; clayey to smooth texture; contorted to soft sediment deformation bedding structure; no hydrocarbon odor in bulk sample; yellow orange visual fluorescence color; no fluorescence cut colors; no residual; none to very weak HCl reaction in bulk sample. Claystone (2890' - 2950') = medium dark gray to dark gray with slight light olive hues colors; mushy to clotted consistency; malleable to pulverulent tenacity; irregular to earthy fracture; massive to rounded cutting habits; waxy earthy luster when wet and dull to earthy when dry; clayey to slight smooth texture with occasional silty texture; massive to thick bedding structure; no hydrocarbon odor; trace yellowish green visual fluorescence color; no HCl reaction in bulk sample. Siltstone (2960' - 3005') = dark gray to medium dark gray with olive gray hues colors; stiff to crunchy tenacity; slightly hackly to splintery fracture; tabular to elongated cutting habits; frosted luster; matte to silty texture; thin bedding structure; no odor in bulk sample; no visual fluorescence colors in sample; weak HCl reaction in bulk sample. Claystone (3015' - 3070') = medium dark gray to dark gray with slight light olive hues colors; pasty to clotted consistency; malleable to pulverulent tenacity; irregular to earthy fracture; massive to rounded cutting habits; waxy earthy luster when wet; clayey to slight smooth texture with occasional silty texture; massive to thick bedding structure; no hydrocarbon odor; 1% trace yellowish green fluorescence color; very weak HCl reaction in bulk sample. Sandstone (3080' - 3145') = clear to translucent with light olive hues, black lithics, white minerals, and slight greenish gray minerals colors; quartz dominant with lithic framework; very fine to fine grain size; very well to wells sorting; angular to subangular angularity; very low to low sphericity; consolidated to firm friable hardness; grain enlargement to overgrowth cement; matrix and cement grain support; thin to lenticular bedding structure; no odor in sample; no visual fluorescence colors no HCl reaction in bulk sample. Claystone (3155' - 3210') = medium dark gray to dark gray with slight light olive hues colors; pasty to clotted consistency; malleable to pulverulent tenacity; irregular to earthy fracture; massive to rounded cutting habits; waxy earthy luster when wet; clayey to slight smooth texture with occasional silty texture; massive to thick bedding structure; no hydrocarbon odor; trace yellowish green fluorescence color; no HCl reaction in bulk sample. Siltstone (3220' - 3265') = dark gray to medium dark gray with olive gray hues colors; crumbly to brittle tenacity; slightly hackly to splintery fracture; tabular to elongated cutting habits; frosted luster; matte to silty texture; thin bedding structure; no odor in bulk sample; 1% visual fluorescence yellowish green color; weak HCl reaction in bulk sample. Claystone (3295' - 3350') = medium dark gray to dark gray with slight light olive hues colors; pasty to clotted consistency; malleable to pulverulent tenacity; irregular to earthy fracture; massive to rounded cutting habits; waxy earthy luster when wet; clayey to slight smooth texture with occasional silty texture; massive to thick bedding structure; no hydrocarbon odor; 1% trace yellowish green fluorescence color; no HCl reaction in bulk sample. Siltstone (3360' - 3405') = dark gray to medium dark gray with olive gray hues colors; crumbly to brittle tenacity; slightly hackly to drusy fracture; tabular to elongated cutting habits; frosted luster; matte to silty texture; thin bedding structure; no odor in bulk sample; 1% visual fluorescence yellowish green color; no HCl reaction in bulk sample. 2N-319A 9 Claystone (3415' - 3470') = medium dark gray to dark gray with slight light olive hues colors; mushy to clotted consistency; malleable to pulverulent tenacity; irregular to earthy fracture; massive to rounded cutting habits; waxy earthy luster when wet; clayey to slight smooth texture with occasional silty texture; massive to thick bedding structure; no hydrocarbon odor; 1% trace yellowish green fluorescence color; no HCl reaction in bulk sample. Claystone (3480' - 3535') = medium dark gray to dark gray with slight light olive hues colors; pasty to clotted consistency; malleable to pulverulent tenacity; irregular to earthy fracture; massive to rounded cutting habits; waxy earthy luster when wet; clayey to slight smooth texture with occasional silty texture; massive to thick bedding structure; no hydrocarbon odor; 1% trace yellowish green fluorescence color; very weak HCl reaction in bulk sample. Siltstone (3545' - 3590') = dark gray to medium dark gray with olive gray hues colors; crumbly to brittle tenacity; slightly hackly to drusy fracture; tabular to elongated cutting habits; frosted to earthy luster; matte texture; thin bedding structure; no odor in bulk sample; 1% visual fluorescence yellowish green color; weak HCl reaction in bulk sample. Siltstone (3600' - 3645') = dark gray to medium dark gray with olive gray hues colors; crunchy to stiff tenacity; slightly hackly to splintery fracture; wedgelike to elongated cutting habits; frosted to earthy luster; matte texture; thin bedding structure; no odor in bulk sample; trace visual fluorescence yellowish green color; weak HCl reaction in bulk sample. Sandstone (3655' - 3750') = olive gray to dark olive gray with translucent to clear minerals, black lithic minerals, slight greenish gray hues, and white minerals color; quartz dominant with lithic framework; very fine to fine grained; well sorted; well rounded to sub-rounded to occasionally sub-angular; predominantly unconsolidated; polished to frosted surface abrasion; often vitreous; weak to very weak to no HCl reaction; 30% dark gray to black lithic fragments; no hydrocarbon indicators. Claystone (3750' - 3810') = medium dark gray to dark gray with slight light olive hues colors; pasty to clotted consistency; malleable to pulverulent tenacity; irregular to earthy fracture; massive to rounded cuttings habit; waxy earthy luster when wet; clayey to slight smooth texture with occasional silty texture; massive to thick structure; very weak HCl reaction in bulk sample; no hydrocarbon indicators. Siltstone (3810' - 3870') = dark gray to medium dark gray with olive gray hues; crunchy to stiff tenacity; earthy to slightly hackly to splintery fracture; wedgelike to elongated cutting habits; frosted to earthy luster; matte texture; thin bedding structure; trace faint fluorescence due to trace ash in sample; weak to very weak to no HCl reaction; interbedded with sandstone and clay- stone; no hydrocarbon indicators. Claystone (3870' - 3930') = medium dark gray to dark gray with slight light olive gray hues; soft, pasty to clotted consistency; malleable to pulverulent tenacity; irregular to earthy fracture; massive to rounded cuttings habit; waxy earthy luster when wet; clayey to slight smooth texture with occasional silty texture; massive to thick structure; trace fluorescence due to ash in sample; no hydrocarbon indicators. Siltstone (3930' - 4000') = dark gray to medium dark gray with olive gray hues; crunchy to stiff tenacity; earthy to slightly hackly to splintery fracture; wedgelike to elongated cutting habits; frosted to earthy luster; matte texture; thin bedding structure; non to very slightly to slightly calcareous; inter- bedded with sandstone and claystone; no hydrocarbon indicators. Sandstone (4000' - 4070') = light olive gray to olive gray to dark gray, with scattered black lithics; quartz dominant with lithics and calcareous framework; lower fine to lower very fine grained, often grading to silt sized particles; fair to well sorted; very angular to angular to sub-angular angularity; low to moderate sphericity; consolidated to friable hardness; matrix to cement grain support; thin bedding structure; often inter-beds with siltstone, clay; frosted to grinding surface abrasion; weak HCl reaction on sandstone; no hydrocarbon indicators in bulk sample. 2N-319A 10 Claystone (4070' - 4130') = medium dark gray to dark gray with occasionally light olive gray; soft, pasty to clotted consistency; malleable to pulverulent tenacity; irregular to earthy fracture; massive to rounded cuttings habit; waxy earthy luster when wet; clayey to slight smooth texture, occasionally silty; massive to thick structure; often interbedded with sandstone and siltstone; no hydrocarbon indicators. Siltstone (4130' - 4180') = dark gray to medium dark gray with olive gray color; crunchy to stiff tenacity; earthy to slightly hackly to splintery fracture; wedgelike to elongated cutting habits; frosted to earthy luster; matte texture; thin bedding structure; non to very slightly to slightly calcareous; often inter-beds with sandstone and claystone; no hydrocarbon indicators. Sandstone (4180' - 4260') = light olive gray to olive gray to dark gray, with scattered black lithics; predominantly quartz, with scattered lithics; lower fine to lower very fine grained, often grading to silt sized particles; fair to well sorted; very angular to angular to sub-angular; low to moderate sphericity; consolidated to friable; matrix to cement grain support; thin bedding structure; often interbedded with shale, siltstone and claystone; frosted to grinding surface abrasion; no reaction to very weak HCl reaction on sandstone; no hydrocarbon indicators. Claystone (4260' - 4320') = medium dark gray to dark gray with occasionally light olive gray; soft, pasty to clotted consistency; malleable to pulverulent tenacity; irregular to earthy fracture; massive to rounded cuttings habit; waxy earthy luster when wet; clayey to slight smooth texture, occasionally silty; massive to thick structure; often interbedded with sandstone and silt- stone; often hardening to a medium dark gray shale; no hydrocarbon indicators. Sandstone (4320' - 4440') = light olive gray to olive gray to dark gray, with scattered black lithics; predominantly quartz, with scattered lithics; lower fine to lower very fine grained, often grading to silt sized particles; fair to well sorted; very angular to angular to sub-angular; low to moderate sphericity; consolidated to friable; matrix to cement grain support; thin bedding; often interbedded with siltstone, shale, and claystone; frosted to grinding surface abrasion; no reaction to very weak HCl reaction; trace white ash; no hydrocarbon indicators in bulk sample. 3.2.4 C-50 4,467’ to 4,814' MD (-3,644' to -3,863' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 181 25 117 42 4 15 Siltstone (4540' - 4590') = dark gray to medium dark gray color; crunchy to stiff tenacity; earthy to splintery fracture; wedgelike to flattened cuttings frosted to earthy luster; matte texture; thin bedding structure; non to very slightly calcareous; often interbedded with sandstone and claystone; trace carbonate and biotite euhedra present no hydrocarbon indicators. Claystone (4590' - 4650') = medium dark gray to dark gray; soft, clotted and pasty consistency; malleable to pulverulent tenacity; irregular to earthy fracture; massive clay with bladed shale cuttings; earthy luster when wet; clayey to smooth texture, occasionally silty; massive to thick structure; often interbedded with siltstone and shale; no hydrocarbon indicators. Sandstone (4650' - 4700') = medium gray very fine grained, well sorted, clast supported, rounded, moderately spherical grains of quartz and carbonate; loose rounded grains of carbonate and quartz present in trace amounts; sand is dull to earthy in luster; sandstone cuttings are massive, while minor siltstone cuttings are plated to bladed; claystone is in minor amounts, has a malleable tenacity; no indicators of hydrocarbons present. 2N-319A 11 Siltstone (4700' - 4775') = gray colored siltstone interbedded with ash fall tuff and very fine sandstone; siltstone has a stiff consistency; brittle; planar and sometimes earthy fracture; cuttings are flaky and sometimes platy/bladed; luster is vitreous when wet, and frosted when dry; has a silty texture; structure is a very thin laminae; minor amounts of pale crystal lithic ash fall tuff found in sample; has weak reaction to HCl; no indicators of hydrocarbons present. Siltstone (4775' - 4835') = gray colored siltstone interbedded with sandstone and claystone; consistency and tenacity are stiff; displays a planar fracture; cuttings are flaky or elongated or platy luster is vitreous when wet, and frosted when dry; has a silty texture; structure is a very thin laminae; trace amounts of calcite are loose in the sample; weak reaction to hydrochloric acid present; no indicators of hydrocarbons present. 3.2.5 C-40 4,814’ to 5,116' MD (-3,863' to -4,047' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 147 15 106 40 6 27 Siltstone (4835' - 4885') = gray colored siltstone interbedded with claystone; has a stiff tenacity, stiff consistency, planar fracture, flaky or elongated cuttings, vitreous to frosted luster, has a silty texture, and thin laminae; trace amounts of green altered ash is present; weak reaction to HCl visible; no indicators of hydrocarbons present. Siltstone (4885' - 4960') = dark gray siltstone interbedded with claystone, loose sand, and shale; brittle tenacity, stiff consistency, planar fracture, cuttings are flaky/planar or elongated, luster is vitreous or frosted, silty texture, and thinly laminated; loose in situ calcite is scattered throughout sample, and trace amounts of biotite and pyrite are present in the siltstone; very weak reaction to HCl, no hydrocarbon indicators. Claystone (4960' - 5010') = medium dark gray to dark gray; soft, clotted and pasty consistency; malleable to pulverulent tenacity; irregular to earthy fracture; massive cuttings habit; earthy luster; silty to clayey to smooth texture, occasionally gritty; very massive to thick structure; often interbedded with siltstone, shale, and sandstone; strong reaction to hydrochloric acid; no hydrocarbon indicators. Shale (5010' - 5080') = dark gray to grayish black; stiff consistency; tough, dense to brittle tenacity; splintery to irregular fracture; wedgelike to elongated to flaky cuttings habit; waxy to earthy luster; smooth to silty to gritty texture; often interbedded with and grading to siltstone; thin beds interbedded with claystone and sand- stone; strong reaction to hydrochloric acid; no hydrocarbon indicators. 3.2.6 C-37 5,116’ to 5,411' MD (-4,047' to -4,226' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 155 14 90 64 6 27 Siltstone (5080' - 5140') = dark gray siltstone interbedded with claystone, loose sand, and shale; brittle tenacity; stiff consistency; planar fracture; flaky/planar or elongated cuttings; vitreous or frosted luster; silty text; thinly laminated; loose in situ calcite is scattered throughout sample; moderate reaction to HCl, no hydrocarbon indicators in bulk sample. 2N-319A 12 Sandstone (5140' - 5210') = medium gray; very fine grained; well sorted; clast supported; rounded; moderately spherical grains of quartz and carbonate; loose rounded grains of carbonate and quartz present in trace amounts; sand is dull to earthy in luster; sandstone cuttings are massive, while minor siltstone cuttings are plated to bladed; claystone is in minor amounts, has a malleable tenacity; no indicators of hydrocarbons present. Shale (5210' - 5280') = dark gray to grayish black; stiff consistency; tough, dense to brittle tenacity; splintery to irregular fracture; wedgelike to elongated to flaky cuttings; waxy to earthy luster; smooth to silty to gritty texture; often interbedded with and grading to siltstone; thin beds inter- bedded with claystone and sandstone; weak reaction to hydrochloric acid; no hydrocarbon indicators. Claystone (5280' - 5350') = olive gray to light olive gray with dark gray hues, and grayish black hues; adhesive clay properties; clumpy to mushy consistency; malleable to pulverulent tenacity; earthy to irregular fracture; rounded to nodular cutting habit; dull to earthy luster when dry and waxy luster when wet; smooth to clayey texture; thin to soft sediment deformation bedding structure; trace 1% yellowish green fluorescence visual color; no hydro- carbon odor; no other hydrocarbon indictors; weak to slight moderate HCl reaction in bulk sample. Siltstone (5360' - 5425') = dark gray to grayish black colors; brittle to crunchy with occasional dense tenacity; hackly to earthy fracture; platy to tabular cutting habits; frosted to earthy luster; matte to silty texture; thick to massive bedding structure; slight hydro- carbon odor in sample; yellowish green in visual fluorescence; bright yellowish white fluorescence cut color; no white streamers; bright white yellowish residual fluorescence cut color; no residual visual colors; moderate HCl reaction in sample. 3.2.7 Iceberg 5,411’ to 6,054' MD (-4,226' to -4,623' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 184 3 102 73 6 22 Shale (5435' - 5485') = black to grayish black color; dense to stiff tenacity; hackly to splintery fracture; wedgelike to platy cutting habits; polished to sparkling when wet luster; smooth to matte texture; lenticular to thick shale bedding structure; trace yellowish green fluorescence color; no hydro- carbon odor in sample; no other hydro- carbon indictors; moderate HCl reaction in bulk sample. Sandstone (5495' - 5580') = clear to translucent with white minerals, black lithics, slight light olive hues, brown to dark brown hues color; quartz dominant with lithics framework; very fine to fine grain size; very well to well sorting; angular to subangular angularity; low to very low sphericity; consolidated to easily friable hardness; calcite to overgrowth cement; matrix to cement grain support; thin to thick bedding structure; trace pyrite inter- bedded; no hydrocarbon odor; trace yellowish greenish fluorescence visual color; no fluorescence cut color; no residual cut colors; no visual residual color; weak to moderate HCl reaction in bulk sample. Sand (5590' - 5665') = clear to translucent with white minerals, black lithics, slight light olive hues, green to greenish brown hues color; quartz dominant with lithics framework; very fine to fine grain size; very well to well sorting; angular to subangular angularity; low to very low sphericity; unconsolidated to very hard hardness; massive bedding structure; trace pyrite inter- bedded; no hydrocarbon odor; trace yellowish greenish fluorescence visual color; no fluorescence cut color; no residual cut colors; no visual residual color; weak to moderate HCl reaction in bulk sample. Siltstone (5675' - 5735') = dark gray to grayish black colors; brittle to crunchy with occasional stiff tenacity; hackly to earthy fracture; flaky to tabular cutting habits; frosted to earthy luster; matte to silty texture; thin to lenticular bedding structure; slight hydro- carbon odor in sample; trace 1% yellowish green visual 2N-319A 13 fluorescence color; no fluorescence cut color; no residual cut colors; no visual residual color; weak to moderate HCl reaction in bulk sample. Sand (5745' - 5820') = clear to translucent with white minerals, black lithics, slight light olive hues, green to greenish blue hues color; quartz dominant with lithics framework; very fine to fine grain size; very well to well sorting; angular to subangular angularity; low to very low sphericity; unconsolidated to very hard hardness; thin bedding structure; trace pyrite inter- bedded; no hydrocarbon odor; trace yellowish greenish fluorescence visual color; no fluorescence cut color; no residual cut colors; no visual residual color; weak to moderate HCl reaction in bulk sample. Shale (5830' - 5880') = black to grayish black color; dense to stiff tenacity; hackly to splintery fracture; wedgelike to platy cutting habits; polished to sparkling when wet luster; smooth to texture; lenticular to thin shale bedding structure; trace yellowish green fluorescence color; no hydro- carbon odor in sample; no other hydro- carbon indictors; weak HCl reaction in bulk sample. Siltstone (5890' - 5950') = dark gray to grayish black colors; crumbly to crunchy with occasional stiff tenacity; hackly to earthy fracture; flaky to tabular cutting habits; frosted to earthy luster; matte to silty texture; thin to lenticular bedding structure; slight hydro- carbon odor in sample; trace yellowish green visual fluorescence color; no fluorescence cut color; no residual cut colors; no visual residual color; weak to moderate HCl reaction in bulk sample. Sandstone (5960' - 6045') = clear to translucent with white minerals, black lithics, slight light olive hues, brown to dark green hues color; quartz dominant with lithics framework; very fine to fine grain size; very well to well sorting; angular to subangular angularity; low to very low sphericity; consolidated to friable hardness; calcite to overgrowth cement; matrix to cement grain support; thin to thick bedding structure; trace pyrite inter- bedded; no hydrocarbon odor; trace yellowish orange fluorescence visual color; no fluorescence cut color; no residual cut colors; no visual residual color; weak to moderate HCl reaction in bulk sample 3.2.8 T-7 6,054’ to 6,450' MD (-4,623' to -4,871' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 157 16 84 94 8 19 Siltstone (6055' - 6160') = dark gray to gray with occasional slight light olive gray; brittle to crumbly tenacity, occasionally dense; earthy to irregular to hackly fracture; elongated to wedgelike with bladed edges cuttings habit; frosted to earthy luster; matte to silty texture; thin to lenticular bedding structure; rare trace yellowish green visual fluorescence color; no fluorescence cut color; no residual cut colors; no visual residual color; weak to moderate HCl reaction in bulk sample. Shale (6160' - 6230') = gray to bluish shale interbedded with light gray silt- stone, pale sandstone, and white clay; brittle tenacity; planar fracture; cuttings are platy or elongated; frosted or sparkly luster; silty texture; thinly laminated; trace amounts of carbonate, pyrite, and ash are present; has a weak reaction to hydrochloric acid; no sample fluorescence or other oil indicators. Shale (6230' - 6280') = light to dark gray shale interbedded with fine to very fine turbidite sandstone; brittle tenacity; planar fracture; platy, flaky or elongated cuttings; vitreous to frosted luster; silty texture; thin lamination; trace amounts of ash present; no sample fluorescence or other oil indicators. Sandstone (6280' - 6340') = light gray to dark gray with bluish hues; fine to very fine grains of quartz, carbonate, biotite, and lithics; well sorted; well rounded; highly spherical; select cuttings show density modified flow with rip up clasts elongated along foliation; trace pyrite occurs with carbonate sand; weak 2N-319A 14 reaction to hydrochloric acid with exception to carbonate cuttings; trace to 5% light yellow sample fluorescence; no cut or residual fluorescence. Sandstone (6330' - 6440') = dark to med gray sandstone and bluish gray shale; sandstone has grains of quartz, biotite, lithics, and minor carbonate; grains are fine to very fine, well sorted, clast supported, and moderately spherical; shale is stiff; brittle; planar; with platy, bladed or elongated cuttings; silty texture; thin laminated structure; trace pyrite with carbonate present; little reaction to hydrochloric acid; 5% light yellow sample fluorescence; very faint milky yellow cut fluorescence, no residual fluorescence. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 6,294 94 22818 1275 584 138 292 0 0 3.2.9 T-4.1 6,450’ to 6,765' MD (-4,871' to -5,069' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 159 1.2 42.8 20 18 18 Siltstone (6500' - 6580') = dark gray to gray with occasional slight light olive gray; brittle to crumbly tenacity, occasionally dense; earthy to irregular to hackly fracture; elongated to wedge- like with bladed edges cuttings habit; frosted to earthy luster; matte to silty texture; thin to lenticular bedding; little reaction to hydrochloric acid; 5% to 10% light yellow sample fluorescence; faint milky yellow cut fluorescence, very slow streaming crush cut; very faint milky-yellow residual fluorescence. Sand (6580' - 6620') = dark yellow brown; quartz, black lithics; lower medium to lower fine grained; well sorted; subrounded; moderate sphericity; clay matrix; massive bedding; slight HCl reaction; no mineral fluorescence, no visible cut, slow dull yellow fluorescence, dull yellow residual fluorescence, no visible residue. Sand (6620' - 6660') = dark yellow brown; quartz, black lithics; lower medium to lower fine grained; well sorted; subangular to subrounded; moderate to high sphericity; clay matrix; massive bedding; slight HCl reaction; no mineral fluorescence, no visible cut, slow dull yellow fluorescence, dull blue-white residual fluorescence, no visible residue. Sand, Siltstone (6660' - 6750') = dusky brown; quartz, black lithics; upper fine to lower very fine grained; well sorted; subangular to subrounded; high sphericity; 30% indurated siltstone; unconsolidated; moderate HCl reaction; no mineral fluorescence, no visible cut, slow dull yellow fluorescence, pale blue residual fluorescence, no visible residue. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 6,512 46 11333 535 328 48 110 0 0 3.2.10 Bermuda Sand 6,765’ to 6,997MD (-5,869' to -5,221' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 132 0.7 41.4 2275 9 1013 2N-319A 15 Sand, Siltstone (6750' - 6820') = dusky brown; quartz, black lithics; upper fine to lower very fine grained; well sorted; subangular to subrounded; high sphericity; unconsolidated; 30% indurated siltstone; moderate HCl reaction; no mineral fluorescence, no visible cut, slow dull yellow fluorescence, dull blue-white residual fluorescence, no visible residue. Sand, Siltstone (6820' - 6870') = dark gray; quartz, black lithics; upper fine to lower very fine grained; well sorted; subangular to subrounded; high sphericity; 60% indurated sandstone, 10% siltstone; no HCl reaction; 50% yellow mineral fluorescence, no visible cut, weak to moderate blue-white residual fluorescence, no visible residue. Sandstone (6870' - 6910') = dark gray; quartz, pyroxene; lower fine to very fine grained; well sorted; subangular to subrounded; moderate sphericity; silica cement; trace siltstone; no HCl reaction; 90% yellow mineral fluorescence, light brown visible cut, slow strong blue-white fluorescence, strong blue-white residual fluorescence, light brown visible residue. Sandstone (6910' - 6960') = light to dark gray with scattered black lithics; lower fine to very fine grained; well sorted; subangular to subrounded; moderate sphericity; silica cement; trace siltstone; no HCl reaction; 95% yellow mineral fluorescence, milky white flash cut, bright yellow slow streaming cut, strong blue-white residual fluorescence, blue-white visible residue; oil seen on shakers; oil sheen observed when cleaning samples; petroleum odor at shakers; samples have petroleum odor; oil staining seen; amber visible cut. Sandstone (6960' - 7020') = light to dark gray with scattered black lithics; lower fine to very fine grained; well sorted; subangular to subrounded; moderate sphericity; silica cement; trace to 10% siltstone; no HCl reaction; bright yellow mineral fluorescence, milky white flash cut, bright yellow slow streaming cut, strong blue-white residual fluorescence, blue-white visible residue; oil seen on shakers; oil sheen observed when cleaning samples; petroleum odor at shakers; samples have petroleum odor; oil staining seen; very slight amber visible cut. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 6822 303 64887 5626 4871 706 1567 191 143 6,849 1,371 280580 25518 23495 3286 7678 1591 1937 6,879 1,702 175201 20221 22873 4006 10134 2623 3335 6,939 2,196 212958 29656 38092 6592 16562 4329 5489 6,996 2,222 232155 26701 33294 5761 14314 3692 4598 2N-319A 16 3.2.11 Base Bermuda 6,997’ to 7,051' MD (-5,221' to -5,256' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 69 1.3 26.5 103 68 85 Sandstone (7040' - 7060') = medium dark gray; quartz, pyroxene; trace mica and ooids; very fine grained; well sorted; subangular; low to moderate sphericity; silica cement; 30% unconsolidated sand, 10% siltstone; very slight HCl reaction; 50% yellow mineral fluorescence; very light brown visible cut; very slow strong blue-white fluorescence; strong blue-white residual fluorescence; very light brown residue; sample oil odor and stain. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 7,012 2,777 313972 35779 41346 6658 16625 4290 5195 7,034 3,087 443997 44179 49344 8292 21230 5514 6915 7,048 3,032 430206 42726 48980 8267 21306 5601 7049 3.2.12 Top Purple 7,051’ to 7,131' MD (-5,256' to -5,309' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 154 1.0 34.7 103 68 85 Sand, Sandstone (7060' - 7100') = medium dark gray; quartz, pyroxene; trace mica; very fine grains; well sorted; subangular; mod sphericity; silica cement; 50% unconsolidated sand, 10% siltstone; very slight HCl reaction; 30% yellow mineral fluorescence; no visible cut; weak blue-white crush fluorescence; weak blue-white residual fluorescence; no residue; slight sample oil odor and stain. Sand, Sandstone (7120' - 7140') = medium dark gray; quartz, pyroxene; trace mica; very fine grains; well sorted; subangular; moderate sphericity; silica cement; 40% unconsolidated sand, 10% siltstone; very slight HCl reaction; 10% yellow mineral fluorescence; no visible cut; weak blue- white fluorescence; weak blue-white residual fluorescence; no residue; very slight sample oil odor and stain. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 7,059 1,989 281060 27871 32610 5523 14304 3794 4787 7,070 2,088 269666 27762 33480 5869 15317 4183 5321 7,102 2,147 165499 20199 28314 6260 17568 5995 6809 2N-319A 17 3.2.13 Base Purple 7,131’ to 7,170' MD (-5,309' to -5,335' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 44 4 29.1 103 68 85 Sand, Siltstone (7140' - 7180') = medium dark gray; quartz, pyroxene; trace mica; very fine grains; well sorted; subangular; moderate sphericity; 30% unconsolidated sand, 30% sandstone; very slight HCl reaction; 40% yellow mineral fluorescence; light brown visible cut; moderate blue-white fluorescence; moderate blue-white residual fluorescence; very light brown residue; sample oil odor and stain. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 7,147 1,576 91715 14236 23571 5823 16995 6156 5722 7,185 888 52875 8791 14806 3265 9310 3006 2200 3.2.14 C-35 to TD 7,170’ to 7,300' MD (-5,335' to -5,427' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 56 6 33.3 103 68 85 Sand, Siltstone (7180' - 7250') = medium dark gray; quartz, pyroxene; trace mica; trace pyrite; very fine to fine grains; well sorted; subangular to angular; moderate sphere; 30% unconsolidated sand, 30% sandstone; very slight HCl reaction; 60% yellow mineral fluorescence; very light brown visible cut; moderate blue-white fluorescence; very slow yellow streaming cut; moderate blue-white residual fluorescence; very light brown residue; sample oil odor and stain; odor at shakers; interbedded with shale, increasing with depth. Sand, Siltstone (7250' - 7300') = medium dark gray; quartz, pyroxene; trace mica; trace pyrite; very fine to fine grains to silt; well sorted; subangular to angular; moderate sphere; 30% unconsolidated sand, 30% sandstone; very slight HCl reaction; 60% yellow mineral fluorescence; light brown cut; moderate blue- white fluorescence; no streaming cut; moderate blue-white residual fluorescence; very light brown residue; sample oil odor and stain; odor at shakers; interbedded with shale. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 7,222 4,612 270932 39817 62821 13195 37195 11598 10360 7,257 3,090 445662 45623 50177 7868 19945 5025 6401 7,286 1,555 72249 13409 22597 4841 13586 4229 4016 2N-319A 18 3.3 Isotube Summary Isotube Depth Box Sample MD ft TVD ft Gas units Methane ppm Ethane ppm Propane ppm Iso Butane ppm Normal Butane ppm Iso Pentane ppm Normal Pentane ppm 1 1 3,000 2,720.42 11 2575 1 2 3,529 3,099.97 6 835 1 3 4,000 3,456.90 33 5700 1 4 4,500 3,814.17 9 2746 1 5 5,000 4,126.35 20 4821 146 1 6 5,500 4,429.08 20 4396 266 91 1 7 6,000 4,740.26 13 3578 174 72 1 8 6,500 5,050.34 24 6282 302 185 1 9 6,610 5,112.59 1 344 19 1 10 6,640 5,137.06 1 255 14 1 11 6,670 5,155.52 1 288 16 1 12 6,700 5,173.91 1 521 28 1 13 6,730 5,192.22 2 481 19 1 14 6,760 5,215.55 6 762 26 1 15 6,790 5,234.92 54 6448 540 446 55 116 1 16 6,811 5,248.49 192 6094 483 396 48 80 1 17 6,820 5,254.33 276 57109 4935 4252 619 1367 157 108 1 18 6,850 5,273.80 1,021 141947 12934 11934 1667 3903 820 1007 1 19 6,880 5,293.27 1,378 142397 16411 18578 3257 8240 2136 2718 1 20 6,910 5,312.78 1,539 159713 17604 20427 3673 9362 2539 3308 1 21 6,940 5,332.38 2,094 183674 26358 34118 5874 14731 3825 4829 1 22 6,970 5,351.97 1,525 165838 19573 23403 4019 10117 2722 2319 1 23 7,000 5,371.56 2,442 271036 29913 36591 6264 15438 3835 4754 1 24 7,030 5,391.13 1,946 228311 22731 25199 4230 10808 2798 3505 1 25 7,060 5,410.57 874 202417 20071 23527 3987 10328 2742 3461 2 1 7,090 5,430.00 1,673 151347 16868 21472 3997 10553 3013 3880 2 2 7,120 5,449.43 861 49445 7272 11867 3204 9499 3694 3845 2 3 7,150 5,468.87 818 47680 7443 12343 3021 8800 3161 2895 2 3 7,180 5,488.30 798 47363 7808 13122 2935 8396 2756 2098 2 5 7,210 5,507.73 651 31146 5297 9177 1984 5746 1832 2507 2 6 7,240 5,527.17 526 15372 3871 7845 1845 5330 883 1229 2 7 7,270 5,546.60 759 29787 6179 10978 2470 6950 2169 2942 2 8 7,300 5,566.03 817 35224 6868 11971 2638 7416 2376 3165 2N-319A 19 3.4 Sampling Program / Sample Dispatch Set Type / Purpose Well Section Sampling Frequency Sampling Interval* Dispatched to A1 & B1 Washed, screened & dried Reference Samples Set owner: CPAI Sidetrack 50’ 2,450’ – 4,550’ Alaska Archives 1300 W. 56th Avenue Unit 14 Anchorage, AK 99518 Attn: D. Przywojski 265-6340 A2 & B2 Washed, screened & dried Reference Samples Set owner: CPAI Sidetrack 50’ 4,550’ – 6,580’ Alaska Archives 1300 W. 56th Avenue Unit 14 Anchorage, AK 99518 Attn: D. Przywojski 265-6340 A3 & B3 Washed, screened & dried Reference Samples Set owner: CPAI Sidetrack 20’ 6,580’ – 7,300’ Alaska Archives 1300 W. 56th Avenue Unit 14 Anchorage, AK 99518 Attn: D. Przywojski 265-6340 C IsoTube Gas Samples Set owner: CPAI Sidetrack 500’ 30’ 3,000’ – 6,500’ 6,610’ – 7,060’ Isotech Laboratories 1308 Parkland Court Champaign, IL 61821 (217) 398-3490 D IsoTube Gas Samples Set owner: CPAI Sidetrack 30’ 7,090’ – 7,300’ Isotech Laboratories 1308 Parkland Court Champaign, IL 61821 (217) 398-3490 Note: Sample frequency was locally altered according to drill rate constraints and zones of interest. 2N - 3 1 9 A 20 4 P R E S S U R E / F O R M A T I O N S T R E N G T H D A T A Th e w e l l w a s d r i l l e d s l i g h t l y o v e r b a l a n c e d a s w a s i n d i c a t ed b y n o c o n n e c t i o n g a s s e s a n d l o w t r i p a n d w i p e r g a s s e s . 4. 1 P o r e P r e s s u r e E v a l u a t i o n In t e r v a l T o p s P o r e P r e s s u r e ( M W ) Fo r m a t i o n In t e r v a l Pr i m a r y Li t h o l o g y (% ) Se c o n d a r y Li t h o l o g y (% ) MD (f t ) TV D S S (f t ) Mi n (p p g ) Ma x (p p g ) Tr e n d Trend Indicators C- 8 0 C L Y S T 9 0 % S D 5 % S L T 5 % 2 , 6 6 2 ’ - 2 , 3 2 6 ’ 9 . 9 5 1 0 . 9 6 E v e n B G , C G , M W Ca m p a n i a n S a n d S N D 5 0 % CL Y S T 2 0 % S L T 30 % 2, 7 3 9 ’ - 2 , 3 8 0 ’ 9 . 8 9 1 1 . 1 2 E v e n B G , C G , M W C- 5 0 C L S T 5 0 % S D 3 0 S L T 2 0 % 4 , 4 6 7 ’ - 3 , 6 4 4 ’ 1 0 . 0 4 1 2 . 0 9 E v e n B G , C G , M W C- 4 0 S L T 2 5 % SH 1 5 % S D 2 0 % SS T 1 5 % C L Y S T 25 % 4, 8 1 4 ’ - 3 , 8 6 3 ’ 1 0 . 4 1 1 2 . 9 7 E v e n B G , C G , M W C- 3 7 S L T 4 0 % SS T 2 0 % S D 2 0 % SH 2 0 5, 1 1 6 ’ - 4 , 0 4 7 ’ 1 0 . 3 3 1 0 . 9 3 E v e n B G , C G , M W Ic e b e r g S D 3 0 % SS T 2 0 % S L T S T 35 % C L Y S T 1 5 % 5, 4 1 1 ’ - 4 , 2 2 6 ’ 1 0 . 3 2 1 0 . 8 4 E v e n B G , C G , M W T- 7 S L T S T 6 0 % CL Y S T 1 0 % S D S T 15 % S D 1 5 % 6, 0 5 4 ’ - 4 , 6 2 3 ’ 1 0 . 4 7 1 0 . 9 8 E v e n B G , C G , M W T- 4 . 1 S L T S T 6 0 % SS T 3 0 % S N 5 % CL Y S T 5 % 6, 4 5 0 ’ - 4 , 8 7 1 ’ 9 . 9 9 1 0 . 8 5 E v e n B G , C G , M W To p B e r m u d a S S T 8 0 % S L S T 1 0 % S N t r a c e 6 , 76 5 ’ - 5 , 0 6 9 ’ 1 0 . 2 5 1 3 . 4 1 I n c r e a s i n g B G , C G , M W Ba s e B e r m u d a S S T 8 0 % S L S T 1 0 % S N t r a c e 6 , 99 7 ’ - 5 , 2 2 1 ’ 1 2 . 7 2 1 4 . 2 3 I n c r e a s i n g B G , C G , M W To p P u r p l e S D 4 0 % SS T 4 0 % S L S T 1 5 % CL Y S T 5 % 7, 0 5 1 ’ - 5 , 2 5 6 ’ 1 1 . 3 2 1 3 . 8 6 E v e n B G , C G , M W Ba s e P u r p l e S S 5 0 % SD 2 0 % S L T S T 1 0 % SH 2 0 % 7, 1 3 1 ’ - 5 , 3 0 9 ’ 1 1 . 9 9 1 3 . 4 6 E v e n B G , C G , M W C- 3 5 S S T 4 0 % S D 3 0 % S L T S T 3 0 % 7 , 1 7 0 ’ -5 , 3 3 5 ’ 1 1 . 5 8 1 5 . 9 6 I n c r e a s i n g B G , C G , M W NO T E : C l y s t = C l a y s t o n e / C l a y , S d = S a n d , S l t s t = S i l t s t o n e , S h = S h a l e , S s t = S a n d s t o n e , A s h = A s h F a l l T u f f , C S l t s t = C a r b o n a c eous Siltstone 2N-319A 21 4.2 Pore Pressure Plot Pore Pressure Gradient C-80 Campanian Sand C-50 C-40 C-37 Iceberg T-7 T-4.1 Top Bermuda Base Bermuda C-35 2500 3500 4500 5500 6500 7500 9 . 5 1 01 0 . 51 11 1 . 51 21 2 . 51 31 3 . 51 41 4 . 5 Pore Pressue (ppg) Me a s u r e d D e p t h ( f t ) PPG C-80 Campanian Sand C-50 C-40 C-37 Iceberg T-7 T-4.1 Top Bermuda Base Bermuda C-35 2N-319A 22 4.3 Quantitative Methods The primary indicators used for PPG evaluation were gas trends relative to mud weight (MW) and effective circulating density (ECD), including increases in background gas (BG), appearance and trends of connection gas (CG), and magnitudes of trip gas (TG) and wiper gas (WG). Regional pore pressure trends from sonic data, provided by ConocoPhillips, and surface manifestations of hole conditions were also considered. As a reference, PPG is calculated initially with a formula provided by Canrig Drilling Technology LTD, and then modified using the indicators described above, DXC and resistivity (RES) data. The formula uses DX, ECD, and BG as measured by total ditch gas: PPG = ECD – (0.6-((.001*TLGSU) + (0.05*DX))) The formula has certain limitations, such that it does not allow for a PPG more than 1 ppg less than the ECD, and TLGSU must be differentiated from show gas and gas carried from over pressure zones, and is dependent on reliable DX data. However, the formula proved useful in helping formulate a PPG range, when estimating trends, as with DXC data, with data points in shale intervals. 2N-319A 23 5 DRILLING DATA 5.1 Survey Data Surveys to 2,417.72’ MD in original wellbore. Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Vertical Section (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Dogleg Rate (o/100ft) 17.72 0.66 92.57 — — — — — 42.72 1.11 126.60 — — — — — 67.72 0.44 184.62 — — — — — 92.72 0.62 176.63 — — — — — 117.72 0.09 333.44 — — — — — 142.72 0.47 224.04 — — — — — 167.72 0.41 179.52 — — — — — 192.72 0.52 173.63 — — — — — 217.72 0.52 227.82 — — — — — 242.72 0.70 175.35 — — — — — 267.72 0.65 186.45 — — — — — 292.72 0.56 183.82 — — — — — 317.72 0.78 200.71 — — — — — 342.72 0.49 166.95 — — — — — 367.72 0.83 187.73 — — — — — 392.72 0.75 207.38 — — — — — 417.72 0.76 166.69 — — — — — 442.72 0.79 191.44 — — — — — 467.72 0.46 153.86 — — — — — 492.72 0.40 228.24 — — — — — 517.72 0.42 176.11 — — — — — 542.72 0.40 192.63 — — — — — 567.72 0.52 174.32 — — — — — 592.72 0.47 146.15 — — — — — 617.72 0.35 203.94 — — — — — 642.72 0.29 173.63 — — — — — 667.72 0.61 206.70 — — — — — 692.72 0.87 192.46 — — — — — 717.72 0.77 156.86 — — — — — 742.72 0.39 185.48 — — — — — 767.72 0.61 194.67 — — — — — 792.72 0.69 118.31 — — — — — 817.72 0.63 189.80 — — — — — 842.72 0.90 176.39 — — — — — 867.72 0.77 118.59 — — — — — 892.72 0.73 238.99 — — — — — 917.72 0.86 142.01 — — — — — 942.72 0.39 151.87 — — — — — 2N-319A 24 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Vertical Section (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Dogleg Rate (o/100ft) 967.72 0.45 204.90 — — — — — 992.72 0.90 276.90 — — — — — 1,017.72 1.38 278.77 — — — — — 1,042.72 1.81 296.48 — — — — — 1,067.72 2.61 296.20 — — — — — 1,092.72 3.28 299.95 — — — — — 1,117.72 3.79 298.47 — — — — — 1,142.72 4.68 303.22 — — — — — 1,167.72 5.50 300.18 — — — — — 1,192.72 6.17 299.95 — — — — — 1,217.72 6.88 302.40 — — — — — 1,242.72 7.91 299.93 — — — — — 1,267.72 8.15 305.74 — — — — — 1,292.72 9.08 302.89 — — — — — 1,317.72 9.77 302.08 — — — — — 1,342.72 10.73 304.73 — — — — — 1,367.72 11.78 301.37 — — — — — 1,392.72 12.30 305.95 — — — — — 1,417.72 13.35 304.94 — — — — — 1,442.72 14.57 305.46 — — — — — 1,467.72 15.55 305.66 — — — — — 1,492.72 16.31 305.60 — — — — — 1,517.72 17.73 306.10 — — — — — 1,542.72 18.35 306.50 — — — — — 1,567.72 18.73 306.61 — — — — — 1,592.72 19.23 307.42 — — — — — 1,617.72 20.43 307.04 — — — — — 1,642.72 21.01 307.93 — — — — — 1,667.72 21.23 307.55 — — — — — 1,692.72 21.86 307.83 — — — — — 1,717.72 22.88 308.25 — — — — — 1,742.72 23.51 306.79 — — — — — 1,767.72 24.14 308.86 — — — — — 1,792.72 24.50 307.25 — — — — — 1,817.72 25.40 307.91 — — — — — 1,842.72 26.37 306.60 — — — — — 1,867.72 26.52 308.78 — — — — — 1,892.72 27.89 307.93 — — — — — 1,917.72 28.65 309.20 — — — — — 1,942.72 28.91 307.94 — — — — — 1,967.72 29.59 309.14 — — — — — 1,992.72 30.37 307.90 — — — — — 2,017.72 30.83 307.51 — — — — — 2N-319A 25 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Vertical Section (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Dogleg Rate (o/100ft) 2,042.72 31.36 307.93 — — — — — 2,067.72 31.59 307.79 — — — — — 2,092.72 32.50 307.79 — — — — — 2,117.72 32.72 306.45 — — — — — 2,142.72 32.97 308.12 — — — — — 2,167.72 33.40 307.39 — — — — — 2,192.72 34.65 307.09 — — — — — 2,217.72 35.44 307.47 — — — — — 2,242.72 35.78 306.92 — — — — — 2,267.72 36.77 307.13 — — — — — 2,292.72 37.62 306.28 — — — — — 2,317.72 37.61 307.14 — — — — — 2,342.72 38.31 306.06 — — — — — 2,367.72 39.45 306.22 — — — — — 2,392.72 40.41 306.15 — — — — — 2,417.72 40.85 305.95 — — — — — 2,442.72 39.83 306.43 2,310.01 291.86 307.12 -422.37 0.00 2,483.92 40.01 303.00 2,341.61 307.13 322.17 -444.10 5.36 2,579.07 41.45 297.00 2,413.74 347.03 353.14 -497.83 4.38 2,673.44 44.56 292.11 2,482.77 392.92 379.80 -556.37 4.83 2,768.28 45.12 288.93 2,550.02 443.75 403.22 -618.99 2.44 2,864.15 42.66 286.33 2,619.11 496.35 423.38 -682.30 3.18 2,958.74 40.59 283.92 2,689.82 547.71 439.80 -742.94 2.77 3,054.33 42.75 284.35 2,761.22 600.31 455.32 -804.56 2.28 3,149.40 44.33 285.04 2,830.14 654.15 471.94 -867.90 1.74 3,244.64 45.59 281.29 2,897.54 710.48 487.24 -933.41 3.08 3,340.91 45.53 277.67 2,964.95 770.29 498.56 -1,001.19 2.69 3,435.78 43.95 275.97 3,032.34 829.87 506.50 -1,067.48 2.09 3,530.46 42.62 273.82 3,101.27 888.74 512.05 -1,132.15 2.10 3,624.75 41.56 270.89 3,171.24 947.18 514.66 -1,195.29 2.37 3,721.87 40.44 268.57 3,244.54 1,007.14 514.38 -1,258.99 1.95 3,818.07 39.43 265.05 3,318.32 1,066.22 510.96 -1,320.63 2.57 3,913.29 39.84 258.55 3,391.68 1,125.61 502.30 -1,380.67 4.37 4,009.29 42.13 254.63 3,464.16 1,188.14 487.65 -1,441.88 3.59 4,104.90 42.42 252.27 3,534.90 1,252.33 469.33 -1,503.52 1.69 4,199.90 43.09 248.43 3,604.67 1,316.79 447.64 -1,564.23 2.83 4,294.52 44.13 244.72 3,673.19 1,381.91 421.69 -1,624.08 2.92 4,389.47 46.30 241.65 3,740.08 1,448.80 391.26 -1,684.19 3.24 4,484.04 48.72 238.13 3,803.97 1,517.42 356.26 -1,744.48 3.75 4,579.61 49.32 234.78 3,866.65 1,587.54 316.39 -1,804.59 2.72 4,675.39 50.71 231.85 3,928.20 1,657.82 272.54 -1,863.41 2.76 4,769.87 52.14 228.30 3,987.13 1,727.23 225.13 -1,920.03 3.30 4,865.11 52.87 229.20 4,045.10 1,797.66 175.32 -1,976.84 1.07 2N-319A 26 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Vertical Section (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Dogleg Rate (o/100ft) 4,960.55 52.80 231.48 4,102.76 1,869.27 126.78 -2,035.38 1.91 5,054.90 52.73 233.02 4,159.85 1,940.81 80.79 -2,094.78 1.30 5,149.69 52.83 234.14 4,217.19 2,013.21 35.98 -2,155.51 0.95 5,245.11 52.70 233.91 4,274.93 2,086.25 -8.65 -2,216.99 0.24 5,340.21 52.83 230.86 4,332.48 2,158.40 -54.85 -2,276.96 2.56 5,435.21 52.83 229.57 4,389.88 2,229.63 -103.29 -2,335.13 1.08 5,530.82 52.09 231.79 4,448.14 2,301.16 -151.33 -2,393.77 2.00 5,625.38 51.84 230.09 4,506.40 2,371.55 -198.26 -2,451.59 1.44 5,721.63 51.16 230.15 4,566.32 2,442.39 -246.55 -2,509.40 0.71 5,817.21 51.31 230.55 4,626.17 2,512.57 -294.11 -2,566.78 0.36 5,911.72 51.27 230.84 4,685.27 2,582.18 -340.82 -2,623.84 0.24 6,005.75 51.21 230.84 4,744.14 2,651.44 -387.13 -2,680.70 0.06 6,102.26 51.67 230.73 4,804.30 2,722.70 -434.84 -2,739.17 0.48 6,197.51 51.73 226.84 4,863.34 2,792.36 -484.07 -2,795.38 3.21 6,292.26 51.78 225.88 4,922.00 2,860.53 -535.43 -2,849.23 0.80 6,388.36 51.76 228.82 4,981.47 2,930.18 -586.56 -2,904.74 2.40 6,483.76 51.70 230.00 5,040.56 3,000.29 -635.29 -2,961.62 0.97 6,541.73 51.79 232.12 5,076.46 3,043.35 -663.90 -2,997.02 2.88 6,615.54 50.48 234.20 5,122.77 3,098.34 -698.36 -3,043.00 2.82 6,710.28 50.07 234.23 5,183.32 3,168.46 -740.97 -3,102.11 0.43 6,805.17 49.32 231.98 5,244.71 3,237.69 -784.40 -3,159.98 1.97 6,805.17 49.33 231.95 5,244.14 3,238.75 -782.86 -3,161.66 4.79 6,899.05 48.88 227.19 5,305.62 3,305.21 -828.85 -3,215.66 3.86 6,931.91 50.19 228.14 5,326.94 3,328.34 -845.68 -3,234.14 4.55 6,962.95 49.57 228.04 5,346.95 3,350.36 -861.54 -3,251.80 2.01 7,026.45 49.32 229.28 5,388.23 3,395.30 -893.41 -3,288.03 1.54 7,119.13 48.95 227.80 5,448.87 3,460.52 -939.81 -3,340.55 1.27 7,215.23 44.99 231.26 5,515.38 3,525.00 -986.48 -3,392.18 4.84 7,258.10 43.91 231.70 5,545.98 3,553.47 -1,005.18 -3,415.67 2.62 2N - 3 1 9 A 27 5. 2 B i t R e c o r d Bi t S i z e M a k e T y p e / S N # Je t s / TF A De p t h I n MD To t a l Fo o t a g e Bi t Hr s Av g . RO P (f t / h r ) Av g . WO B (K l b s ) Av g RP M Av g PP (p s i ) Wear BHA 1 6 . 7 5 ” Ha l l i b u r t o n FX 5 5 P D C / 11 5 6 6 3 2 1 4x 1 0 / 0. 3 8 3 2, 4 4 1 ’ 4 , 1 3 9 ’ 46 . 2 5 1 0 8 . 7 5. 1 1 0 9 2, 0 1 6 2- 2 - C T - G - X - 1-WT-TD 1 — 7 . 5 ” We a t h e r f o r d Ri p t i d e Un d e r - re a m e r / 93 5 2 0 2 1 - 1 - 1 — 2, 4 4 1 ’ 4 , 1 3 9 ’ 46 . 2 5 1 0 8 . 7 5. 1 1 0 9 2, 0 1 6 1- 1 - N O - A - X - 1-RR-TD 1 2 4 . 7 5 ” Sm i t h XR 2 0 P S In s e r t / RA 4 2 6 5 1x 1 3 , 2x 1 1 / 0. 3 1 5 6, 5 8 0 ’ 7 2 0 ’ 29 . 7 5 3 2 . 1 8. 8 64 . 9 2, 8 2 5 0- 1 - N 0 - A - E - 1-NO-TD 2 2N - 3 1 9 A 28 5. 3 M u d R e c o r d Co n t r a c t o r : M I S W A C O Mu d T y p e : L S N D ( L o w S o l i d s / N o n - D i s p e r s e d ) Da t e De p t h MW (p p g ) Te m p VI S (s / q t ) PV Y P G e l s FL (c c ) FC So l s (% ) O/ W Ra t i o Sd (% ) pH Cl (ml/l) Ca (ml/l) 10 / 2 5 / 1 4 2, 8 0 0 9 . 8 8 4 — — — — — — — — — — — — 10 / 2 6 / 1 4 2, 8 0 0 9 . 8 7 5 — — — — — — — — — — — — 10 / 2 7 / 1 4 2, 8 0 0 9 . 8 6 8 — — — — — — — — — — — — 10 / 2 8 / 1 4 2, 8 0 0 9 . 8 6 4 — — — — — — — — — — — — 10 / 2 9 / 1 4 2, 8 0 0 9 . 8 6 2 — — — — — — — — — — — — 10 / 3 0 / 1 4 2, 8 0 0 1 0 . 0 7 6 4 8 1 0 1 6 6 / 7 / 8 5 1 / - 7 . 5 2 / 9 1 0 . 0 9 . 0 6 , 5 0 0 2 2 0 10 / 3 1 / 1 4 2 , 8 0 0 1 0 . 0 5 8 5 0 1 0 1 9 7 / 8 / 9 5 1 / - 7 . 5 2 / 9 1 — 8 . 8 6 , 5 0 0 2 2 0 11 / 1 / 1 4 2, 8 0 0 9 . 6 6 0 4 3 7 1 2 4 / 5 / 6 4 . 8 1 / - 6 2 / 9 2 — 9 . 4 6 , 5 0 0 2 2 0 11 / 2 / 1 4 2, 8 0 0 9 . 6 5 4 4 6 7 1 2 3 / 4 / 7 4 . 9 1 / - 6 2 / 8 2 — 9 . 2 6 , 9 0 0 2 8 0 11 / 3 / 1 4 3, 0 0 0 9 . 6 7 8 4 6 1 2 1 9 9 / 1 2 / 1 5 4 . 5 1 / - 6 2 / 9 2 — 1 0 . 2 6 , 6 0 0 1 8 0 11 / 4 / 1 4 3, 8 5 6 9 . 6 8 0 4 4 1 2 2 0 1 0 / 2 0 / 2 6 4 . 5 1 / - 6 2 / 9 2 0 . 3 9 . 5 2 , 4 0 0 1 5 8 11 / 5 / 1 4 5, 5 9 0 9 . 6 8 6 4 4 1 1 2 0 1 1 / 1 2 / 1 3 4 . 5 1 / - 6 . 5 2 / 9 1 . 5 0 . 2 5 9 . 0 2 , 4 0 0 1 0 0 11 / 6 / 1 4 6 , 5 8 0 9 . 7 9 2 4 6 1 2 1 7 8 / 9 / 1 5 4 . 5 1 / - 7 2 / 9 1 0 . 2 5 9 . 1 1 , 6 0 0 9 0 11 / 7 / 1 4 6, 5 8 0 9 . 6 — 4 6 1 1 2 2 8 / 1 0 / 1 1 4 . 5 1 / - 6 . 5 2 / 9 2 0 . 2 5 9 . 3 2 , 3 0 0 8 0 11 / 8 / 1 4 6, 5 8 0 9 . 7 — 4 9 1 0 1 7 8 / 9 / 1 0 4 . 5 1 / - 6 . 5 2 / 9 1 . 5 0 . 2 5 9 . 0 2 , 3 0 0 9 0 11 / 9 / 1 4 6, 5 8 0 9 . 8 7 6 5 0 1 1 1 6 8 / 9 / 1 0 4 . 5 1 / - 7 2 / 9 1 0 . 2 5 9 . 0 2 , 2 0 0 9 0 11 / 1 0 / 1 4 6, 5 8 0 9 . 8 — 4 9 1 1 1 6 8 / 9 / 1 0 4 . 4 1 / - 7 2 / 9 1 0 . 2 5 9 . 0 2 , 2 0 0 9 0 11 / 1 1 / 1 4 6, 5 8 0 9 . 8 — 4 9 1 1 1 6 8 / 9 / 1 0 4 . 4 1 / - 7 2 / 9 1 0 . 2 5 9 . 1 2 , 2 0 0 9 0 11 / 1 2 / 1 4 6 , 6 5 0 9 . 8 8 4 4 3 1 0 8 5 / 5 / 7 4 . 5 1 / - 7 2 / 9 1 — 1 0 . 1 2 , 1 0 0 2 0 0 11 / 1 3 / 1 4 6, 8 5 7 1 0 . 0 9 4 4 5 7 2 1 7 / 8 / 1 0 4 . 2 1 / - 8 2 / 9 0 — 8 . 9 1 , 5 0 0 8 0 11 / 1 4 / 1 4 7, 0 1 9 1 0 . 8 9 1 4 6 1 7 2 1 8 / 9 / 1 1 4 . 2 1 / - 1 0 3 / 8 7 — 9 . 3 6 5 0 7 0 11 / 1 5 / 1 4 7, 3 0 0 1 1 . 3 9 4 4 4 1 5 3 6 1 1 / 1 2 / 1 3 3 . 2 1 / - 1 2 3 / 8 5 0 . 2 5 9 . 2 7 0 0 7 0 11 / 1 6 / 1 4 7, 3 0 0 1 1 . 6 9 0 5 1 1 2 3 7 1 2 / 1 4 / 1 6 3 . 0 1 / - 1 3 . 5 4 / 8 3 0 . 2 5 9 . 5 7 0 0 6 0 11 / 1 7 / 1 4 7, 3 0 0 1 1 . 6 7 5 5 6 1 4 3 6 1 2 / 1 4 / 1 5 3 . 1 1 / - 1 2 . 5 4 / 8 2 0 . 2 5 9 . 3 7 0 0 8 0 11 / 1 8 / 1 4 7 , 3 0 0 1 1 . 6 7 5 4 9 1 2 3 8 1 1 / 1 2 / 1 6 3 . 5 1 / - 1 4 4 / 8 2 0 . 2 5 9 . 0 7 0 0 8 0 11 / 1 9 / 1 4 7, 3 0 0 1 1 . 6 1 2 0 4 2 1 4 2 0 1 0 / 1 2 / 1 4 4 . 0 1 / - 1 4 . 5 4 / 8 2 0 . 2 5 8 . 9 7 0 0 8 0 11 / 2 0 / 1 4 7, 3 0 0 1 1 . 6 — 2 8 — — — — — — — — — — — 11 / 2 1 / 1 4 7, 3 0 0 1 1 . 6 — 2 8 — — — — — — — — — — — 2N - 3 1 9 A 29 Ab b r e v i a t i o n s MW = M u d W e i g h t G e l s = G e l S t r e n g t h S d = S a n d c o n t e n t E C D = E f f e c t i v e C i r c u l a t i n g D e n s i t y WL = W a t e r o r F i l t r a t e L o s s C l = C h l o r i d e s V I S = F u n n e l V i s c o s i t y F C = F i l t e r C a k e Ca = H a r d n e s s C a l c i u m P V = P l a s t i c V i s c o s i t y S o l s = S o l i d s O / W = O i l t o W a t e r r a t i o YP = Y i e l d P o i n t 30 6 SHOW REPORTS Hydrocarbon Show Report #1 Operator: Well:API Number: Field: Date: Rig: Time: County: Depth Start End State:6,810'MD 7,051'MD Country:5,248'TVD 5,405'TVD Averages Before During After Maximum ROP (fph)26 41 33 132 WOB 10 9 10 19 RPM 51 57 81 93 Mud Weight 9.8 10.6 10.8 10.8 Chloride 650 700 700 700 Total Gas 28 1,522 1,057 3,108 C1 (ppm)3,350 183,613 79,733 443,997 C2 (ppm)258 19,005 10,485 44,179 C3 (ppm)187 21,264 15,423 49,345 C4 (ppm)69 12,706 12,401 29,632 C5 (ppm)- 5,244 5,887 12,662 Lithology Cuttings Analysis Odor Slight Fluorescence Cut Fluorescence Residual Cut Stain Amount 95%Type Immediate Amount Amount 10%Distribution Even Intensity Bright Color Color Yellow brown Intensity Strong Color Yellow Residual Fluorescence Cut Color Blue-White Intesity Color None Color Show Ratin 3 Free Oil in Mud Comments Report by: Pale Allen Odegaard / Ben Calo Free oil and slight to moderate odor reported at shakers by sample catcher. Yes Yellow North Slope Borough Alaska United States ConocoPhillips Alaska, Inc. : 50-103-20271-01-002N-319A Tarn Oil Pool Nabors 9ES November 14, 2014 5:13pm to 7:33pm Light Milky-White Sandstone = light to dark gray with scattered black lithics; lower fine to very fine grained; well sorted; subangular to subrounded; moderate sphericity; silica cement; trace to 10% siltstone; no HCl reaction; bright yellow mineral fluorescence, milky white flash cut, bright yellow slow streaming cut, strong blue- white residual fluorescence, blue-white visible residue; oil seen on shakers; oil sheen observed when cleaning samples; petroleum odor at shakers; samples have petroleum odor; oil staining seen; very slight amber visible cut. 1 10 100 1000 10000 1234 pp m DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Hydrocarbon Show Report #2 Operator: Well:API Number: Field: Date: Rig: Time: County: Depth Start End State:7,051'MD 5,405'MD Country:7,300'TVD 5,576'TVD Averages Before During After Maximum ROP (fph)41 33 154 WOB 9 10 16 RPM 57 81 93 Mud Weight 10.6 10.8 10.8 Chloride 700 700 700 Total Gas 1,522 1,057 4,613 C1 (ppm)183,613 79,733 445,662 C2 (ppm)19,005 10,485 45,624 C3 (ppm)21,264 15,423 62,821 C4 (ppm)12,706 12,401 50,391 C5 (ppm)5,244 5,887 21,959 Lithology Cuttings Analysis Odor Slight Fluorescence Cut Fluorescence Residual Cut Stain Amount 60%Type Slow Amount Amount 10%Distribution Even Intensity Bright Color Color Yellow brown Intensity Moderate Color Yellow Residual Fluorescence Cut Color Blue-White Intesity Color None Color Show Ratin 3 Free Oil in Mud Comments Report by: Sand, Sandstone = medium dark gray; quartz, pyroxene; trace mica; very fine grains; well sorted; subangular; mod sphericity; silica cement; 50% unconsolidated sand, 10% siltstone; very slight HCl reaction; 30% yellow mineral fluorescence; no visible cut; weak blue-white crush fluorescence; weak blue- white residual fluorescence; no residue; slight sample oil odor and stain. Light Milky-White North Slope Borough Alaska United States ConocoPhillips Alaska, Inc. : 50-103-20271-01-002N-319A Tarn Oil Pool Nabors 9ES November 15, 2014 7:33pm to 11:57am Pale Allen Odegaard / Ben Calo Free oil and slight odor reported at shakers by sample catcher. Yes Yellow 1 10 100 1000 10000 1234 pp m DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 33 7 DAILY REPORTS ConocoPhillips Alaska, Inc. 2N-319A Daily Geologic Report Report for: Don Mickey G. Rizek Date: 10/31/14 Time: 23:59 Current Depth (MD): 2802’ Current Depth (TVD): 2802’ Current Operations: Drilling ahead 24 hr Footage (MD): 0’ Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: Gels: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas Connection Gases Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Operational Summary: PULLING CASING -ATTEMPT TO PULL CSG ON THE HOOK, SWABBING F/1912' T/ 1843'. ATTEMPT TO RIH, TOOK 25K WT AT 1843'. PUMP OUT OF THE HOLE, 235 GPM, 80 SPM, 200 PSI. F/ 1843' T/973', PU WT-48K, SOW-48K PULLING CASING CONT PULL CASING, PUMPING OUT F/973', T/941', CIRC HOLE @ 172 SPM, 330 PSI, 514 GPM / 158 SPM, 270 PSI, 460 GPM, C/O AIRBOOT ON RISER. CIRCULATE AND CONDITION PUMP HI VIS SWEEP 140 SPM, 285 PSI, 420 GPM PULLING CASING CONT PULL WHILE PUMPING, F/941', T/651', 86 SPM, 117 PSI, 253 GPM, UWT 45K, DWT 43K PULLING CASING CONT PULL WHILE PUMPING, F/ 651', T/ CUT JOINT, UWT 42K, DWT 42K, SPM 86, GPM 253, PSI 60,CUT JT 11.7, OD 7.5", MONITOR WELL 10 MIN, CONFIRMED DEAD CLEAN OUT MUD SYSTEM BD LINES, CLEAN AND CLEAR THE FLOOR, SET WEAR RING, C/O BALES, ELEVATORS, PREP AND RU FOR RUN TBG COMPLETION-TRIP TUBING/DP RUN 3.5 9.3PPF TBG CEMENT STINGER W/4" DP, UWT 35K, DWT 35K, F/SURFACE TO 895', MULE SHOE 3.90'. M/U TQ = 2800 FT/LBS. TRIP IN HOLE C/O ELEVATORS T/ 4" AND RIH W/ DP F/ 895' T/2042'. PU WT- 50K, SOW-50K Failures: None ConocoPhillips Alaska, Inc. 2N-319A Daily Geologic Report Report for: Don Mickey G. Rizek Date: 11/1/14 Time: 23:59 Current Depth (MD): 2802’ Current Depth (TVD): 2802’ Current Operations: Picking up BHA. 24 hr Footage (MD): 0’ Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: Gels: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas Connection Gases Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Operational Summary: TRIP IN HOLE - CONT. RIH WITH DP F/ 2042' T/ 2613'. PU WT-55K, SOW-55K. TAG TOP OF BRIDGE PLUG @ 2613' SET 5K DN T/ VARIFY. CIRCULATE AND CONDITION CBU @ 5BPM W/ 200 PSI. PREP F/ CMT JOB. ESTABLISH FLOW THROUGH CHOKE MANIFOLD, 315 PSI @ 5BBL/MIN. PJSM W/ ALL INVOLVED PERSONAL FOR CMT JOB. CEMENT PLUGS SET 25BBL 17PPG CMT PLUG @ 2613'. PUMP 5BBLS OF 12.5PPG MUD PUSH, PT 4000 PSI, PUMP 10 BBLS 12.5 MUD PUSH @5BPM W/ 282PSI. DROP WHIPER BALL FOLLWED BY 25 BBLS OF 17PPG CMT@ 5BPM W/ 310 PSI PUMP 5 BBLS OF MUD PUSH W/ 258PSI, DISPLACE CMT W/ 12.8BBLS OF 10PPG LSND W/ THE RIG @ 5BPM W/ 226 PSI. CMT IN PLACE @ 03:30. TRIP OUT OF HOLE R/D CMT LINES AND POOH F/ 261' T/ 2232' UP WT 55K DN WT 55K. PULL AT A SLOW RATE AND VARIFY FLUID DROPPING. B/D CMT LINES, CHOKE LINE AND CHOKE MANIFOLD. CLEAN OUT CMNT STINGER @ 2232' DROP WHIPPER BALL AND CIRC STRING CLEAN @ 8BBL/MIN W/ 430 PSI. TRIP OUT OF HOLE POOH F/ 2232' T/ 895' 55K UP, 55K DN. COMPLETION-TRIP TUBING/DP R/U GBR, L/D 3 1/2" TBG F/ 895' T/ SURFACE. LAY DOWN 3RD PARTY TOOLS PJSM - L/D GBR EQUIPMENT. CLEAN AND CLEAR FLOOR. PICK UP 3RD PARTY TOOLS PJSM - P/U AND INSTALL DUTCH RISER. PJSM W/ HALIBURTION CREW ON P/U WL TOOLS T/ RIG FLOOR AND CONT' T/ R/U WL. M/U PACK OFF AND TEST T/ 500 PSI. CASED HOLE LOGS PJSM,RU HALLIBURTON E LINE & RUN CASING LOG IN THE 7-5/8" 29.7 PPF L-80 BTC-M MULTIFINGER CALIPER COMPLETION-SLICK LINE/WIRELINE WORK RD WIRE LINE, BD LINES, LD DUTCH RISER PU TEST TOOLS MU TIW/DART, PULL WEAR RING, SET TEST PLUG/4" TEST JT, PURGE STACK AND CHOKE W/H2O, TEST BOPS STARTING ACCUMULATOR PSI 2900, 36 SEC 200PSI GAIN, 155 SEC FINAL PSI, AVERAGE BOTTLES 1970 PSI LD TEST TOOL RD AND BD LINES, CLEAN AND CLEAR FLOOR, SET WEAR RING, PICK UP BHA RIG UP FOR BHA. Failures: None ConocoPhillips Alaska, Inc. 2N-319A Daily Geologic Report Report for: Don Mickey G. Rizek Date: 11/2/14 Time: 23:59 Current Depth (MD): 2331’ Current Depth (TVD): 2331’ Current Operations: POOH. 24 hr Footage (MD): 0’ Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: Gels: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas Connection Gases Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Operational Summary: CLEANING RIG/PLATFORM --PJSM - CLEARING ICE F/ DERRICK. PICK UP BHA PJSM W/ ALL INVOLVED PERSONAL. M/U INTERMEDIATE BHA AS PER SLMB. VARIFY BIT S/N AND JETS. CIRCULATE AND CONDITION TEST RIP TIDE REAMER. 40 SPM - 250 PSI, 50 SPM - 360 PSI, 60 SPM - 515 PSI. REAMER IS FUNCTIONING PROPERLY AS PER WEATHERFORD REP. C/O BLANKS AND INSTALL 3 - 5/32 JETS. B/D TOP DRIVE. LAY DOWN BHA L/D REAMER, STAB, AND NM PONY T/ INSTALL SOURCE IN THE ADNVISION. PICK UP BHA CONT' T/ P/U BHA AS PER SLMB. TRIP IN HOLE F/ 619.75' T/ 2045' W/ 4" DP. UP WT 45K DN WT 45K. DISPLACE WELL BORE FLUID DISPLACE WELL W/ 9.6 PPG LSND @ 200 GPM W/ 850 PSI. CIRC UNTIL GOOD MW IN AND OUT. PRE JOB SAFETY B/D TD. PJSM W/ CREW F/ CUT AND SLIP. CUT DRILLING LINE CUT AND SLIP 76' OF DRILLING LINE. SERVICE RIG SERVICE AND INSPECT DRAW WORKS AND TOP DRIVE. TRIP IN HOLE CALIBRATE BLOCK HIGHT W/ CANRIG. CHECK/RESET CROWN SAVER. KELLY UP F/ SHALLOW PULSE TEST @ 2045 CIRCULATE AND CONDITION @2045' TEST MWD TOOLS, GPM 250, SPM 84, PSI 1357, UWT 70K, DWT 67K REAMING/WASHING WASH DOWN F/2045, T/2236', TAG CEMENT 2232', DRILL DOWN 4' AND CIRC BU. GPM 250, PSI 1300, TQ OFF 1360, TQ ON 2100, RPM 40, MW 9.6, UWT 71K, DWT 69K, ROT 76K PRESSURE TEST CSG/SHOE RU TO TEST CSG, PJSM, TEST CSG T/2500PSI FOR 30 MIN AND CHART, RD AND BD LINES DRILLING CEMENT DRILL F/ 2231 T/2331, WOB 5K, GPM- 290, PSI ON-1495, PSI OFF- 1499. RPM-50 TQ ON-3500K, TQ OFF 1600K. PU WT- 73K, SOW-68K, ROT-70K, ART-1.5HRS, ADT-1.5HRS, AST 0, TOTAL BIT HRS-1.5 TOTAL JAR HOURS-1.5 MW- 9.6 PPG, CIRCULATE AND CONDITION CLEAN UP HOLE, TEST MWD TOOLS, SPM 84, GPM 250, PSI1800, UWT 73, DWT 68, TRIP OUT OF HOLE PJSM, POOH F/ 2331', T/ 2045', DROP TABS FOR REAMER,PUMP AND TEST REAMER TOOL, 84 SPM, GPM 250, PSI 1785, CONT TROUBLE SHOOT MWD TOOL, BD TD PREP POOH TRIP OUT OF HOLE PJSM, POOH F/2045, T/619', UWT 70K, DWT 65K, MONITOR WELL 10 MIN AT BHA LAY DOWN BHA POOH T NUKES, LD NUKES AND MU PONY, STAB, RIP TIDE, TEST TOOLS,CONT LD TOOLS LAY DOWN BHA CLEAN AND CLEAR FLOOR, TROUBLESHOOT MWD TOOLS. Failures: None ConocoPhillips Alaska, Inc. 2N-319A Daily Geologic Report Report for: Don Mickey G. Rizek Date: 11/3/14 Time: 23:59 Current Depth (MD): 2250’ Current Depth (TVD): 3290’ Current Operations: Drilling Ahead. 24 hr Footage (MD): 1000’ Drilling Parameters ROP: Current: 120.600 Max: 427 Torque: Current: - Max: - WOB: Current 4.007 Max: 15 RPM: Current: 115.70 Max: 121 PP: Current: 1846.76 Max: 1859 Lag: Strokes: 1552 Time: 00:14:26 Surf-Surf: Strokes: 2028 Time: 00:18:55 ECD: Current: 11.3 Max: 11.4 Mud Properties @ MW: Gels: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : 12.2 46 2662’ MD LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas Connection Gases Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 3000’ MD 10.021 2574.520 3085’ MD 19.612 4984.849 Lithologies: 60% Claystone, 30% Siltstone, 10% Sand Operational Summary: PICK UP BHA PJSM W/ ALL INVOLVED ON P/U BHA. P/U BHA AS PER SLMB DD. @ 01:30 LOAD SOURCE IN ADN AND CONT' T/ M/U BHA T/ 619'. UP WT 45K DN W T 45K. TRIP IN HOLE F/ 619' T/ 2045' UP WT 65K DN WT 60K. CIRCULATE AND CONDITION @ 2045' M/U BLOW ER HOSE ON TD. SHALLOW PULSE MWD, STAGE UP T/ 225 GPM W/1095 PSI. UP WT 70K DN WT 65K. RT @ 25 RPM W/ 1.2K TQ, RT WT 68K. MWD GETTING A GOOD SIGNAL, WORKING ON COMPUTER TO READ/RECORD DATA. TRIP IN HOLE F/ 2045' T/ 2236' UP WT 72K DN WT 65K. WASH DN F/ 2236' T/ 2331' @ 220 GPM W/ 1080PSI. DRILLING CEMENT F/ 2331' T/ 2436' @ 217 GPM W/ 1075 PSI ON 1020 PSI OFF, 50 RPM W/ 3.5K TQ ON, 1.5K TQ OFF, W/ 5- 8K WOB. SPR @ 2436' MD, 2310' TVD- MP#1 @ 2BPM - 210 PSI, @ 3BPM - 370 PSI, MP#2 @ 2BPM - 220 PSI, @ 3BPM - 370 PSI. CONT' T/ DRILL T/ 2485' MD, 2332' TVD @ 265 GPM W/ 1500 PSI ON, 1480 PSI OFF, 0-5K WOB, 50 RPM W/ 3.5K TQ ON,1.6K OFF. UP WT 75K DN WT 65K, RT WT 73K. CONFIRM W/ MUD LOGGER 20' NEW HOLE. CIRCULATE AND CONDITION CIRC @ 2485' @ 265 GPM W/ 1490 PSI @ 50 RPM @ 1.8K TQ UNTIL HOLE CLEANS UP AND MUD PROPERTIES ARE GOOD. RACK BACK STAND T/ BE INSIDE THE SHOE @ 2426' F/ LOT. PRESSURE TEST CSG/SHOE PERFORMS LOT @ 2426' MD, 2300' TVD. PUMP DN DP AND ANNULUS MONITORING/RECORDING PSI ON ANNULUS. PRESSURE UP T/ 550 PSI, BROKE OVER- SHUT IN AND RECORD PSI. PSI STABALIZED @ 550PSI. EMW - 14.2PPG CIRCULATE AND CONDITION BD LINES RD TEST EQUIP ROTARY DRILLING DRILL F/ 2485 T/2807', WOB 7K, GPM- 330, PSI ON-1500, PSI OFF- 1450. RPM-120 TQ ON-4.5K, TQ OFF 1.7K. PU WT- 81K, SOW-71K, ROT-74K, ART-5.17HRS, ADT-5.17HRS, AST 0, TOTAL BIT HRS-6.67TOTAL JAR HOURS-10.36SPRS TAKEN AT 1550HRS, 2420'MD, 2332 TVD, PUMP #1 AT 2 BPM= 220 PSI, AT 3 BPM=380 PSI. PUMP #2 AT 2 BPM=220 PSI, AT 3 BPM= 370 PSI MW- 9.6 PPG, ROTARY DRILLING DRILL F/ 2807 T/3284, WOB 7K, GPM- 328, PSI ON-1875, PSI OFF- 1850. RPM-120 TQ ON-3K, TQ OFF 2K. PU WT- 90K, SOW-75K, ROT-80K, ART- 4.52HRS, ADT-4.52HRS,AST 0, TOTAL BIT HRS-11.19 TOTAL JAR HOURS-14.88,SPRS TAKEN AT 2200HRS, 3189 MD, 2857 TVD, PUMP #1 AT 2 BPM= 220PSI, AT 3 BPM=350 PSI. PUMP #2 AT 2 BPM=230 PSI, AT 3 BPM= 360 PSI MW- 9.6 PPG. Failures: None ConocoPhillips Alaska, Inc. 2N-319A Daily Geologic Report Report for: Don Mickey G. Rizek Date: 11/4/14 Time: 23:59 Current Depth (MD): 4428’ Current Depth (TVD): 3707’ Current Operations: Wiper trip. 24 hr Footage (MD): 2178’ Drilling Parameters ROP: Current: 62.13 Max: 427 Torque: Current: - Max: - WOB: Current 4.41 Max: 15 RPM: Current: 119.83 Max: 125 PP: Current: 2004.07 Max: 2062 Lag: Strokes: 2133 Time: 19:39:00 Surf-Surf: Strokes: - Time: - ECD: Current: - Max: 11.28 Mud Properties @ MW: Gels: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : 0 46 2662’ MD LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas Connection Gases Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 3760’ MD 21.029 3933.424 3941’ MD 14.800 2621.473 4304’ MD 20.717 4086.013 4420’ MD 11.112 2253.203 Lithologies: 20% Claystone, 20% Siltstone, 50% Sandstone, 10% Sand Operational Summary: ROTARY DRILLING DRILL F/ 3284' T/ 3761, TVD 3274' W OB 5K, GPM- 325, PSI ON-1910, PSI OFF- 1890. RPM-120 TQ ON-4.3K, TQ OFF 2.8K. PU WT- 88K, SOW-75K, ROT-78K, ART-4.22HRS, ADT 4.22HRS, TOTAL BIT HRS-15.41 TOTAL JAR HOURS-19.10, SPRS TAKEN AT 0430HRS, 3665' MD, 3198 TVD, PUMP #1 AT 2 BPM= 240 PSI, AT 3 BPM=370 PSI. PUMP #2 AT 2 BPM=240 PSI, AT 3 BPM= 370 PSI MW- 9.6 PPG.UTILIZE HI-VIS SWEEPS EVERY 300'. ROTARY DRILLING DRILL F/ 3761 T/4170, TVD 3586' WOB 5K, GPM- 328, PSI ON-1998, PSI OFF- 1970. RPM-120 TQ ON-4.8K, TQ OFF 3.8K. PU WT- 95K, SOW-80K, ROT-85K, ART-3.86HRS, ADT-3.86HRS, TOTAL BIT HRS-19.27 TOTAL JAR HOURS-22.96, SPRS TAKEN AT 11:15HRS, 4143' MD, 3559 TVD, PUMP #1 AT 2 BPM=240 PSI, AT 3 BPM=380 PSI. PUMP #2 AT 2 BPM=240 PSI, AT 3 BPM= 390 PSI MW- 9.6 PPG. UTILIZE HI-VIS SWEEPS EVERY 300' ROTARY DRILLING DRILL F/ 4170’ T/4358’, WOB 6.5K, GPM- 328, PSI ON-2000, PSI OFF- 1975. RPM-120 TQ ON-5K, TQ OFF 3.7K. PU WT- 105K, SOW-83K, ROT-88K, WAITING ON 3RD PARTY TOOLS CANRIG TROUBLESHOOTING RIGWATCH ROTARY DRILLING DRILL F/ 4358’ T/4428’,TVD 3764, WOB 7K, GPM- 330, PSI ON-2020, PSI OFF- 2010. RPM-120 TQ ON-6.9K, TQ OFF4K. PU WT- 108K, SOW-83K, ROT-89K, ART-2.98HRS, ADT- 2.98HRS, AST 0, TOTAL BIT HRS-22.25TOTAL JAR HOURS-25.94, SPRS TAKEN AT 1725HRS, 4428 MD, 3764 TVD PUMP #1 AT 2 BPM=250PSI, AT 3 BPM=390 PSI. PUMP #2 AT 2 BPM=260 PSI, AT 3 BPM= 390 PSI MW- 9.6 PPG, CIRCULATE AND CONDITION PUMP SURVEY, SHUTDOWN MWD TOOLS, CLOSE REAMER, PUMP HI-VIS SWEEP, MONITOR WELL 10 MIN BACK REAMING F/ 4428’ T/2426', GPM- 317, PSI OFF-2525 . RPM-100, TQ OFF4.3 K. PU WT- 107K, SOW-85K, ROT-89K, BOOH W/REAMER CLOSED, AT SHOE UWT 84K, DWT 71K, ROT 72K, PSI 1640, GPM 247, SPM 84 RPM 120, TQ 2K. Failures: None ConocoPhillips Alaska, Inc. 2N-319A Daily Geologic Report Report for: Don Mickey G. Rizek Date: 11/5/14 Time: 23:59 Current Depth (MD): 5764’ Current Depth (TVD): Current Operations: Drilling Ahead. 24 hr Footage (MD): 1336’ Drilling Parameters ROP: Current: 82.32 Max: 184.0 Torque: Current: 7609 Max: 8051 WOB: Current 6.9 Max: 16 RPM: Current: 0 Max: 123 PP: Current: 2213.08 Max: 2290 Lag: Strokes: 2918 Time: 00:26:45 Surf-Surf: Strokes: 3774 Time: 00:34:37 ECD: Current: 11.05 Max: 11.1 Mud Properties @ MW: Gels: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : 25 73 5427’ MD LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas Connection Gases 5711’ MD 16u Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 5165’ MD 22.479 5653.192 203.760 5253’ MD 35.412 8411.999 289.815 61.721 5665’ MD 45.329 7628.073 481.662 197.253 5744’ MD 27.727 6257.372 365.914 134.499 Lithologies: 10% Claystone, 20% Siltstone, 20% Sandstone, 50% Sand Operational Summary: REAMING/WASHING F/ 2522' T/ 2426' @ 250 GPM W/ 1485 PSI, UP WT 65K DN WT 75K. ONCE INSIDE THE SHOE @ 2441', CBU T/ CLEAN UP CSG. WELL CONTROL B/D TOP DRIVE AND MONITOR THE WELL F/ FLOW. WELL IS STATIC. TRIP IN HOLE F/ 2426' T/ 4332' UP WT 65K DN WT 78K. OBSERVERED NO HOLE DRAG. CALC DISP = 12.6 BBLS, ACTUAL DISP=17.2 BBLS, TOOK 11.5 BBLS T/ FILL PIPE. REAMING/WASHING WASH DN F/ 4332' T/ 4428' @ 250 GPM W/ 1660 PSI, @ 50 RPM W/ 3.8K TQ. RT WT 90K, UP WT 100K DN WT 85K. CBU ON BTM. CIRCULATE AND CONDITION DROP 4 TAGS AS PER WEATHERFORD REP T/ OPEN REAMER. PUMP DN @ 250 GPM W/ 1632 PSI. @ 50 RPM W/ 3.8K TQ. @ 505 STK PSI DROPED T/ 1344 PSI AND TQ INCREASED T/ 4.2K, T/ CONFIRM REAMER IS OPEN. PUMP SURVEY ON BTM W/ MWD. ROTARY DRILLING DRILL F/ 4426 T/4522, TVD 3830' WOB 3-5K, GPM- 325, PSI ON-1960, PSI OFF- 1950. RPM-120 TQ ON-5.9K, TQ OFF 3.8K. PU WT- 110K, SOW-85K, ROT-90K, ART. 96HRS, ADT-.96HRS, TOTAL BIT HRS-23.21 TOTAL JAR HOURS-26.90 ROTARY DRILLING DRILL F/ 4522 T/4999, TVD 4112' WOB 6K, GPM- 328, PSI ON-2140, PSI OFF- 2020. RPM-100 TQ ON-5.6K, TQ OFF 3.8K. PU WT- 105K, SOW-85K, ROT-93K, ART-4.46HRS, ADT-4.46HRS, TOTAL BIT HRS-27.67 TOTAL JAR HOURS-31.36, SPRS TAKEN AT 10:40HRS, 4904' MD, 4066 TVD, PUMP #1 AT 2 BPM=270 PSI, AT 3 BPM=410 PSI. PUMP #2 AT 2 BPM=260 PSI, AT 3 BPM= 410 PSI MW- 9.6 PPG. PUMP SWEEPS EVERY 300' OR AS NEEDED. ROTARY DRILLING DRILL F/ 4999 T/5379, TVD 4350 WOB 5, GPM- 325, PSI ON-2140, PSI OFF- 2035. RPM-100 TQ ON 6.3K, TQ OFF 5.3K. PU WT- 114K, SOW-93K, ROT-98K, ART- 4.2HRS, ADT-4.2HRS, AST 0, TOTAL BIT HRS-31.87TOTAL JAR HOURS-35.56, SPRS TAKEN AT 1730 HRS, 5379MD, 4350 TVD, PUMP #1 AT 2 BPM=290PSI, AT 3 BPM=430 PSI. PUMP #2 AT 2 BPM=290 PSI, AT 3 BPM= 430 PSI MW- 9.6 PPG, ROTARY DRILLING DRILL F/5379 5729,TVD4584' WOB 5-10K, GPM- 328, PSI ON-2230, PSI OFF- 2210. RPM-120 TQ ON-7.8K, TQ OFF 6.5K. PU WT- 120K, SOW-92K, ROT- 101K, ART-4.55HRS, ADT-4.55, HRS, AST 0, TOTAL BIT HRS-36.42, TOTAL JAR HOURS-40.11, MW- 9.6 PPG. Failures: None ConocoPhillips Alaska, Inc. 2N-319A Daily Geologic Report Report for: Don Mickey G. Rizek Date: 11/6/14 Time: 23:59 Current Depth (MD): 6580’ Current Depth (TVD): Current Operations: Back reaming 24 hr Footage (MD): 816’ Drilling Parameters ROP: Current: 61.54 Max: 178.3 Torque: Current: 6976.3 Max: 9037 WOB: Current 4.86 Max: 14 RPM: Current: 101.48 Max: 134 PP: Current: 2483.36 Max: 2527 Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: 10.6 Max: 11.4 Mud Properties @ MW: Gels: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : 23 94 4406’ MD LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas 6307’ MD 94 u Connection Gases 6359’ MD 25 u Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 6512’ MD 46.108 11333.306 535.340 328.641 48.924 110.722 0 0 6294’ MD 94.188 22818.842 1275.187 584.712 138.493 292.837 0 0 Lithologies: 60% Shale, 30% Siltstone, 10% Sandstone Operational Summary: ROTARY DRILLING DRILL F/ 5729’ T/6138’,TVD 4826' WOB 7K, GPM- 323, PSI ON-2280, PSI OFF- 2275. RPM-110 TQ ON-7.6K, TQ OFF 5.3K. PU WT- 118K, SOW-90K, ROT-100K, ART-4.15HRS, ADT- 4.15HRS,TOTAL BIT HRS-40.57 TOTAL JAR HOURS-44.26, SPRS TAKEN AT 0100 HRS, 5855' MD, 4649’ TVD, PUMP #1 AT 2 BPM= 300 PSI, AT 3 BPM=460 PSI. PUMP #2 AT 2 BPM=300 PSI, AT 3 BPM= 460 PSI MW- 9.6 PPG. PUMP HIGH VIS SWEEPS EVERY 300'. ROTARY DRILLING DRILL F/ 6138’ T/6520’ ,TVD 5049 WOB 7K, GPM- 330, PSI ON-2500, PSI OFF- 2490. RPM-100 TQ ON-7.8K, TQ OFF 4.8K. PU WT- 120K, SOW-93K, ROT-103K, ART-4.84HRS, ADT-4.84HRS, TOTAL BIT HRS-45.41 TOTAL JAR HOURS-49.1SPRS TAKEN AT 0830 HRS, 6331 MD, 4942’ TVD, PUMP #1 AT 2 BPM= 300 PSI, AT 3 BPM=460 PSI. PUMP #2 AT 2 BPM=310 PSI, AT 3 BPM= 480 PSI MW- 9.6 PPG. PUMP SWEEPS EVERY 300'. LIMIT ECD'S MAX 11.8. ROTARY DRILLING DRILL F/ 6521’ T/6580’,TVD 5100 WOB 8K, GPM- 330, PSI ON-2480, PSI OFF- 2475. RPM-100 TQ ON-7.3K, TQ OFF 6.3K. PU WT- 135K, SOW-97K, ROT-100K, ART-.8HRS, ADT- .8HRS,AST0,TOTAL BIT HRS-46.21TOTAL JAR HOURS-49.9, SPRS TAKEN AT 1330, HRS, 6580 MD, 5100’ TVD, PUMP #1 AT 2 BPM= 300 PSI, AT 3 BPM 500 PSI. PUMP #2 AT 2 BPM=330 PSI, AT 3 BPM= 500 PSI MW- 9.6PPG. CIRCULATE AND CONDITION OBTAIN SURVEY, SPR'S, DOWNLINKS, CLOSE REAMER, PUMP HI VIS SWEEP, MONITOR WELL. BACK REAMING F6580', T/6235' 30 MIN PER STAND, UWT 128K, DWT 94K, ROT 103K, GPM 240, PSI 1525, MONITOR WELL MW 9.6. BACK REAMING CONT F/6235', T/ 4522', UWT 107K, DWT 84K, ROT 88K, GPM 240, PSI 1400, MW 9.6. Failures: None ConocoPhillips Alaska, Inc. 2N-319A Daily Geologic Report Report for: Don Mickey G. Rizek Date: 11/7/14 Time: 23:59 Current Depth (MD): 6580’ Current Depth (TVD): Current Operations: Preparing to run casing 24 hr Footage (MD): 0’ Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: Gels: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : 0 LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas Connection Gases Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: 60% Shale, 30% Siltstone, 10% Sandstone Operational Summary: LAY DOWN BHA CONT. L/D BHA F/ 6 5/8 STAB, REMOVE SOURCE, REMOVE ADN, MILK MTR, BRAKE BIT, CONT. L/D BHA LAY DOWN 3RD PARTY TOOLS - L/D BHA TOOLS DOWN BEAVER SLIDE, CLEAN AND CLEAR FLOOR, M/U JOHNNY WACKER ON JNT DP REAMING/WASHING - FUNCTION BOP'S, JOHNNY WACK STACK INSTALL/REMOVE WEAR BUSHING - PULL WR RIG UP/DOWN TO RUN CASING - MAKE DUMMY RUN W/ HGR, L/D LANDING JNT, LEAVE HGR ON FLOOR RIG UP/DOWN TO RUN CASING - REMOVE DP ELEVATORS, INSTALL SIDE DOOR ELEVATORS, REMOVE HT-40 SAVER SUB PU TEST TOOLS - M/U BLANK, TEST BRAKE ON SAVER SUB, AND TIW VALVE ON SUB, R/D B/D TD RIG UP/DOWN TO RUN CASING - REMOVE SHORT BAILS, INSTALL LONG BAILS, P/U VOLANT RUNNING TOOL, M/U TOOL ON TD, PRE JOB SAFETY MEETING - RUN LINER, 5.5 563/L80 M/U SHOE TRACK Failures: None ConocoPhillips Alaska, Inc. 2N-319A Daily Geologic Report Report for: Don Mickey G. Rizek Date: 11/8/14 Current Depth (MD): 6580’ Time: 23:59 Current Depth (TVD): Current Operations: 24 hr Footage (MD): 0’ Preparing to cement Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: FV: PV: YP: FL: Gels: Sol: pH: Cl: Ca: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : 13 84 6512’ MD LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas Connection Gas Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: 60% Shale, 30% Siltstone, 10% Sandstone Operational Summary: RUN CASING CONT' T/ RUN 5 1/2" LINER F/ 3954' T/ 4500' @ 40'/MIN MAX RUNNING SPEED. UP WT 90K DN WT 78K. CIRCULATE AND CONDITION - CIRC B/U @ 4500' STAGE PUMPS UP T/ 6 BPM, 1100 PSI, NO LOSSES DURING CIRC. CONT. TO RIH RUN CASING CONT' T/ RUN 5 1/2" LINER F/ 4500' T/ 6570' @ 25'/MIN MAX RUNNING SPEED. UP WT 125K DN WT 75K. CAL FILL-16.5 BBLS, ACT FILL 18.7 BBLS RUN CASING - M/U HGR, P/U LANDING JNT REAMING/WASHING - WASH DOWN W/ HGR, PACKING OFF, SLOWLY STAGE PUMPS UP WHILE WORKING DOWN, CIRC. 2.5 B/U, 5 BPM 950 PSI, WORK CSG FREE UNTILL GOOD RETURNS ARE OBSERVED, RICP 15' F/ BTM, PREP MUD FOR CMT JOB Failures: None ConocoPhillips Alaska, Inc. 2N-319A Daily Geologic Report Report for: Don Mickey G. Rizek Date: 11/9/14 Current Depth (MD): 6580’ Current Operations: Preparing for casing test Time: 23:59 Current Depth (TVD): 24 hr Footage (MD): 0’ Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: FV: PV: YP: FL: Gels: Sol: pH: Cl: Ca: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 0 Max: 13 Depth (MD/TVD): 6511’ MD Avg BG : 0 LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas Connection Gas Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: 60% Shale, 30% Siltstone, 10% Sandstone Operational Summary: DISPLACE TO COMPLETION FLUID - PRPE RIG FLOOR FOR L/D 4" DP, P/U 2 7/8 TOOLS, PREP CELLAR FOR FREEZE PROTECTING OA W/ 44 BBLS H20 FOLLOWED BY 37 BBLS ISOTHERM, CIRC @ 3 BBL MIN 610 PSI, BROKE OVER @ 580 PSI, S/D LINE UP LRS, CIRC @ 1.5-1.8 BBL/MIN 1600 PSI, OA PSI 540 LAY DOWN DRILL PIPE - L/D 93 JNTS 4" DP VIA MOUSE HOLE PICK UP 3RD PARTY TOOLS - C/O SAVER SUB/DIE BLOCK/STABBING GUIDE F/ 2 7/8 PIPE, INSTALL ELEVATORS, P/U LIFT NUBS FOR RACKING BACK PIPE, INSTALL PULL BACK ROPE IN 2 7/8 PIPE IN DERRICK WELL CONTROL - MONT. WELL 30 MIN. PREP CELLAR FOR C/O BOTH SETS OF VBR'S T/ 2 7/8 X 5. R/U UP FOR CASING TEST. Failures: None ConocoPhillips Alaska, Inc. 2N-319A Daily Geologic Report Report for: Don Mickey G. Rizek Date: 11/10/14 Current Depth (MD): 6580’ Time: 23:59 Current Depth (TVD): Current Operations: 24 hr Footage (MD): 0’ Testing BOP Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: FV: PV: YP: FL: Gels: Sol: pH: Cl: Ca: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Data Ditch Gas: Current: 0 Avg BG : 0 Max: 25 Depth (MD/TVD): 6543’ MD Gas Events Depth (MD/TVD) Total Trip Gas Connection Gas Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: 60% Shale, 30% Siltstone, 10% Sandstone Operational Summary: TEST BOPS TEST BOPS. 250 PSI/ 3500 PSI F/ 5 MIN CHART W/ 2 7/8" AND TEST CHOKE VALVE 1-16, MANUAL CHOKE AND KILL, HCR CHOKE AND KILL, DEMCO KILL, SPR CKE/MAN CHOKE, 2 7/8 TIW/DART, UIBOP, LIBOP, ANN, TOP RAMS - 2 7/8 X 5" BLINDS, LOWER RAMS - 2 7/8 X 5", BAG FAIL, R/D TEST EQUIP. FOR C/O HYDRILL ELEMENT, KMY TEST K=2900 M=1500, FUNCTION RAM/HCR K=1750 M=1500, 31 SEC 200 PSI 140 FULL CHARGE, 6 BTL AVG 2025. CHANGE ROTATING HEAD/RUBBER - REMOVE RISER, REMOVE DUTCH RISER, L/D MOUSE HOLE, REMOVE STABBING GUIDE, M/U X-O FOR TD QUILL T/ HT-40, M/U POTATO MASHER ON HYDRIL, C/O HYDRIL ELEMENT, R/D MASHER, M/U DUTCH RISER, INSTALL RISER. TEST BOPS - R/U TESTING EQUIPMENT, FILL STACK, INSTALL 3.5 JNT, TEST OTTER SPOOL VALVE, BAG Failures: None ConocoPhillips Alaska, Inc. 2N-319A Daily Geologic Report Report for: R. Dolcater J. Riley Date: 11/11/14 Current Depth (MD): 6580’ Time: 23:59 Current Depth (TVD): Current Operations: 24 hr Footage (MD): 0’ Running in hole Drilling Parameters ROP: Current: 0 Max: 0 Torque: Current: 3.53 Max: 354 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 3143 PP: Current: 1324 Max: Lag: Strokes: 1515 Time: 23:59 Surf-Surf: Strokes: N/A Time: 23:59 ECD: Current: 0 Max: 0 Mud Properties @ MW: FV: PV: YP: FL: Gels: Sol: pH: Cl: Ca: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Data Ditch Gas: Current: 0 Avg BG : 0 Max: 0 Depth (MD/TVD): N/A Gas Events Depth (MD/TVD) Total Trip Gas Connection Gas Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: 60% Shale, 30% Siltstone, 10% Sandstone Operational Summary: TEST BOPS TEST 2 7/8" TEST JT W/ ANNULAR AND OUTER TEST SPOOL VALVE, 250 LOW / 3500 PSI HIGH F/ 5 MIN, TEST ANNULAR W/ 3.5 " TEST JT AND INNER TEST SPOOL VALVE 250 LOW / 3500 PSI HIGH. INSTALL/REMOVE WEAR BUSHING PULL TEST AND RIH W/ WR AS PER FMC REP, RUN IN LDS. LD TEST TOOL R/D TEST EQUIPMENT AND B/D LINES. LINE UP CHOKE MANIFOLD AND STACK F/ NORMAL DRILLING OPS. PREP FLOOR F/ M/U BHA. PICK UP BHA M/U 4 3/4 BHA AS PER SLMB. SAFETY STAND-DOWN SAFETY STAND DOWN W/ CREW DISCUSSING PROPER PRE-JOB PLANNING AND MITIGATION. PICK UP DRILL PIPE PJSM W/ ALL INVOLVED. C/O GRIPPER BLOCK F/ BACK UP WRENCH AND ADJUST FOOT F/ M/U 2 7/8" DP. SINGLE IN THE HOLE F/ 115' T/ 304' RABBITING OFF THE SKATE T/ 1.3 DRIFT. PICK UP DRILL PIPE - PJSM W/ DOYON CASING, R/U POWER TONGS, CONT. RIH F/ 304' T/ 1500' UWT-49K DWT-46K, DRIFT W/ 1.37 CAL HOLE FILL- 8 BBLS ACT HOLE FILL- 8.1BBLS. CIRCULATE AND CONDITION - FILL PIPE, SHALLOW TEST MWD TOOLS, CIRC @ 42 SPM 125 GPM 1520 PSI, BLOW DOWN TD. PICK UP DRILL PIPE -CONT. RIH F/ 1500' T/ 5779' UWT-94K DWT-63K DRIFT W/ 1.37 CAL HOLE FILL- 20 BBLS ACT HOLE FILL-25.3 BBLS, FILL PIPE @ 3500/5500' B/D TD. Failures: None ConocoPhillips Alaska, Inc. 2N-319A Daily Geologic Report Report for: R. Dolcater J. Riley Date: 11/12/14 Current Depth (MD): 6674’ Time: 23:59 Current Depth (TVD): 5157’ Current Operations: 24 hr Footage (MD): 94’ Drilling ahead Drilling Parameters ROP: Current: 28.27 Max: 61.5 Torque: Current: 2351.57 Max: 6976 WOB: Current Max: RPM: Current: 70.24 Max: 101 PP: Current: 2608.75 Max: 3295 Lag: Strokes: 1856.39 Time: 23:59 Surf-Surf: Strokes: 2379 Time: 23:59 ECD: Current: Max: Mud Properties @ MW: 9.8 FV: 43 PV: 10 YP: 8 FL: 4.5 Gels: 5/5/7 Sol: 7 pH: 10.1 Cl: 2100 Ca: 200 MW Change: Depth: N/A From: N/A To: N/A Reason: N/A Mud Loss event: Depth: N/A Volume: N/A LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Data Ditch Gas: Current: 0 Avg BG : 1 Max: 8 Depth (MD/TVD): 6580 Gas Events Depth (MD/TVD) Total Trip Gas N/A N/A Connection Gas N/A N/A Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 9 6610 1 10 6640 1 Lithologies: 70% Sand, 30% Clay Operational Summary: Pick up drill pipe, run in hole, circulate and condition, drill out cement, FIT @ 15.8ppg, continue drilling. Failures: None ConocoPhillips Alaska, Inc. 2N-319A Daily Geologic Report Report for: R. Dolcater J. Riley Date: 11/13/14 Current Depth (MD): 6678’ Time: 23:59 Current Depth (TVD): 5283’ Current Operations: 24 hr Footage (MD): 204’ Increasing mud density and circulating Drilling Parameters ROP: Current: 0 Max: 132 Torque: Current: 5 Max: 2800 WOB: Current 0 Max: 14 RPM: Current: 0 Max: 85 PP: Current: 1869 Max: 2959 Lag: Strokes: 1907 Time: 23:59 Surf-Surf: Strokes: 2437 Time: 23:59 ECD: Current: Max: Mud Properties @ MW: 10 FV: 45 PV: 7 YP: 21 FL: 4.2 Gels: 7/8/10 Sol: 8 pH: 8.9 Cl: 1500 Ca: 80 MW Change: Depth: 6879’ MD From: 10 To: 10.2 Reason: Well control Mud Loss event: Depth: Volume: LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Data Ditch Gas: Current: 1704 Avg BG : 272 Max: 1483 Depth (MD/TVD): 6871 Gas Events Depth (MD/TVD) Total Trip Gas 6753’ MD 22 Connection Gas 6845’ MD 1580 Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 11 6670’ MD 1 288 16 12 6700’ MD 1 521 28 13 6730’ MD 2 481 19 14 6760’ MD 6 762 26 15 6790’ MD 54 6448 540 446 55 116 16 6811’ MD 192 6094 483 396 48 80 17 6820’ MD 276 57109 4935 4252 619 1367 157 108 18 6850’ MD 1021 141947 12934 11934 1667 3903 820 1007 Lithologies: 40% Sand, 40% Sandstone, 10% Siltstone, 10% Claystone Operational Summary: Drill ahead from 6691’ to 6753’ MD, back ream from 6753’ to 6555’ MD, cut/slip and circulate @ 6555’ MD, trip in hole from 6565’ to 6754’, drill ahead from 6754’ to 6857’ MD, increase mud density from 9.8 to 10 ppg, wipe from 6857’ to 6825’, drill ahead from 6857’ to 6879’ MD, increase mud density from 10 to 10.2 ppg and circulate at 6879’. Failures: None ConocoPhillips Alaska, Inc. 2N-319A Daily Geologic Report Report for: R. Dolcater J. Riley Date: 11/14/14 Current Depth (MD): 7106’ Time: 23:59 Current Depth (TVD): 5439’ Current Operations: 24 hr Footage (MD): 428’ Drilling ahead Drilling Parameters ROP: Current: 36 Max: 153.8 Torque: Current: 206 Max: 3074 WOB: Current 9 Max: 19 RPM: Current: 17 Max: 93 PP: Current: 2825 Max: 3045 Lag: Strokes: 1973 Time: 33 min Surf-Surf: Strokes: 4497 Time: 42 min ECD: Current: Max: Mud Properties @ MW: 10.8 FV: 46 PV: 17 YP: 21 FL: 3.5 Gels: 8/9/11 Sol: 10 pH: 9.3 Cl: 650 Ca: 70 MW Change: Depth: 7019’ MD From: 10.6 To: 10.8 Reason: Vol. gains Mud Loss event: Depth: N/A Volume: N/A LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Data Ditch Gas: Current: 816 Avg BG : 1031 Max: 4716 Depth (MD/TVD): 7034’ MD Gas Events Depth (MD/TVD) Total Trip Gas N/A N/A Connection Gas 7037’ MD 2466 Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 19 6880’ MD 1378 142397 16411 18578 3257 8240 2136 2718 20 6910’ MD 1539 159713 17604 20427 3673 9362 2539 3308 21 6940’ MD 2094 183674 26358 34118 5874 14731 3825 4829 22 6970’ MD 1539 165838 19573 23403 4019 10117 2722 2319 23 7000’ MD 2094 271036 29913 36591 6264 15438 3835 4754 24 7030’ MD 1525 228310 22731 25199 4230 10808 2798 3505 25 7060’ MD 2442 202417 20071 23527 3987 10328 2742 3461 26 7090’ MD 1946 142397 16411 18578 3257 8240 2136 2718 Lithologies: 50% Sand, 40% Sandstone, 10% Siltstone Operational Summary: Continued drilling from 6678’ MD, increased mud density from 10.6 to 10.8 at 7019’ MD to reduce mud volume gains and control gas, and drilled through to 7106’ MD. Failures: None ConocoPhillips Alaska, Inc. 2N-319A Daily Geologic Report Report for: R. Dolcater J. Riley Date: 11/15/14 Current Depth (MD): 7300’ Time: 23:59 Current Depth (TVD): 5570’ Current Operations: 24 hr Footage (MD): 194’ Reached TD. Well control. Drilling Parameters ROP: Current: 0 Max: 56 Torque: Current: 0 Max: 2223 WOB: Current 0 Max: 16 RPM: Current: 0 Max: 93 PP: Current: 2 Max: 3127 Lag: Strokes: 2011 Time: 42min Surf-Surf: Strokes: 2573 Time: 53min ECD: Current: N/A Max: N/A Mud Properties @ MW: 11.3 FV: 44 PV: 15 YP: 36 FL: 3.2 Gels: 11/12/13 Sol: 12 pH: 9.2 Cl: 700 Ca: 70 MW Change: Depth: 7300’ MD From: 10.8 To: 11.3 Reason: Vol. gains Mud Loss event: Depth: N/A Volume: N/A LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Data Ditch Gas: Current: 0 Avg BG : 1008 Max: 4787 Depth (MD/TVD): 7222’ MD Gas Events Depth (MD/TVD) Total Trip Gas N/A N/A Connection Gas 7070’ MD 784 7105’ MD 1637 7135’ MD 2003 7165’ MD 1014 7195’ MD 2289 7225’ MD 4111 7260’ MD 4105 7290’ MD 2306 Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 7,120 861 49445 7272 11867 3204 9499 3694 3845 7,150 818 47680 7443 12343 3021 8800 3161 2895 7,180 798 47363 7808 13122 2935 8396 2756 2098 7,210 651 31146 5297 9177 1984 5746 1832 2507 7,240 526 15372 3871 7845 1845 5330 883 1229 7,270 759 29787 6179 10978 2470 6950 2169 2942 7,300 817 35224 6868 11971 2638 7416 2376 3165 Lithologies: 10% Sand, 20% Sandstone, 20% Siltstone, 20% Shale Operational Summary: Drilled ahead to TD. Tarn 2N-319A reached TD at 7300’ MD. Mud density was increased from 10.8 to 11.3 throughout the day to control fluid gains and gas. Failures: None ConocoPhillips Alaska, Inc. 2N-319A Daily Geologic Report Report for: R. Dolcater J. Riley Date: 11/16/14 Current Depth (MD): 7300’ Time: 23:59 Current Depth (TVD): 5570’ Current Operations: 24 hr Footage (MD): 0’ Pulling out of well Drilling Parameters ROP: Current: 0 Max: 0 Torque: Current: 287 Max: 6000 WOB: Current 0 Max: 0 RPM: Current: 17 Max: 71 PP: Current: 3 Max: 2687 Lag: Strokes: 2011 Time: 42min Surf-Surf: Strokes: 2573 Time: 53min ECD: Current: N/A Max: N/A Mud Properties @ MW: 11.6 FV: 51 PV: 12 YP: 37 FL: 3 Gels: 12/14/16 Sol: 13.5 pH: 9.5 Cl: 700 Ca: 60 MW Change: Depth: 7300’ MD From: 11.3 To: 11.6 Reason: Well control Mud Loss event: Depth: 7300’ MD Volume: 15 bbls LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Data Ditch Gas: Current: 154.21 Avg BG : 267 Max: 2801 Depth (MD/TVD): 7300’ MD Gas Events Depth (MD/TVD) Total Trip Gas N/A N/A Connection Gas N/A N/A Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A Lithologies: 10% Sand, 20% Sandstone, 20% Siltstone, 20% Shale Operational Summary: Washed and reamed, increased mud density from 11.3 to 11.6 to control gas, monitored the well before pulling out, and then proceeded to pulled out of the well. Failures: None ConocoPhillips Alaska, Inc. 2N-319A Daily Geologic Report Report for: R. Dolcater J. Riley Date: 11/17/14 Current Depth (MD): 7300’ Time: 23:59 Current Depth (TVD): 5570’ Current Operations: 24 hr Footage (MD): 0’ Wireline Drilling Parameters ROP: Current: 0 Max: 0 Torque: Current: 6 Max: 5334 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 21 PP: Current: 5 Max: 1768 Lag: Strokes: 2011 Time: 42min Surf-Surf: Strokes: 2573 Time: 53min ECD: Current: N/A Max: N/A Mud Properties @ 7300’ MD MW: 1.6 FV: 56 PV: 14 YP: 14 FL: 3.1 Gels: 12/14/15 Sol: 14 pH: 9.3 Cl: 700 Ca: 80 MW Change: Depth: N/A From: N/A To: N/A Reason: N/A Mud Loss event: Depth: N/A Volume: N/A LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Data Ditch Gas: Current: 17.3 Avg BG : 31 Max: 182 Depth (MD/TVD): 7300’ MD Gas Events Depth (MD/TVD) Total Trip Gas N/A N/A Connection Gas N/A N/A Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A Lithologies: 10% Sand, 20% Sandstone, 20% Siltstone, 20% Shale Operational Summary: Ream and wash on way out of well, and began logging well via wireline. Failures: None ConocoPhillips Alaska, Inc. 2N-319A Daily Geologic Report Report for: R. Dolcater J. Riley Date: 11/18/14 Current Depth (MD): 7300’ Time: 23:59 Current Depth (TVD): 5570’ Current Operations: 24 hr Footage (MD): 0’ Casing Drilling Parameters ROP: Current: 0 Max: 0 Torque: Current: 8 Max: 14998 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 45 PP: Current: 7 Max: 466 Lag: Strokes: 2011 Time: 42min Surf-Surf: Strokes: 2573 Time: 53min ECD: Current: N/A Max: N/A Mud Properties @ 7300’ MD MW: 11.6 FV: 49 PV: 12 YP: 38 FL: 3.5 Gels: 11/12/16 Sol: 14 pH: 9 Cl: 700 Ca: 80 MW Change: Depth: N/A From: N/A To: N/A Reason: N/A Mud Loss event: Depth: N/A Volume: N/A LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Data Ditch Gas: Current: 94.5 Avg BG : 68 Max: 681 Depth (MD/TVD): 7300’ MD Gas Events Depth (MD/TVD) Total Trip Gas N/A N/A Connection Gas N/A N/A Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A Lithologies: 10% Sand, 20% Sandstone, 20% Siltstone, 20% Shale Operational Summary: Completed wireline logging, and began lining production section with 3.5“ casing. Failures: None
