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HomeMy WebLinkAbout186-108 • • 2-Co'oco WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. r_ nJuly 22, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 G .k DATA LOGGED /14/2015 Anchorage, Alaska 99501 M K.BENDER RE: Radial Cutting Torch & String Shot: 2T-07 Run Date: 7/3/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2T-07 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20069-00 SCANNED 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: iDvaizetstix_dckf jelegveye • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg '1li� DATE: July 21, 2015 P. I. Supervisor 'f e FROM John Crisp, SUBJECT: Permanent Plug and Abandon Petroleum Inspector KRU 2T-07 PTD 186-108 Conoco/Phillips July 21, 2015: I traveled to Conoco/Phillips' Kuparuk River Unit 2T-07 to witness casing cutoffs and to verify integrity of top cement plug. Casing strings were found to be cut off at a depth of approximately 7 feet below tundra level. Cement was hard in all casing strings cut off at surface. Well abandonment marker plate was installed with accurate well information bead- welded on the plate as per 20 AAC 25.120. Summary: I witnessed permanent surface abandonment and plate installation as per 20 AAC 25.120 on KRU 2T-07. Attachments: 7 Photos Non-Confidential 10 AUL ZQ" 2015-0721_Surface Abandon KRU 2T-07_jc.docx Page 1 of 5 • • .000i 0 d O Q N N 4cti N LOVi� s" Q R W o • 7 3 co o +' tj CI H C1) h CL C p _ -41 *t -3611/4 N 0 t I C4 C4 RI — O 015 CI. EL r•-• • • :-,rte, ,- . • a f:.-\1‘-'11''.r.' •:i•-•,',, -. 4'14‘4*:',,,';'.'''''''.....-.; - 1 ;,l�iill,i1,I1 i! is ' El..' z - ..x Vit: ( tt �1 'G _ __ -...44!1!1: =i f� i L,f� _ ! ' _ tt , w • II,ii } _ It O 0 CCI CI) ` • � ',�i= ii b M :Y, it _1!' _0 bA c3 U Ct 1-1 1 t# N vn O N yX • • 1 ' r s . w ,-%:,-,;,-,,,,A;,:„,„: _ y� `s'i 44�y+ tF _ 0 Fi 0 ,b , 0 • 1 H K.+ --`�. *, +.. ti I Y ***Z.,:,,:..1"', o ice" x�• 0 h4t. a) al I.1 a) ct cI y r Vn O CA -gym•:. " :t • • `*„.,, ,, '.4".-' . ,. - ,,'I.:: ' 1,1, . ,i j ,, ,,..i 'P.\:*: , ::lat''i''''‘'''1. ,': % 4 r;'... ; ;#":,' ' ; $: ' ''''.‘* f;*4',,:w *7\ 14 o ti A tel''1 _ ''PP•S '4,0.,'4.'.,...:-„?2' t i l .yA '� •7 s: _,, .. .. t N I� E. . ' : r,. s • kr F p :• O .0 e N $/ r.. N O V) O eV :46.....c,... .,µ ,. s 1 r'+ • 2Ca t 0 0 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. July 7, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 104/201S BENDER.vi.K.BENDE AUG 13 2Ui;; RE: Multi Finger Caliper(MFC): 2T-07 Run Date: 6/26/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2T-07 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-103-20069-00 SCANNED PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: MA-42-'141/4-4) 6-44ftedde RECEIVED STATE OF ALASKA JUL 3 1 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOCCC 1 a.Well Status: oi J Gas❑ SPLUG U Other ❑ Abandoned Suspended❑ lb.Well Class: 20nkC 25.105 20AAC 25 110 Development [71 - Exploratory ❑ GINJ ❑ WINJ [I WAGE] WDSPL❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp., Susp.,or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 7/11/2015 -186-108/315-275/315-374/315-416/315-417 3.Address: 7. Date Spudded: 15.API Number: P. O. Box 100360,Anchorage,AK 99501 7/22/1986 50-103-20069-00 - 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 277'FSL, 556'FWL, Sec. 1,T11N, R8E, UM 8/25/1986 KRU 2T-07 Top of Productive Interval: 9. KB(ft above MSL): 117' 17. Field/Pool(s): 1286'FSL, 1172'FEL, Sec.2, T11N, R8E, UM GL(ft above MSL): 41' Kuparuk River Field/Kuparuk River Oil Poo Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: ,1409'FSL, 1477'FEL, Sec. 2,T11N, R8E, UM surface ADL 25569 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 498945 y- 5970258 Zone- 4 6975'MD/6087'TVD 2667 TPI: x- 497216 y- 5971266 Zone- 4 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 496911 y- 5971390 Zone- 4 1786'MD/1786'TVD 1550'MD/1550'TVD 5. Directional or Inclination Survey: Yes ❑(attached) No ❑ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 na (ft MSL) not applicable 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment,whichever occurs first.Types of logs to be listed include, but are not limited to: mud log,spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance,dipmeter,formation tester,temperature, cement evaluation, casing collar locator,jewelry, and perforation record. Acronyms may be used.Attach a separate page if necessary NONE SCANNED SEP 0 9 2015 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 16" 62.5# H-40 33' 110' 33' 110' 24" 245 sx CS II 9.625" 36# J-55 33' 2772' 33' 2772' 12.25" 750 sx AS III, 285 sx Class G 7" 26# J-55 348' 6449' 348' 5724' 8.5" 410 sx Class G,200 sx AS I 5" 18# S-140/N-8 6229' 6975' 5574' 6086' 6.125" 125 sx Class G 24.Open to production or injection? Yes ❑ No ❑ 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 2.875"x 2.375" 6566' 6076'MD/5472'TVD and 6571'-6613'interval squeezed off 6551'MD/5795'TVD 6524'-6539'open perfs 26.ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No Per 20 AAC 25.283(0(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 1675-6026' 804 sx Class G 491'-1633' 254 sx Class G 264-365'and 34'-262' 604 sx Class G and 109 sx Class G 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): plugged and abandoned Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period - Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate .....,- Form -►Form 10-407 Revised 5/2015 (� 7-- ?5--- COQ N/U/3fr QM PAGE B �� AUG 2 7 2015 Submit ORIGINIAL on 28.CORE DATA Conventional Core(s): Yes ❑ No ❑✓ Sidewall Cores: Yes ❑ No Q If Yes, list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. NONE 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No 0 Permafrost-Top surface surface If yes, list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1550' 1550' Attach separate pages to this form, if needed,and submit detailed test information, including reports,per 20 AAC 25.071. Kuparuk C 6521' 5773' Base Kuparuk C 6540' 5786' Top Kuparuk A 6540' 5786' Base Kuparuk A 6738' 5923' NA Formation at total depth: Kuparuk 31. List of Attachments: Summary of Daily Operations,wellbore schematic,photos of welled plate Information to be attached includes, but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report,production or well test results,per 20 AAC 25.070. 32 I hereby certify that the foregoing is true and correct to the best of my knowledge. �� Contact' Danny Kane @ 265-6048 Email: Daniel.Kane@cop.com 3t 3�1 1 Printed Name: G.L Alvord Title: Alaska Drilling Manager Signature - . Gd Phone: 265-6120 Date: 7 N (za c INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item 1 a. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item lb: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing 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 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation:Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results,including,but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including, but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 5/2015 Submit ORIGINAL Only s \ KUP PROD 2T-07 ConocoPhillips ° Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MO(ftKB) Act Btm(ftKB) 1gpy 501032006900 KUPARUK RIVER UNIT PROD 49.68 5,400,00 6,975.0 ... `� Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) `Rig Release Date 2T-07,7/21/20153:27:18 PM SSSV:LOCKED OUT Last WO: 6/4/2015 40.00 8/28/1986 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: 6,573.0 2/7/2004 Rev Reason:WORKOVER smsmith 7/21/2015 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 33.0 110.0 110.0 62.50 H-40 WELDED Ir. !--, „f�,-fri Casing Description 0D(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread • -'.4-L.'''.' ' umSURFACE 95/8 8.921 33.0 2,772.5 2,772.4 36.00 J-55 BUTT 2 500 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread .' - `Left in hole 2015* 7 6.276 348.1 6,448.6 5,724.2 26.00 J-55 BTC nnnnn PRODUCTION .M/CONDUCTOR;33.0.110.0.4.M.M''"<v-�"' Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ,:`,50'a" LINER 5 4.151 6,228.5 6,975.0 6,087.1 18.00 S-140 LTC BRIDGE PLUG W/CEMENT . Liner Details CAP;262.0 NominaI ID NA +.gam._ Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) v a '13n 28 6,228.5 5,574 5 47.64 HANGER BAKER LINER HANGER 5.000 ai Tubing Strings pg Tub ng Description Stains Ma...ID(in) Top(ftKB) (Set Depth(ft..f Set Depth(TVD)(.1 Wt(Ib/it) Grade Top Connection SAFETYVLV;1,785.6 ' ! I 'Left In hole`TUBING 2 7/8 2.441 360 01 6,565 9 5,804 9 6.50 J-55 EUE8rdABMOD O. 2.875"02 375 GAS LIFT;2,582.2 `"1 Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 1,785.6 1,785.5 0.23 SAFETY VLV CAMCO TRDP-1A-SSA(LOCKED OUT 9/3/1993) 2.312 6,056.8 5,459.4 48.20 PBR BROWN PER 2.500 6,076.0 5,472.3 48.13 PACKER BROWN HB-1 PACKER 2.750 SURFACE;33.0-2772.5-+ 6,135.6 5,512.1 47.96 SLEEVE-C OTS XA SLIDING SLEEVE(CLOSED 4/2/1995) 2.310 6,154.5 5,524.8 47.91 NIPPLE CAMCO D NIPPLE 2.250 GAS LIFT;4090.0 'i 6,156.4 5,526.0 47.91 XO reducing XO reducing 2.875x2.375,4.708,N-80,1.995 2.375 6,512.0 5,767.8 46.53 BLAST RING CARBIDE BLAST RING 1.995 GAS LIFT;4,958.9 6,550.0 5,793.9 46.54 LOCATOR BAKER LOCATOR 1.995 6,551.0 5,794.6 46.54 PACKER BAKER DB PACKER w5'SEAL BORE EXT. 3.250 GAS LIFT;5.318.8 r '1` 6,563.0 5,802.9 46.54 NIPPLE CAMCO D NIPPLE NO GO 1.812 r� 6,565.3 5,804.5 46.54 SOS CAMCO SHEAR OUT 1.995 GAS LIFT;5,697.2 it Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) s0,t Top(TVD) Top Incl GAS LIFT;6,016.0 -/ Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 262.0 262.0 0.48 BRIDGE Cement Retainer used during squeeze and to put 7/10/2015 0.000 PLUG W/ top/surface cement plug on top of. CEMENT FISH;8,038.0 lel% . CAP PBR;8,056.8 6,038.0 5,446.9 48.27 FISH Lost in hole during Plug&Suspend Operations. 7/3/2015 Unknown location in hole but believed to be beneath ...-.t... bottom of tubing at 6026'. PACKER;0078.0 OAL:32.66,OD is 2.19"for bottom 36"and 1.5 for remainder. GAS LIFT;6,113.6Pli 6555.0 5,797.4 4654. CMT PLUG Pumped 15 bbls of 15.8 ppg Class G cement slurry 12/16/2010 0.000 Perforations&Slots SLEEVE-C;6,135.8 I Shot I Dens rop(TVD) etm(TVD) (shotstt NIPPLE;6,154.5 Top(ftKB) Ben(91G3) (ftKB) (11613) Zone Date t) Type Com 6,524.0 6,539.0 5,776.1 5,786.4 C-4,Unit B, 10/30/1986 12.0 IPERF 3 3/8"HyperJet II;60 i l 2T-07 deg.Ph '.. 6,571.0 6,613.0' 5,808.4' 5,837.3 A-3,21-07 10/30/1986 12.0 IPERF '3 3/8"HyperJet II;60 11! {( jdeg.Ph L 1 Stimulations&Treatments Min Top Max Btet Depth Depth Top(TVD) Ben(TVD) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com 6,524.0 6,613.0 5,776.1 5,837.3 FRAC 10/12/198 PUMP 89,295#16/20 CARBOLITE 8 Cement Squeezes Top(TVD) Btm(TVD) °Len In hole 2015' Top(ftKB) Btm(111(6) (ftKB) (ORB) Des Start Date , Com PRODUCTION;348.1.6,448.86,555.0 6,614.0 5,797.4 5,838.0 Cement Plug 12/16/201 1 0 1,675.0 6,026.0 1,674.9 5,438.9 Cement Plug 7/7/2015 Balanced plug 6026 ft to 1675 ft. IPERF;8,524.0-0.539.0 _ _ Pumped 5 BBLS of Mud flush ahead.PT 1500 psi./ 3500.continue with 10 more BBL5 of mud flush,152 i bbls of G cement W/.2%D046,.3%D065,.4%D167, .015 Gal/sx D177.Displaced with 5 BBIs mud flush,5 bbls 9.4 Brine.Cement in place @ 01:55 hrs.Pump LOCATOR;6,550.0 ®.. Pressure thru job @ 2 BPM @ 250 PSI. .era - PACKER;6,551.0 491.0 1,633.0 491.0 1,632.9 Cement Plug 7/9/2015 Pump balanced cement plug from 1633'to 491'MD. PT lines to 1500/3500 psi.pump 12.1 bbls lead water i 2 bpm @ 210 psi,42 bbls 15.7 ppg Bass"G-AS-1 t/_+°°. cement 3 bpm @ 220 psi,4 bbis chase water 3 bpm NIPPLE;6,583.0 @ 370 psi.Cement in place at 02:33. 264.0 365.0 264.0 365.0 Cement Plug 7/10/2015 Pump 5.0 bbls Fresh Water,Pressure test line at soft 6,565.3below retainer 2,000 psi,Pump 10 bbls Fresh Water,Start retainer squeeze at 2.2 bpm/50 psi WHP.Continue pumping FRAC;6,524.0 cement at 2.2 bpm density,15.78 bl/gal.WHP after CMT PLUG;E555.0. i 55 bbls pumped,125 psi.treating pressure,250 psi. IPERF;8,571.0-6,613.0 No sign of squeezing cement behind the 9 5/8" - -- Casing...just drinking it.Continue mixing and pumping cement.End pumping after 100 bbls away. Final WHP 140 psi,max observed pressure,150 psi., final rate 2.2 bpm,final density,15.78 lb/gal (monitored well cellars on either side of 2T-07 and the reserve pit area in front of the well during pumping for any sign on cement broaching to surface...all good). end.Wash up. LINER;6,228.5-6,975.0 ., KUP PROD 2T-07 ConocOPhillips Alaska,Iflc, corosospennom 2T-07,7/21/2015 3:27:20 PM Ver5cal schematic(actual) Cement Squeezes Top(ND) Btm(TVD) Top(ftKB) Btm(1100) (ftKB) (ftKB) Des Start Dale Com i/ 264.0 365.0 264.0 365.0 Cement Plug 7/10/2015 Pump 5.0 bbls Fresh Water,Pressure test line at A ww (Same as 2,000 psi,Pump 10 bbls Fresh Water,Start retainer ,"✓" �''. squeeze but was squeeze at 2.2 bpm/50 psi WHP.Continue pumping also a plug) cement at 2.2 bpm density,15.78 bl/gal.WHP after 55 bbls pumped,125 psi.treating pressure,250 psi. No sign of squeezing cement behind the 9 5/8" .4s./.,CONDUCTOR;33.0-110.0 tee, Casing...just drinking it.Continue mixing and pumping cement.End pumping after 100 bbls away. BRIDGE PLUG W/CEMENT Final WHP 140 psi,max observed pressure,150 psi., CAP;262.0 final rate 2.2 bpm,final density,15.78 lb/gal y z (monitored well cellars on either side of 2T-07 and the O 5; reserve pit area in front of the well during pumping for .. .•,;:,.,, any sign on cement broaching to surface...all good). 110 end.Wash up. SAFETY VLV;1,785.8 y, ,: 1 34.0 262.0 34.0 262.0 Cement Plug 7/10/2015 Pick-up and sting out of the cement retainer.Bring a cement pump back on line at 2.3 bpm/250 psi treating GAS LIFT;2,5822 r - pressure,40 psi WHP.Cement density 15.8 lb/gal. ":v Saw cement in the retums at 18 bbls away.Continue pumping an additional 2bbls of clean cement. Final sample caught=15.7lb/gal....15:D8hrs ./:, Mandrellnserts St SURFACE;33.0-2,772.5- i. Po ati on Top(ND) Valve Latch Port Size TRO Run GAS LIFT;4,090.0 1. e. N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 2,582.2 2,582.1 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,336.0 10/30/2004 GAS LIFT;4,056.9 2 4,090.0 4,015.0 CAMCO ,KBMG 1 GAS LIFT GLV BK 0.188 1,334.0 10/30/2004 3 4,956.9 4,718.9 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 10/31/1986 GAS LIFT;5,318.61 all 4 5,318.6 4,976.7 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,327.0 10/30/2004 NI GAS LIFT;5,697.2 111,11 5 5,697.2 5,223.0 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 10/31/1986 GAS LIFT;6,016.0 6 6,016.0 5,432.3 MMH HTC 11/2 GAS LIFT OV RK 0.250 0.0 3/4/2006 7 6,113.6 5,497.3 CAMCO KBMG 1 PROD DMY BK 0.000 0.0 10/31/1986 Close l d FISH;6,038.0 lik d Notes:General&Safety PBR;6,056.8 End Date Annotation 2/7/2004 NOTE:HEAVY, ERRATIC PICKUP WEIGHTS SUGGEST CORKSCREW TBG FROM TTL-500' 11/30/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 PACKER;6,076.0 GAS LIFT;6,113.6 SLEEVE-C;6,135.6 it NIPPLE;6,154.5 Mt k Jl i 'Left in hole 2015' PRODUCTION;348.1-6,448.6 IPERF;6,524.0-6,539.0- R i LOCATOR;6,550.0 'ACP-s PACKER;6,551.0 gi NIPPLE;6,563.0 45 111 SOS;6,565.3 iv FRAC;6,524.0 CMT PLUG;6,555.0 WO -- IPERF;6,571.0-6,613B -. I I LINER;6,228.5-6,975.0 ConocoPhillips Time Log & Summary Wel/view Web Reporting Report Well Name: 2T-07 Rig Name: NABORS 7ES Job Type: RECOMPLETION Rig Accept: 6/7/2015 3:30:00 AM Rig Release: 7/11/2015 6:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 36/04/2015 24 hr summary DEMOB rig for move to 2T pad 22:00 00:00 2.00 MIRU MOVE MOB P Began DeMob rig for move to 2T pad 06/05/2015 MOb rig and equipment to 2T pad from 1L pad 00:00 06:00 6.00 MIRU MOVE MOB P Continue to De-MOB rig support equipment off 1L pad. 06:00 15:00 9.00 MIRU MOVE WAIT T Unable to move Camp, Shop, and Pits...Sows still tied up with setting up Doyon 25 on 1-Y Pad. (Can not move the Rig until the Pit module is pull away from the Sub Base). Continue to wait on Trucks. However, continue to move miscellaneous equipment to 2T-Pad with KDTH trucks. 15:00 00:00 9.00 MIRU MOVE MOB P Sows arrive on location. Resume de-mob rig support equipment. 06/06/2015 Continue to Mob equipment to 2T pad. MIRU. 00:00 16:00 16.00 MIRU MOVE MOB P Continue to MOB rig to 2T pad. Plts, Shop, Office on pad @ 04:00 hrs. Rig on pad @ 16:00 hrs 16:00 00:00 8.00 MIRU MOVE MOB P Set mats and move rig over well. Continue to RU equipment. Spot KIII and Open Top Tanks. Lay hardline. 06/07/2015 Continue to MIRU. Rig accepted©03:30 hrs Pulled BPV. RU&Test kill lines.Kill well with 9.4 Brine Revese. Set BPV. ND tree. NU BOPE 00:00 08:00 8.00 MIRU MOVE RURD P Continue to MIRU equipment and lines.Take on 9.8#KWF(Brine) Rig Accepted©03:30 Hrs. Continue to fill Pits. Review pre-well work check list. 08:00 09:00 1.00 MIRU WELCTL MPSP P Pick-up Lubricator. Pull BPV. Lay down same. Tbg=50 psi, IA up 0 psi, OA=50 psi. 09:00 09:30 0.50 MIRU WELCTL SFTY P PJSM. Review well kill operations and the hazzards assoated with same. Page 1 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:30 12:00 2.50 MIRU WELCTL KLWL P Pressure test hardline at 250/2,500 psi. Reverse circulate with 9.4 lb/gal Brine at 2.0 bpm/680 psi. Increase rate to 3.0 bpm/1,300 psi. Reduce rate to 2.5 bpm/1,060 psi. Pumped a total of 350 bbls to get the well cleaned up. Returns=—98%9.4 lb/gal Brine and—2%milky interface on top of the sample. Total bbls recovered=340 bbls. Blow down lines. 12:00 12:30 0.50 MIRU WELCTL OWFF T Monitor Well. Well out of balance. IA on vacuumn. Tubing flowing a solid stream out the sample port valve. 12:30 13:00 0.50 MIRU WELCTL RURD T Swap circulating manifold around to pump down the tubing. Tubing pressure went up to 650 psi in 5 pump strokes. Double check valve alignment. Good. Unable to pump down the tubing(confirm LRS fiindings...see the Pre-RWO entry dated 02/09/2015...Confirm that the GLM 6,016-ft has a check valve in the pocket...IA to Tbg). Swap valves around again. 13:00 14:00 1.00 MIRU WELCTL KLWL T Reverse circulate 55 bbls of 9.4 lb/gal Brine back to the Pits at 1.5 bpm/340 psi. Note...OA pressure remains at 50 psi during pumping. 14:00 15:30 1.50 MIRU WELCTL OWFF P Shut in well and allow pressure to drop. Open Well. Tubing=0 psi. IA=0 psi. Monitor well static. However, after 5 minutes the IA started slight flow then stopped. IA then started to dribble and never stopped. 15:30 16:00 0.50 MIRU WELCTL KLWL P Reverse circulate in with 25 bbls of 9.4 lb/gal Brine at 1.0 bpm/168 psi. 16:00 17:00 1.00 MIRU WELCTL OWFF P Shut in well and allow pressure to drop. Open well. Tubing=0 psi. IA =0 psi. Monitor well static x 30 minutes. 17:00 17:30 0.50 MIRU WHDBO MPSP P Install BPV and test dart. 17:30 19:30 2.00 MIRU WHDBO NUND P ND tree and adaptor. 19:30 00:00 4.50 MIRU WHDBO NUND P NU BOPE and adjust in cellar due to well head lean. 06/08/2015 Test BOPE 250/2500. Grew tbg. 18"pick up to string weight 4.5 ft.space out tbg.to rig floor. RU Eline. Attempt to get tools thru tight spot @ 350 ft with out success. 00:00 01:30 1.50 MIRU WHDBO RURD P Continue to rig up lines for BOPE test. Page 2 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:30 08:30 7.00 MIRU WHDBO BOPE P Test BOPE 250/2500 psi. .Test Waived By John Crisp AOGCC. Test: 1) LPR W/2 7/8 TJ. TD HCR. Pass 2) UPR W/2 7/8 TJ, Choke 1,2,3,16, RFkill,TD Man. Pass 3)Choke,5,6, HCR kill, HT-38 FOSV Pass 4)Choke 7,8,9, Man kill. Pass 5)Super choke, Man Choke Pass. 6)Choke 10,11, Pass 7)Annular, Choke 12,13 Pass. 8)BR, HCR choke, HT-38 Dart. Pass 9)Man choke. Pass 10)Annular W/3.5 TJ, Choke 15, 3.5 EUE 8rd FOSV. pass 11) UPR,W/3.5 TJ. Choke 14, Inner test spool. Pass. BPR, Outer test spool. Pass. Draw down. Pass. Nitrogen 5@ 1975 PSI. 08:30 09:30 1.00 MIRU WHDBO RURD P Rig down BOP test equipment. Blow down Choke Manifolds. Lay down test joint. Pump out Stack. Clear Rig Floor. 09:30 10:30 1.00 MIRU WHDBO MPSP P Pull BPV and lay down same. 10:30 10:45 0.25 COMPZ RPCOM SFTY P PJSM. Discuss BOLDS and unseating the tubing Hanger and the hazards associated with same. 10:45 11:30 0.75 COMPZ RPCOM RURD P Pick up 3 1/2"Space-out drill pipe pup joint assembly. Screw into the Tubing Hanger. Make up the Top Drive. BOLDS. 11:30 12:30 1.00 6 6 COMPZ RPCOM PULL P Slowly pick up Top Drive. Tubing Hanger"un-seated"itself and grew 18"from compression. Pick up an additional 5-ft to—string weight. Total hanging weight=55K including Blocks. Set slips. 12:30 14:00 1.50 6 6 COMPZ RPCOM FLOG P Ready floor for E-Line ops. Spot HES Logging Unit. Off-load Lubricator sections. 14:00 14:15 0.25 6 6 COMPZ RPCOM SFTY P PJSM. Rigging up E-Line Lubricator _and Tool String. 14:15 16:30 2.25 6 6 COMPZ RPCOM FLOG P Install Wireline BOPS. Build Lubricator sections including Grease Head. Make-up Tool String as follows: Cable Head,Weight Bar, Weight Bar, Knuckle Roller,Weight Bar, Knuckle Roller, CCL,Wight Bar. Max OD= 1.69". Total Length= 27.94-ft. Cable Head fish neck OD= 1.375". Page 3 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:30 17:00 0.50 6 6 COMPZ RPCOM SEQP P Pick-up Tool String and stab Lubricator. Attempt to pressure test Lubricator. However, have connection leak. Replace"0"ring. Pressure test at 1,000 psi. 17:00 18:30 1.50 6 COMPZ RPCOM SFTY P Held Safety Recognition dinner for both crew 18:30 20:00 1.50 COMPZ RPCOM ELOG P RIH with 1 11/16 tool string unable to get past 350 ft. POOH and re-head for 1"tool assembly. RIH with 1"assembly with 1 7/16 XO on bottom. Stopped @ 350 ft. POOH took off the XO. RIH stopped © same. 20:00 20:30 0.50 COMPZ RPCOM WAIT X Discussed with Town on path forward 20:30 23:30 3.00 COMPZ RPCOM WAIT X Wait on 2 25"Jet cutter and gauge ring 23:30 00:00 0.50 COMPZ RPCOM ELNE X Attempted to drift with 2.25 gauge with out success. hanging up at surafce. 06/09/2015 Cut Tubing at 300+/-ft.with jet cutter. PU BHA#1 (Rope Spear)and pull control line from hole. PU and RIH with RBP. Set RBP and dump sand on top. Nipple DOwn BOPE. 00:00 01:00 1.00 COMPZ RPCOM WAIT X Wait on 2 1/8 gauge and cutter. 01:00 02:00 1.00 COMPZ RPCOM ELNE X RIH with 2 1/8"Gauge to 345 ft. POOH 02:00 04:00 2.00 COMPZ RPCOM WAIT X wait on 2 1/8 jet cutter from Dead Horse. 04:00 05:00 1.00 COMPZ RPCOM ELNE P PJSM Make up 2 1/8"jet cutter. RIH. Cut tbg @ 310 ft. POOH. 05:00 07:00 2.00 COMPZ RPCOM ELNE P Rig down E-Line Unit and place on stand-by. 07:00 08:30 1.50 COMPZ RPCOM RURD P Rig up GBR equipment to handle 2 7/8"Tubing. 08:30 10:00 1.50 310 0 COMPZ RPCOM PULL P Single down 2 7/8"Jet Cut Tubing. Recovered Tubing Hanger Assembly, 2 ea Pup Joints, 8 full joints of Tubing, and a Jet Cut Stub(3 7/8" OD flare). Total length 286-ft TT. Cut depth 314-ft ORKB. Control Line appears to be not severed. No recovery. However, still have the top end of the Control Line at surface. 10:00 11:00 1.00 0 0 COMPZ RPCOM RURD P Rig down GBR equipment. Clean floor. 11:00 11:30 0.50 0 0 COMPZ RPCOM SVRG P Inspect Top Drive. Inspect Drawworks. 11:30 12:30 1.00 0 0 COMPZ RPCOM RURD P Rig up to handle 3 1/2"Drill Pipe. Tally 10 joints of 3 1/2"Drill Pipe. 12:30 14:00 1.50 0 0 COMPZ RPCOM BHAH P Off-load Fishing Tools. Make-up BHA#1...Rope Spear. 14:00 19:30 5.50 0 0 COMPZ RPCOM PULL P Pull Control Line. Work Rope Spear and eventually Lay Down same. Retrieved— 1750'of control line (measured by weight). 19:30 20:00 0.50 0 14 PROD1 WELLPF BHAH P Pick Up Retrievable Bridge Plug. Page 4 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 20:30 0.50 14 256 PROD1 WELLPF PULD P Single in hole with Drill Pipe. 20:30 21:00 0.50 256 256 PROD1 WELLPF MPSP P Set RBP at 256'dpmd(center of element). 21:00 21:30 0.50 256 0 PROD1 WELLPF TRIP P Trip out o f hole. 21:30 22:00 0.50 0 0 PROD1 WELLPF MPSP P Test RBP to 1000 psi for 10 minutes. charted. 22:00 22:30 0.50 0 99 PROD1 WELLPF TRIP P Pick Up Muleshoe and Trip in hole. 22:30 23:15 0.75 99 99 PROD1 WELLPF MPSP P Dump 15 bags of sand on RBP. 23:15 00:00 0.75 99 0 PROD1 WELLPF TRIP P Trip in and tag top of sand at 226' dpmd.Trip out of hole. 06/10/2015 Grow Casing. Spear and Stretch Casing. NU BOPE. Test Breaks. PU and RIH with RBP Retrieval Tool (cleanout sand retrieve RBP). TOOH and LD RBP and retrieval tool. 00:00 01:00 1.00 0 0 PROD1 CSGRC'NUND P Nipple Down BOP Stack and stand back on pedestal. 01:00 03:30 2.50 0 0 PROD1 CSGRC'RURD P Rig Up Hydratight Break bolts. Some bolts too corroded to break. Cut bolts off with torch. 03:30 03:45 0.25 0 0 PROD1 CSGRC'SFTY P PJSM with all hands involved in growing casing in the cellar. 03:45 05:45 2.00 0 0 PROD1 CSGRC'CUTP P Grow Casing using Hydratight to control casing growth. Total Growth:23-5/8" 05:45 06:15 0.50 0 0 PROD1 CSGRC'RURD P Rig Down Hydratight from wellhead. 06:15 07:00 0.75 0 0 PROD1 CSGRC'NUND P Remove the Tubing Spool with some difficulty. 07:00 07:30 0.50 0 0 PROD1 CSGRC'BHAH P Make-up 5 3/4"ITCO Casing Spear w/6.220"Grapple. 07:30 08:30 1.00 0 0 PROD1 CSGRC'CUTP P Spear Casing. Pull up to 50K over. Set back down on Slips(the old ones). Release and set back spear. 08:30 10:15 1.75 0 0 PROD1 CSGRC'CUTP P Rig up Wachs Cutter. Cut off and dress the 7"Casing. Rig down same. 10:15 15:30 5.25 0 0 PROD1 CSGRC'NUND P Install the Primary Pack-off Bushing (with difficulty due to crooked Wellhead). Install secondary Pack-Off. Nipple up Tubing Spool. 15:30 17:30 2.00 0 0 PROD1 CSGRC'WWSP P Pressure test the Primary Pack-Off at 250/2,500 psi. Pressure test the Secondary Pack-Off at 250/3,000 psi. Had to pack the void area with plastic sealant to get the tests. Once again this is because the Well head is crocked and the Casing can not center itself due to a slight "buckle" just below surface. 17:30 20:00 2.50 0 0 PROD1 CSGRC'NUND P Nipple Up BOP Stack and riser. 20:00 21:00 1.00 0 0 PROD1 CSGRC'BOPE P Test break in stack to 250/2500 psi. Charted. 21:00 22:00 1.00 0 200 PROD1 WELLPF TRIP P Pick Up retrieving tool and TIH. 22:00 22:45 0.75 200 256 PROD1 WELLPF CIRC P Clean sand off top of RBP 12 bpm @ 260 psi. Page 5 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:45 23:00 0.25 256 256 PROD1 WELLPF MPSP P Retrieve RBP per Baker Hughes Rep. 23:00 23:30 0.50 256 21 PROD1 WELLPF TRIP P TOOH with RBP and Retrieval Tool. 23:30 00:00 0.50 21 0 PROD1 WELLPF BHAH P Lay Down RBP and Retrieving Tool. 06/11/2015 PU and TIH BHA#3(Tubing Dressoff). Dressoff Tubing Stub. TOOH and LD BHA#3. PU and TIH with BHA#4 (Overshot). Engage tubing stub. Rig Up E-Line. E-Line cannot drift. Rig Down E-Line.Attempt to pull seals. tubing string parted. TOOH and LD cut joint and 1 full joint. TIH with BHA#4.Attempt to drift 7"casing to tubing stub.TOOH and LD BHA#4. 00:00 00:15 0.25 0 7 PROD1 WELLPF BHAH P Pick Up BHA#3(Tubing Dressoff Shoe) 00:15 00:45 0.50 7 310 PROD1 WELLPF TRIP P Trip in with BHA#3. Establish Parameters. Up/Dn/Rot Wt=32k. 35 RPM.Tq Off 600 ft lbs. 3 bpm @ 60 psi. 00:45 01:30 0.75 310 312 PROD1 WELLPF MILL P Dressoff Tubing Stub. 40 rpm,Tq on =900 ft lbs, 3 bpm=60 psi. 1k WOM. Tubing stub @ 312'dpmd. 01:30 02:00 0.50 312 7 PROD1 WELLPF TRIP P Trip out of hole with BHA#3. 02:00 02:30 0.50 7 0 PROD1 WELLPF BHAH P Lay Down BHA#3 Components. 02:30 03:00 0.50 0 0 PROD1 WELLPF SVRG P Inspect and Service Top Drive. 03:00 03:45 0.75 0 28 PROD1 WELLPF BHAH P Pick Up BHA#4(2-7/8"Overshot w/ Grapple) 03:45 04:15 0.50 28 300 PROD1 WELLPF TRIP P Trip in hole with BHA#4. 04:15 04:45 0.50 300 312 PROD1 WELLPF FISH P Engage Top of tubing stub with Overshot. Up Wt=32k Dn Wt=32k. Pull up and set in slips at 60k(28k over string weight prior to engaging stub). 04:45 06:00 1.25 312 312 PROD1 WELLPF ELNE P Spot E-Line Unit outside rig. Prepare rig floor for E-Line work. 06:00 09:00 3.00 312 312 PROD1 WELLPF ELNE P Rig up E-line equipment, lubricator with grease head. Make-up Tool String. 09:00 09:15. 0.25 312 312 PROD1 WELLPF ELNE P Pressure test Lubricator at 1,000 psi. Good. 09:15 09:45 0.50 312 312 PROD1 WELLPF ELNE P Run in with the 1 11/16" Drift Assembly Set down at 350-ft. Repeat with the same results. Pull out of the hole. 09:45 11:15 1.50 312 312 PROD1 WELLPF ELNE P Prep for the next attempt. Swap over to 1" Running gear and pick up the 1 3/8"Drift Assembly. 11:15 11:45 0.50 312 312 PROD1 WELLPF ELNE P Run in with the 1 3/8" Drift Assembly... Set down at 350-ft. Repeat with the same results. Pull out of the hole. 11:45 12:00 0.25 312 312 PROD1 WELLPF ELNE P Prep for the next attempt. 1"Split Shot Dummy Drift Assembly.... Set down at 350-ft. Repeat with same results. Pull out of the hole. Notify the Anchorage Engineer. 12:00 13:30 1.50 312 312 PROD1 WELLPF ELNE P Rig down and release HES E-Line Unit. Clear Floor. Page 6 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 14:00 0.50 312 312 PROD1 WELLPF PRTS P Pressure test the pack-off on the Baker Overshot at 750 psi. Good. 14:00 15:00 1.00 312 312 PROD1 WELLPF CIRC P Reverse circulate tubing volume through the 48/64"Orifice Valve in the GLM at 6,016-ft. Rates=2.0 bpm/200 psi, 3.0 bpm/376 psi..4.0 bpm/545 psi. Blow down lines. 15:00 18:30 3.50 312 312 PROD1 WELLPF WAIT P Secure Well. Waiting on orders from Anchorage Engineering Team. (SIMOPS...Maintain Rig...miscellaneous small maintenance project and cleaning rig). 18:30 20:00 1.50 312 356 PROD1 WELLPF FISH P Pull to 80%of tubing strength to attempt to pull seals. Seal will not pull free. Use pull and Hydraulic force,seals will not pull free. Contact CPAI Engineer, decision to go to 90%pull. Pull to 90%once, not movement. On second pull to 90% observed indications of string parting as 90%was reached(122k). Up Wt —34k after parting.Attempt to go down,string goes past previous bottom indicating part going past upward looking part. 20:00 20:30 0.50 356 72 PROD1 WELLPF TRIP P TOOH with BHA#4 and fish. 20:30 21:00 0.50 72 0 PROD1 WELLPF PULL P Lay Down cut joint(14.10')and 1 full piece of 2-7/8"tubing. String came apart when threads on pin end pulled free from collar. 21:00 21:30 0.50 0 343 PROD1 WELLPF TRIP P Trip in hole with BHA#4 again to test drift damage area at—350'. Observe BHA Overshot stack out at 342.5' dpmd. 21:30 22:00 0.50 343 28 PROD1 WELLPF TRIP P Trip out of hole with BHA#4. Contact CPAI Engineer,discuss plan forward. Decision to run various OD BHAs to determine restrictions and damage of 7"casing. Mobilize Baker fishing tools from Deadhorse. Order 3.5" L-80 EUE8rd tubing for use from warehouse. 22:00 22:30 0.50 28 0 PROD1 WELLPF BHAH P Lay Down BHA#4. 22:30 23:00 0.50 0 352 PROD1 WELLPF TRIP P Pick Up Muleshoe and Trip in hole. Observe string stack out with Muleshoe at 351.5'dpmd observing string rotate right slightly in final 5-10 feet of movement. Pick up without problem. Set back down and observe string stack out—347.5'dpmd. Pick up and rotate string left 1/4 turn and then slack off and observe string stack out at 351.5'dpmd again observing a slight right rotation in final 5 feet of travel. Page 7 of 67 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 23:00 23:30 0.50 352 0 PROD1 WELLPF TRIP P Trip out of hole with Muleshoe. 23:30 00:00 0.50 0 0 PROD1 WELLPF WAIT P Wait on Baker fishing tools and 3.5" EUE8rd tubing to arrive for next BHA. 36/12/2015 PU and TIH with BHA#5(Overshot and 3.5 EUE8rd joint drift).Attempt to drift 7"casing to tubing stub. TOOH and LD BHA#5. Rig Up for E-Line. Run Caliper Log with E-Line. RUn Impression Blocks with E-Line. 00:00 01:30 1.50 0 0 PROD1 WELLPF WAIT P Wait on Baker fishing tools and 3.5" EUE8rd tubing to arrive for next BHA. 01:30 03:00 1.50 0 38 PROD1 WELLPF BHAH P Process joint of 3.5" EUE8rd tubing for BHA and pick Up BHA#5. Overall length 38.3'. 03:00 03:30 0.50 38 351 PROD1 WELLPF TRIP P Trip in Hole with BHA#5. Observe Overshot stack out at 351'dpmd. Pull up and try again, stack out 3' higher, turn slightly and observe string stack out at 351'dpmd again with 7k down. 03:30 04:00 0.50 351 0 PROD1 WELLPF TRIP P Trip out of hole with BHA#5. Lay Down BHA#5 in 1 piece in pipe shed. 04:00 06:00 2.00 0 0 PROD1 WELLPF ELOG P Rig Up Dutch Riser in preparation for E-Line Operations. E-Line Mobilized to location. 06:00 10:30 4.50 0 0 PROD1 WELLPF ELOG P (Divert the E-Line Unit from other scheduled work).. Move in and spot HES E-Line Unit. Gather lubricator sections and load in Pipe Shed. Bring sheaves to floor. 10:30 10:45 0.25 0 0 PROD1 WELLPF SFTY P PJSM. Discuss the hazards associated with rigging up Lubricator sections, Grease Head, and the Tool String. 10:45 11:45 1.00 0 0 PROD1 WELLPF ELOG P Rig up E-Line. Make-up Lubricator. Re-head line, Make-up tool string. 11:45 12:15 0.50 0 0 PROD1 WELLPF ELOG P Pressure test Lubricator at 1,000 psi. Good. 12:15 14:00 1.75 0 0 PROD1 WELLPF ELOG P Run in with a 24-Arm Caliper Tool. Set down at 352-ft(pick-up depth). Log up for the initial pass. Observe the"peak"of the suspected collapse at 346-ft. Drop back down to 352-ft. Attempt to log up to record the main pass to surface. However, some of the arms were reading"small". Pull out. 14:00 15:00 1.00 0 0 PROD1 WELLPF ELOG P Inspect Caliper Tool. Had some tiny pieces of grit behind a couple of arms. Change out Caliper. 15:00 16:30 1.50 0 0 PROD1 WELLPF ELOG P Run back in. Set down at 352-ft. Record a 24-Arm Caliper log to surface. Good. Drop back down to 352-ft and record a repeat pass back to surface. Down load Logs and send to town for review. 16:30 17:30 1.00 0 0 PROD1 WELLPF ELOG P Lay down Caliper Tool String. Re-configure tool string to run different sizes of Impression Blocks. Page 8 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:30 20:30 3.00 0 0 PROD1 WELLPF ELNE P Run Impression Blocks(All tag runs at—348'wlmd):4.11"(inconclusive, pictures taken); 3.88"(inconclusive, pictures taken); 3.00"(inconclusive, pictures taken). Contact CPAI engineer. Decision to stand back E-Line, next operation will be downhole video. 20:30 21:30 1.00 0 0 PROD1 WELLPF WWWH P Wash BOP Stack and wellhead in preparation for Swapping to filtered Brine and Downhole video E-Line work. 21:30 22:00 0.50 0 0 PROD1 WELLPF SVRG P Service and Inspect Top Drive. 22:00 00:00 2.00 0 0 PROD1 WELLPF WAIT P Wait on EV video(being mobilized from Kenai)for downhole camera run with E-Line. Process 1"work string joints.Work on Rig Maintenance Projects. 06/13/2015 Circulate well above casing damage to filtered Brine. Run Downhole Video with E-Line(3 runs). 00:00 06:00 6.00 0 0 PROD1 WELLPF WAIT P iWait on EV video(being mobilized from Kenai)for downhole camera run with E-Line.Work on Rig Maintenance Projects. 06:00 09:00 3.00 0 0 PROD1 WELLPF WAIT T 'Continue to wait on Filtered Brine. Continue to wait on EV Video Service Rep from Kenai. Discuss and fine tune the plan forward with Anchorage Engineer. Filtered Brine arrives on location. Grab several samples...reject as the Brine is not "camera quality". Peak Vac Tuck from Kuparuk was not properly cleaned enough even though"they" said it was. Order out an ad hoc Vac Truck from Peak in Deadhorse. Have Vac Truck washed in Peak's washday. Then go to MI to receive filtered 9.4 lb/gal Brine. 09:00 09:45 0.75 0 42 PROD1 WELLPF BHAH P Make-up BHA#6 as follows: 1"CS Mule Shoe(1 5/16"OD), 1 jt of 1" CS Hydril Tubing(1 5/16"OD), 5 ea XOs to get back to drill pipe thread. 09:45 10:15 0.50 42 351 PROD1 WELLPF TRIP P Trip in BHA#6 with 3 1/2"Drill Pipe from the Derrick. Set down at 351-ft dpmd. However the Drill Pipe "chattered"with 1K down weight from 349-ft to set down weight. 10:15 11:00 0.75 352 351 PROD1 WELLPF FISH P Worked the 1"Mule Shoe Stinger Joint to 352-ft dpmd after several attempts(1/4 turn rotations and light weight bobbles). However, if we have to work to get the 1 5/16"Stinger down...the video camera being a larger OD and hanging on the end of E-Line has very little chance to get past the 7"Casing damage. Page 9 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 12:00 1.00 351 351 PROD1 WELLPF CIRC P Park the Mule Shoe at 351-ft dpmd. Circulate the Well with the rejected "camera quality".9.4 lb/gal Brine at 3.0 bpm/380 psi to help clean up the Well until cleaner Brine arrives. SIMOPS...E-line Crew arrives on location. Re-head line. Continue to wait on EV Camera Rep and cleaner filtered Brine. volume pumped= 150 bbls. 12:00 12:30 0.50 351 42 PROD1 WELLPF TRIP P Trip out standing back 3 1/2"Drill Pipe in the Derrick 12:30 12:45 0.25 42 0 PROD1 WELLPF PULD P Lay down the CS Hydril Stinger Assembly. 12:45 13:30 0.75 0 347 PROD1 WELLPF TRIP P Trip back in with 3 1/2"Drill Pipe with a Mule Shoe on the end to 350-ft. Pull up and space out for camera window to 347-ft. 13:30 14:00 0.50 347 347 PROD1 WELLPF SFTY P Spill Drill in the Cellar. PJSM with all to discuss rigging up E-Line and the hazards associated with. 14:00 16:15 2.25 347 347 PROD1 WELLPF ELOG P Prep video camera equipment. Rig up E-Line equipment and Lubricator. 16:15 19:30 3.25 347 347 PROD1 WELLPF FLOG P Run in hole with EV Down Hole Video Camera. Lens picked up a "blob". Set down on top of the 7" obstruction. It appears that the camera is trying to enter the obstruction and then the screen blacks out as it get pinched off to the side. Pull out to clean lens. Wait on more filtered Brine. (SIMOPS...Weekly SLT Meeting). 19:30 23:00 3.50 347 347 PROD1 WELLPF FLOG P E-Line Downhole camera Run#2. Circulate well with filtered 9.4 ppg Brine. RIH and see collar @ 346' wlmd. Observe significant deformationb/collapse of 7"casing at 346.8'wlmd. Pictures and video taken and emailed to CPAI engineer. Decision to attempt to move muleshoe past damage and run video again. Set E-Line to side. 23:00 23:15 0.25 347 351 PROD1 WELLPF TRIP P Slack off on string and observe muleshoe slide down to 351'dpmd. 23:15 00:00 0.75 351 351 PROD1 WELLPF ELOG P Rig E-Line back up and RIH withDownhole Camera run#3. Circulate with Filtered 9.4 ppg Brine. Run camera to end of muleshoe and observe side of casing. Due to deviation of string(6.5+degrees)and the orientation of casing relative to string the camera cannot make it out of the muleshoe. 06/14/2015 RIH with 2-7/8"muleshoe. POOH with 2-7/8"muleshoe. Muleshoe bent due to sideloading.Wait on orders. Page 10 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:15 0.25 351 351 PROD1 WELLPF FLOG P Complete Downhole video run#3 with muleshoe at 351'. POOH. Contact CPAI Engineer. Decision to changeout muleshoe on end of drill string and try camera again in morning after E-Line crew returns. E-Line Crew timing out for day. 00:15 01:00 0.75 351 351 PROD1 WELLPF ELOG P Rig E-Line down(off to side)and rig down Downhole camera. Mobilize Filtered Brine truck to Deadhorse for 200 bbls of additional filtered Brine. 01:00 01:30 0.50 351 0 PROD1 WELLPF TRIP P Trip out of hole with muleshoe and lay down same. 01:30 02:00 0.50 0 0 PROD1 WELLPF SVRG P Service Rig: Top Drive, Drawworks. 02:00 11:00 9.00 0 0 PROD1 WELLPF WAIT P Wait on E-Line Crew to come back on tour after rest.Wait on More Filtered Brine from Mud Plant. Get 2-7/8"muleshoe ready for next Downhole Video Run. 11:00 11:45 0.75 0 350 PROD1 WELLPF TRIP P Resume operations. Vac Truck on location with filtered 9.4 lb/gal Brine. Trip in with a 2 7/8" Mule Shoe Pup Joints(10-ft and a 4-ft)x 3 1/2"Drill Pipe from the derrick. Set down at 350-ft dpmd. 11:45 12:00 0.25 350 358 PROD1 WELLPF FISH P Worked the 2 7/8"Mule Shoe into the 7"Casing damaged top. Continue to work down with 3K-5K bobbles to 354-ft dpmd. Pull back out to 351-ft. Smooth, no drag. Continue down to 358-ft dpmd. (Calculated top of the 2 7/8"Tubing Collar—359'-360'). 12:00 13:00 1.00 358 0 PROD1 WELLPF TRIP P Trip out and stand back Drill Pipe. As expected the 10-ft Mule Shoe Pup Joint was severely bowed from side-loading. The tip of the Mules Shoe was permanently bent 12 inches out starting from 7-ft up down to the tip of the Mule Shoe. Drift the bent 2 7/8"Mule Shoe Pup Joint with a 5-ft Weight Bar..."No-Go". Send pictures to the Anchorage Engineering Team and discuss a plan forward. 13:00 21:30 8.50 0 0 PROD1 WELLPF WAIT P Wait on orders for plan ahead.After Discussion with CPAI Engineers release EV Video,filtered Brine truck and E-Line crew(due to E-Line job in morning in Alpine). Schedule new E-Line crew out at 2pm after BOPE Test. 21:30 23:30 2.00 0 0 PROD1 WELLPF WAIT T Wait on BOPE test. Continue Rig Maintenance. 23:30 00:00 0.50 0 0 PROD1 WELLPF SVRG P Service Top Drive and do Daily Inspection. Page 11 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/15/2015 24 hr Summary Test 7"Casing integrity with pressure test. BOPE test.Test with 2-7/8"and 3-1/2"test joints.All test PASS except Annular. Test witness by AOGCC Representative Jeff Jones. Change Out Annular element. 00:00 04:00 4.00 0 0 PROD1 WELLPF WAIT T Wait on BOPE test. Continue Rig Maintenance. 04:00 05:00 1.00 0 0 PROD1 WELLPF PRTS P Pressure Test 7"casing to confirm integrity.With OA monitored pressured up on 7"casing, as pressure built on 7"to 550 psi OA pressure built to same level at same time. Bled pressure off 7"casing from 500 psi and pressure bled off OA at same time. Pressure on the OA was then bled from—60 psi to 20 psi.Attempt to pressure test again with OA open and monitored. No pressure built on 7"casing, OA was then shut in and monitored and pressure starts to build on both 7" casing and OA gauge up to 500 psi. Shut off pumps and monitor pressure. 7"bleeds down to 150 psi over 4 minutes with OA pressure tracking exact same. Indications of communication between OA and 7". Bleed all pressure off and suspend pressure test attempt. 05:00 10:00 5.00 0 0 PROD1 WELLPF WAIT T Wait on BOPE test. Continue Rig Maintenance. SIMOPS: Contact CPAI Engineer with information about observed communication from 7"to OA. 10:00 16:00 6.00 0 0 PROD1 WHDBO BOPE P Perform the weekly BOPE test as per ConocoPhillips/AOGCC requirements at 250/2,500 psi with a 3 1/2"and 2 7/8"Test Joints. Test Gas Alarms. Perform the Koomey draw down test. All tests were witnessed by AOGCC Field Inspector,J. Jones. Note: The Annular Element failed with the 2 7/8"test joint after several attempts...both low and high pressure tests. 16:00 20:00 4.00 0 0 PROD1 WHDBO RURD T Rig Down and Blow Down Test Equipment. Remove Riser and bolts for Dutch Riser and Set to side. 20:00 00:00 4.00 0 0 PROD1 WHDBO RGRP T Work on getting top of Annular cover off.The top came partially unscrewed and stopped. It was able to move back towards the closed position initially(screwing the cap on)and then was stuck going both directions.Attempt to contact Hydril support Engineer. 06/16/2015 Remove Broken Annular. Get New Annular Element. Lift New Annular to area behind Rig. Move New Annular to Cellar. Page 12 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 0 0 PROD1 WHDBO RGRP T Work on getting top of Annular off to replace element. Contact Hydril Support for options to remove. Continue to try and work free.After exhausting every option contact CPAI Engineer to discuss Annular. 06:00 18:00 12.00 0 0 PROD1 WHDBO RGRP T Contact CPAI Engineer discuss Mill BHA options. Contact CPAI Drilling Leadership on plan forward. Decision to mobilize new annular to location and organize crane pick. Meet with Pad operator on crane pick. Mobilize Crane Operator to pad to discuss crane pick for Annular. Meet with the crane operators. Discuss plan forward with the crane personnel, pad operator and safety engineer from CPF2.Write up a Picking Plan. 18:00 21:00 3.00 0 0 PROD1 WHDBO RGRP T New Hydril Annular arrived on location at 1800 HRS.Attempt to obtain signatures form CPF2 1st Line supervisor, and safety specialist on Crane picking plan. Continue prep rear of cellar area, and reserve pit with matting boards for setting the Hydril. Get picking plan signed off by all necessary personnel. Mobilize crane to 2T pad. Contact Pad operator to mobilize to pad for pick. Prepare Annular for crane pick. 21:00 21:30 0.50 0 0 PROD1 WHDBO SFTY T Pre Job Safety meeting with all rig personnel, crane operator, pad operator, etc. Double check all paperwork and adjust pick parameters to weight of annular (12.5k). 21:30 22:30 1.00 0 0 PROD1 WHDBO RGRP T Pick Annular from far side of pad and land on inside of flow lines in middle of alley between flowlines. 22:30 00:00 1.50 0 0 PROD1 WHDBO RGRP T Pull annular under remaining flow lines to base of back of rig(to edge of cellar). 06/17/2015 Put New Annular Element on stack and Nipple Up BOPE.Test 3-1/2"and 2-7/8"test joints on Annular. PASS; BOPE test complete. PU and RIH w/BHA#8(Carbide Bullnose)and mill. TOOH and LD BHA#8. PU and RIH w/Muleshoe. Rig Up E-Line. RIH and take pictures of milling. TOOH. PU and RIH BHA#8 for a second run.TOOH and LD BHA#8. PU and RIH with BullNose. RIH w/E-Line and take pictures. 00:00 01:30 1.50 0 0 PROD1 WHDBO RGRP T Pull New Annular into cellar and place into lift ring. 01:30 05:30 4.00 0 0 PROD1 WHDBO NUND T Nipple Up New Annular to BOP Stack. Nipple Up Air Boot and Riser. 05:30 07:30 2.00 0 0 PROD1 WHDBO RURD T Fill stack with water and rig up test equipment. 07:30 10:30 3.00 0 0 PROD1 WHDBO BOPE T Test Annular with 3-1/2"and 2-7/8" test joint.Tests pass. Charts reviewed by Lou Grimaldi and rig approved to continue work on well. Page 13 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:30 11:00 0.50 0 0 PROD1 WHDBO RURD P Rig Down Test Equipment. 11:00 11:30 0.50 0 0 PROD1 WELLPF BHAH X Make Up Bullnose Milling BHA per Baker Rep. 11:30 12:00 0.50 0 348 PROD1 WELLPF TRIP X Trip in hole to 348'dpmd. 12:00 13:00 1.00 348 348 PROD1 WELLPF MILL X Time Mill 1"at 3 bpm, 50 psi,40 rpm,TQ 1100-1300. 13:00 13:45 0.75 348 0 PROD1 WELLPF TRIP X Trip out of hole with Milling Assembly 13:45 14:15 0.50 0 0 PROD1 WELLPF BHAH X Lay Down Bullnose Milling Assembly and Pick Up Muleshoe. 14:15 15:30 1.25 0 346 PROD1 WELLPF TRIP X Trip in hole and place Muleshoe at 346'. 15:30 18:00 2.50 346 346 PROD1 WELLPF ELOG X Rig Up E-Line, Lubricator, Greasehead, etc. 18:00 19:15 1.25 346 346 PROD1 WELLPF ELOG X Run Downhole Camera with E-Line. 19:15 20:00 0.75 346 346 PROD1 WELLPF ELOG X Rig E-Line off to side. 20:00 20:30 0.50 346 0 PROD1 WELLPF TRIP X Trip out of Hole with Muleshoe. 20:30 21:00 0.50 0 0 PROD1 WELLPF TRIP X Pick Up Bullnose Milling and Trip in hole to 348'. 21:00 21:30 0.50 0 348 PROD1 WELLPF MILL X Time Mill as per Baker Rep. 3 bpm, 50 psi,40-50 rpm, Tq 1300, Up/Dn Wt=34k. 21:30 22:45 1.25 348 347 PROD1 WELLPF TRIP X Trip out of hole with milling assembly and trip in hole with Baker Bullnose for camera run. 22:45 23:00 0.25 347 347 PROD1 WELLPF SFTY X PJSM for Slickline rig up. 23:00 23:30 0.50 347 347 PROD1 WELLPF ELOG X Rig Up E-Line for camera run. 23:30 00:00 0.50 347 347 PROD1 WELLPF ELOG X Run camera run on E-Line. 06/18/2015 Take Picture with E-Line.TOOH with bullnose. PU @ RIH with milling BHA and Mill. TOOH. PU and RIH with bullnose. RU E-Line, RIH with camera and take pictures. TOOH with bullnose. PU and RIH with milling BHA and Mill.TOOH. PU and RIH with bullnose. RU E-Line, RIH with camera and take pictures.TOOH with _ bullnose. PU @ RIH with milling BHA and Mill. _ 00:00 03:30 3.50 347 331 PROD1 WELLPF FLOG X Continue camera run with E-Line. Take pictures of milling area twice and attempt to take pictures of casing at 334'. Not successful in determining any casing issues at this depth. POOH with E-Line Camera String. 03:30 04:30 1.00 331 331 PROD1 WELLPF ELOG X Rig E-Line off to side. 04:30 05:30 1.00 331 0 PROD1 WELLPF TRIP X Trip out of hole with bullnose for E-Lining. 05:30 06:30 1.00 0 0 PROD1 WELLPF SVRG X Service Rig. Inspect Top Drive.Discuss options with town engineer, and agree on the next milling BHA. Total length of mills- 3.81'. Total BHA- 11.77'. Page 14 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:30 07:00 0.50 0 11 PROD1 WELLPF BHAH X Make up Milling BHA as agreed.This mill has more agressive carbide pattern in the nose with and OD of 5 1/8", and carbide along the water courses on the side of the mill aproximately 18"from the nose. Along with the stabilizing mill of 5 1/2" OD with a smooth OD. This assembly is considered as a little "stiffer"than previous BHA. 07:00 07:30 0.50 11 348 PROD1 WELLPF MILL X TIH, 3 stands to 295'. Obtain parameters. Continue in hole to tag at 344'. UP WT-34K, SO WT 33K. ROT WT-33K. Pumps at 3 BPM- 80 PSI. RPM's at 40-600 ft/lbs of torque. Rotate through 344', and continue down to 348.70'. Begin milling with 1-3K WOB, for approximately 2 inches. Observed 1350 ft'lbs of torque, and mill off. When attempting to straight pull off of bottom,we observed an overpull of 5K.We slacked off and rotated back out of it past the 344'mark. 344', is the confirmed depth of the"S"curve above the casing collar. Circulate 2 bottoms up at higher rates of 5 BPM -1300 PSI. 07:30 08:15 0.75 348 347 PROD1 WELLPF TRIP X POOH, inspect mill, and flex joint. Observed minimal wear on mill but good indication of cutting, and flex joint was shined up in the middle of the joint from the bend in the casing while rotating. It was not junk cut however. Lay down mill assembly and keep ready for reuse. Make up Mule shoe on DP and TIH 3 stands to set mule shoe at 347'. 08:15 08:30 0.25 347 347 PROD1 WELLPF SFTY X Held PJSM with HES E-line c rew and rig crew. Discuss safety and hazard recognition issues. Discuss procedure to rig up and E-line camera run. 08:30 09:30 1.00 347 347 PROD1 WELLPF ELOG X Rig up HES E-line crew with Lubricator and pump in sub. Make up EV Camera assembly as per rep. Page 15 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:30 11:00 1.50 347 347 PROD1 WELLPF ELOG X WLIH to 347'. Pumps at 3 BPM-15 Barrels of clean 9.4 PPG with NTU's at 16.4 pumped to clean up wellbore. Obtain good pictures and maintain pump at 1-2 BPM.Work camera down to 350'WLM until observed camera lens tagged up. Pull back up hole and work to obtain good pictures looking down, Switch to sideview and obtain pictures rotating the camera. Switch back to down view catching a different view with the camera now 180 degrees form last view. Observe casing"split" at the collar area, either shaved or partially pulled apart. Pull up into the DP, and continue WLOOH. Lay down camera. 11:00 11:30 0.50 347 347 PROD1 WELLPF ELOG X RD HES E-Line Lubricator and pump in sub. Set back same on rig floor for reuse. Down load camera video and snapshots,and send pics to Town engineer. Discuss snapshots and plan forward.Agreed that we will not run another mill with carbide welded on the side of the mill. The mill is being redressed at BOT. Plan to wait on mill. 11:30 12:00 0.50 347 0 PROD1 WELLPF TRIP X Trip out of hole with 3 stands, breakout and lay down the mule shoe. 12:00 18:00 6.00 0 0 PROD1 WELLPF WAIT X Rig on standby for redressed mill. Perform rig maintenance, changing oil in the draw works. 18:00 18:15 0.25 0 0 PROD1 WELLPF SFTY X PJSM Picking Up BHA. Document BHA and Contact CPAI Engineer. Mili/BHA ok for milling downhole. 18:15 18:30 0.25 0 0 PROD1 WELLPF BHAH X Pick Up Milling BHA. Smooth side, carbide faced Bullnose with flex joint. 18:30 19:15 0.75 0 348 PROD1 WELLPF TRIP X Trip in hole 3 stands with milling BHA. 19:15 19:30 0.25 348 348 PROD1 WELLPF MILL X Mill— 1.5". 5 minutes of milling. Up/Dn/Rot Weight=34k, pump 4 bpm at 70 psi, , Free Tq above bad spots 500, Free Tq in bad spot prior to milling 900, Milling Tq= 1150-1200. 19:30 19:45 0.25 348 348 PROD1 WELLPF OWFF X Monitor well.Well static. 19:45 20:00 0.25 348 0 PROD1 WELLPF TRIP X Trip out of hole 3 stands with Milling BHA, 20:00 20:15 0.25 0 0 PROD1 WELLPF BHAH X Lay Down mill BHA and pick up Camera Run Bullnose. Bullnose smooth with half Muleshoe,thick walled. 20:15 20:30 0.25 0 347 PROD1 WELLPF TRIP X Trip in hole 3 stands with Bullnose for camera. 20:30 21:15 0.75 347 347 PROD1 WELLPF ELOG X Rig Up E-Line for camera run. Page 16 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:15 22:15 1.00 347 347 PROD1 WELLPF ELOG X Run downhole camera run. Picture taken. Smooth Mill did not burn into side of casing. Progress evident. Ramp/metal still remain in hole. Camera run—2'past"ramp"casing damage with taking weight, then camera ran into other side of 7" casing. No damage or impact marks on area past ramp. 22:15 22:45 0.50 347 347 PROD1 WELLPF ELOG X Rig Down E-Line to side. Contact CPAI Engineer. Mill BHA ok for 2nd milling run. 22:45 22:45 0.00 347 0 PROD1 WELLPF TRIP X Trip out of hole 3 stands with Bullnose for camera run. 22:45 23:00 0.25 0 0 PROD1 WELLPF BHAH X Lay Down Camera Run Smooth Bullnose. Pick Up Milling BHA for second run: Smooth side, carbide faced Bullnose with flex joint. 23:00 23:30 0.50 0 348 PROD1 WELLPF TRIP X Trip in hole 3 stands with milling BHA. 23:30 23:45 0.25 348 348 PROD1 WELLPF MILL X Mill— 1.5". 10 minutes of milling. Up/Dn/Rot Weight=34k, pump 4 bpm at 70 psi, , Free Tq above bad spots 500, Free Tq in bad spot prior to milling 900, Milling Tq= 1100-1300.WOM 1-2k. 23:45 00:00 0.25 348 348 PROD1 WELLPF OWFF X Monitor well. Static. 06/19/2015 Continue Milling and E-Line picture taking Operations. 00:00 00:15 0.25 348 0 PROD1 WELLPF TRIP X Trip out of hole 3 stands with Milling BHA, 00:15 00:30 0.25 0 0 PROD1 WELLPF BHAH X Lay Down mill BHA(Mill wear evident, approximately 40% life left) and pick up Camera Run Bullnose. Bullnose smooth with half Muleshoe, thick walled. 00:30 00:45 0.25 0 347 PROD1 WELLPF TRIP X Trip in hole 3 stands with Bullnose for camera. 00:45 01:00 0.25 347 347 PROD1 WELLPF ELOG X Rig Up E-Line for camera run. 01:00 02:00 1.00 347 347 PROD1 WELLPF ELOG X Run downhole camera run. Picture taken. Smooth Mill did not burn into side of casing. Progress evident. Ramp/metal still remain in hole but confirm work done on it. Camera run —2'past"ramp"(casing damage) without setting down, observed 7" casing behind"ramp"bowed up and then curving down, looks like it curves up behind the ramp and then away. 02:00 02:15 0.25 347 347 PROD1 WELLPF ELOG X Rig Down E-Line to side. 02:15 02:45 0.50 347 0 PROD1 WELLPF TRIP X Trip out of hole 3 stands with Bullnose for camera run. Contact CPAI Engineer. Mill BHA ok for 3rd milling run. Page 17 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:45 03:00 0.25 0 0 PROD1 WELLPF BHAH X Lay Down Camera Run Smooth Bullnose. Pick Up Milling BHA for third run: Smooth side, carbide faced Bullnose with flex joint. 03:00 03:30 0.50 0 348 PROD1 WELLPF TRIP X Trip in hole 3 stands with milling BHA. 03:30 03:45 0.25 348 348 PROD1 WELLPF MILL X Mill— 1". 12 minutes of milling. Up/Dn/Rot Weight=34k, pump 4 bpm at 70 psi, Free Tq in bad spot prior to milling 900, Milling Tq = 1200-1300.WOM 2k-3k. 03:45 04:00 0.25 348 348 PROD1 WELLPF OWFF X Monitor well prior to coming off bottom,Well Static. Blow down Top Drive. 04:00 04:15 0.25 348 0 PROD1 WELLPF TRIP X Trip out of hole 3 stands with Milling BHA, 04:15 04:30 0.25 0 0 PROD1 WELLPF BHAH X Lay Down mill BHA(Mill mobilized to Baker in Deadhorse for redress. Pick up Bullnose for Camera Run. Bullnose smooth with half Muleshoe, thick walled. 04:30 04:45 0.25 0 347 PROD1 WELLPF TRIP X Trip in hole 3 stands with Bullnose for camera. Position bullnose at 2'off of bottom at 347'. 04:45 05:00 0.25 347 347 PROD1 WELLPF SFTY X PJSM with rig crew and a-line crew for rigging up E-Line. 05:00 05:45 0.75 347 347 PROD1 WELLPF ELOG X Rig Up E-Line for camera run. Note: Sent the 5" mill that we are using back to BOT for redress. Plan to wait on mill. 05:45 06:45 1.00 347 347 PROD1 WELLPF ELOG X WLIH with EV Camera to observe and take video and snapshots. Observed that there is definite separation, but still milling in the center of hole and no sidetracking. WLOH and lay down camera. 06:45 07:30 0.75 347 347 PROD1 WELLPF ELOG X Rig down the E-line and lubricator. Set equipment to the side on rig floor for reuse.Download pictures, and send to S drive and engineers. Discuss plan forward with town engineer. 07:30 08:00 0.50 347 0 PROD1 WELLPF TRIP X POOH with the bullnose, standing back the drill pipe. 08:00 08:15 0.25 0 0 PROD1 WELLPF BHAH X Make up a 6" upper watermelon mill with smooth OD on the water courses. 08:15 08:45 0.50 0 334 PROD1 WELLPF TRIP X TIH to 334' 08:45 09:00 0.25 334 343 PROD1 WELLPF MILL X Mill/Dress the 7"casing from 334' down to 343'and stack out. 09:00 09:15 0.25 343 0 PROD1 WELLPF TRIP X CBU at high rates, and POOH standing back the drill pipe. 09:15 09:30 0.25 0 0 PROD1 WELLPF BHAH X Breakout and lay down the mill. 09:30 13:00 3.50 0 0 PROD1 WELLPF WAIT X Rig on standby for return of dressed mill. Perform rig maintenance. 5" Redressed mill on location at 1300 HRS. Page 18 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:00 13:30 0.50 0 349 PROD1 WELLPF TRIP X Make up BHA#20, redressed mill, and TIH to tag at 349'. 13:30 13:45 0.25 349 349 PROD1 WELLPF MILL X Mill H 2". 10 minutes of milling. Up/Dn/Rot Weight=34K, pump 3 BPM at 50 psi, Free Tq prior to milling 900, Milling Tq = 1200-1300. WOM 2k-3k.60 RPM's 13:45 14:15 0.50 349 0 PROD1 WELLPF TRIP X CBU at higher rates,and TOH standing back DP. Breakout and lay down mill. Inspect mill and observed minimal wear on the nose of the mill. 14:15 14:30 0.25 0 347 PROD1 WELLPF TRIP X Make up muleshoe assembly and TIH to position muleshoe at 347' 14:30 14:45 0.25 347 347 PROD1 WELLPF SF-1Y X Held PJSM with rig crew and HES E-line crew. Discuss safety and hazard recognition issues. Discuss procedure to rig up E-line with lubricator and pump ion sub. Line up trucks to pump clean filtered 9.4 PPG Brine. 14:45 15:15 0.50 347 347 PROD1 WELLPF ELOG X Rig up HES E-line with Lubricator and pump in sub. Make up EV camera. 15:15 15:45 0.50 347 347 PROD1 WELLPF ELOG X Wireline in hole with camera to 347'. Pump 20 BBLS of 9.4 PPG clean filtered brine at 3-4 BPM. Observed hole clean. Obtain pictures, indicating that we are still in the middle of the hole milling on the ramp,taking camera down to 350', up and over the ramp. WLOH. 15:45 16:15 0.50 347 347 PROD1 WELLPF ELOG X Rig down Lubricator assembly and set back same. 16:15 16:45 0.50 347 0 PROD1 WELLPF TRIP X POOH with 3 stand sof DP. Breakout and lay down mule shoe. Download pictures and send to town engineer. Discuss plan forward and agree to mill 4"on next run. 16:45 17:15 0.50 0 349 PROD1 WELLPF TRIP X Make up 5" bullnose mill again with 5 1/2'stabilizer, and flex joint.TIH to tag at 349'. Obtain parameters. 17:15 17:45 0.50 349 350 PROD1 WELLPF MILL X Mill—4". 10 minutes of milling. Up/Dn/Rot Weight=34K, pump 3 BPM at 50 psi, Free Tq prior to milling 900, Milling Tq= 1200-1300. WOM 2k-3k.60 RPM's 17:45 18:00 0.25 350 0 PROD1 WELLPF TRIP X Trip out of hole 3 stands with Milling BHA, 18:00 18:15 0.25 0 0 PROD1 WELLPF BHAH X Lay Down mill BHA(Mill looks good but wear evident)and pick up Camera Run Bullnose. Bullnose smooth with half Muleshoe,thick walled. 18:15 18:30 0.25 0 347 PROD1 WELLPF TRIP X Trip in hole 3 stands with Bullnose for camera. 18:30 18:45 0.25 347 347 PROD1 WELLPF FLOG X Rig Up E-Line for camera run. Page 19 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:45 19:15 0.50 347 347 PROD1 WELLPF ELOG X Run downhole camera run. Picture taken. Bottom part of"Ramp"metal still remain in hole. Camera run just past"ramp"through"gun sight" (notch hole in lower part of ramp) could not observe past as camera lights were washed out by"ramp". 19:15 19:30 0.25 347 347 PROD1 WELLPF ELOG X Rig Down E-Line to side. 19:30 19:45 0.25 347 0 PROD1 WELLPF TRIP X Trip out of hole 3 stands with Bullnose for camera run. Contact CPAI Engineer. Mill BHA approved to rerun mill without centralizing donut mill behind. So BHA Bullnose mill, flex joint only to allow flex into damage spot. 19:45 20:00 0.25 0 0 PROD1 WELLPF BHAH X Lay Down Camera Run Smooth Bullnose. Pick Up Milling BHA: Smooth side, carbide faced Bullnose (2nd run after redress)with flex joint. 20:00 20:15 0.25 0 349 PROD1 WELLPF TRIP X Trip in hole 3 stands with milling BHA. 20:15 20:30 0.25 349 349 PROD1 WELLPF MILL X Mill-2.5"-3.0". 15 minutes of milling. Up/Dn/Rot Weight=34K, pump 5 BPM at 70 psi, Free Tq prior to milling 700, Milling Tq=900-1300. WOM 2k-3k.60 rpm. 20:30 20:45 0.25 349 0 PROD1 WELLPF TRIP X Trip out of hole 3 stands with Milling BHA, 20:45 21:00 0.25 0 0 PROD1 WELLPF BHAH X Lay Down mill BHA(Mill shows wear on side, leading edges and scratching inside to-2.5")and pick up Camera Run Bullnose. Bullnose smooth with half Muleshoe,thick walled. 21:00 21:15 0.25 0 347 PROD1 WELLPF TRIP X Trip in hole 3 stands with Bullnose for camera. 21:15 21:30 0.25 347 347 PROD1 WELLPF ELOG X Rig Up E-Line for camera run. 21:30 22:00 0.50 347 347 PROD1 WELLPF ELOG X Run downhole camera run. Picture taken. Bottom part of"Ramp"milled away except ey hole gun sight piece which was inside ID of mill. Camera run through"gun sight"(it is-2"-3" long/deep)could not observe past end of gun sight due to turbulence of fluid and lighting. 22:00 22:15 0.25 347 347 PROD1 WELLPF ELOG X Rig Down E-Line to side. 22:15 22:30 0.25 347 0 PROD1 WELLPF TRIP X Trip out of hole 3 stands with Bullnose for camera run. Contact CPAI Engineer. Mill BHA approved to rerun mill again (3rd run with mill after redress, second without stabilizer behind). BHA: Bullnose Carbide faced mill and flex joint. Page 20 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:30 22:45 0.25 0 0 IPROD1 WELLPFBHAH X Lay Down Camera Run Smooth Bullnose. Pick Up Milling BHA: Smooth side, carbide faced Bullnose (3rd run after redress). 22:45 23:00 0.25 0 349 PROD1 WELLPF TRIP X Trip in hole 3 stands with milling BHA. 23:00 23:15 0.25 349 350 PROD1 WELLPF MILL X Mill—2.0"-2.5". 15 minutes of milling. Up/Dn/Rot Weight=34K, pump 5 BPM at 50 psi, Free Tq prior to milling 700, Milling Tq= 1050-1300.WOM 2k-5k, 50 rpm. Calculated total milled to date-18". 23:15 23:30 0.25 350 0 PROD1 WELLPF TRIP X Trip out of hole 3 stands with Milling BHA, 23:30 23:45 0.25 0 0 PROD1 WELLPF BHAH X Lay Down mill BHA(Bullnose Mill is completely worn out showing wear on all leading edges and scratching inside to-5")and pick up Camera Run Bullnose. Bullnose smooth with half Muleshoe,thick walled. 23:45 00:00 0.25 0 347 PROD1 WELLPF TRIP X Trip in hole 3 stands with Bullnose for camera. 06/20/2015 00:00 00:15 0.25 347 347 PROD1 WELLPF ELOG X Rig Up E-Line for camera run. 00:15 00:45 0.50 347 347 PROD1 WELLPF ELOG X Run downhole camera run. Picture taken. Observed that the"Ramp"is gone.The"Gun Sight"is still there and is now 4"-5"long. Observed with sideview that we have been cuffing the 7"(coring)along as we cut through the ramp. It seems we have been cutting a trench along the 7" which had shifted behind the ramp. 00:45 01:00 0.25 347 347 PROD1 WELLPF ELOG X Rig Down E-Line to side. 01:00 01:15 0.25 347 0 PROD1 WELLPF TRIP X Trip out of hole 3 stands with Bullnose for camera run. 01:15 02:00 0.75 0 0 PROD1 WELLPF BHAH X Lay Down Camera Run Smooth Bullnose. Contact CPAI Engineer. Mill discuss results, pictures and plan forward. BHA approved to run custom sharp tapered mill. BHA: Sharp Tapered Carbide faced mill and flex joint. 02:00 02:30 0.50 0 350 PROD1 WELLPF TRIP X Trip in hole 3 stands with milling BHA. 02:30 03:00 0.50 350 350 PROD1 WELLPF MILL X Mill—3.0".4 minutes of milling. Up/Dn/Rot Weight=34K, pump 4 BPM at 100 psi, Free Tq prior to milling 400, Milling Tq= 1200-1300. WOM 0.5k, 30 rpm. Observed carbide catch and worked past area —1'above 03:00 03:15 0.25 350 0 PROD1 WELLPF TRIP X Trip out of hole 3 stands with Milling ' BHA, Page 21 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:15 03:30 0.25 0 0 PROD1 WELLPF BHAH X Lay Down mill BHA(Sharp Tapered Mill shows some wear and some chipped carbide from tip to OD with more wear on outer OD portion)and pick up Camera Run Bullnose. Bullnose smooth with half Muleshoe, thick walled. 03:30 03:45 0.25 0 347 PROD1 WELLPF TRIP X Trip in hole 3 stands with Bullnose for camera. 03:45 04:00 0.25 347 347 PROD1 WELLPF SFTY X PJSM, all involved in E-Line rig up. First rig up after 3 am crew change. 04:00 04:30 0.50 347 347 PROD1 WELLPF ELOG X Rig Up E-Line for camera run. 04:30 05:00 0.50 347 347 PROD1 WELLPF ELOG X Downhole camera run. Pictures taken.The"gun sight"is bent down and has scratch marks on it from mill teeth.The mill rode up on top of the sliver of 7"casing that was in the middle of the bullnose mill and pushed it down slightly and milled on its surface. Good progress and the mill successfully milled on the surface we were targeting.WLOH 05:00 05:30 0.50 347 347 PROD1 WELLPF ELOG X Rig Down E-Line to side. 05:30 06:00 0.50 347 0 PROD1 WELLPF TRIP X Trip out of hole 3 stands with Bullnose for camera run. 06:00 06:30 0.50 0 0 PROD1 WELLPF SVRG X Service Top Drive. Send pictures to town engineers and discuss forward plan. 06:30 07:00 0.50 0 347 PROD1 WELLPF TRIP X Make up 5" Mill, repeat of last run. TIH 3 stands to 347' 07:00 07:30 0.50 347 351 PROD1 WELLPF MILL X Tag at 348.5'. Pick up and begin milling, observed increased torque of 500 ft/lbs at 348'. MIII through this spot with no issues and continue mill down a total of 4"to 350.58'. Repeat milling and polishing from 347'- 350.58'x 2. Mill—4.0". 15 minutes of milling. Up/Dn/Rot Weight=34K, pump 4 BPM at 100 psi, Free TQ prior to milling 400 FT/LBS, Milling TQ= 1200-1300.WOM 0.5k, 30 rpm. CBU at higher rates,did not observe any iron cuttings across the shakers. 07:30 08:15 0.75 351 0 PROD1 WELLPF TRIP X Trip out of hole. Observed bottom joint, or first joint above mill polished from side load on casing and ground down approximately 1/16"in the middle of the joint for about 4'. . Remove form service. Inspect and lay down mill.Approximately 10-15% wear across cutting structure. Good shape, 08:15 08:45 0.50 0 347 PROD1 WELLPF TRIP X Make up Mule shoe on Drill pipe and TIH to set in slips at 347'. Page 22 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:45 09:00 0.25 347 347 PROD1 WELLPF SFTY X Held PJSM with rig crew and HES E-line crew. Discuss safety and hazard recognition issues. Discuss procedure to rig up E-line with lubricator and pump in sub. Line up trucks to pump clean filtered 9.4 PPG Brine. 09:00 09:30 0.50 347 347 PROD1 WELLPF ELOG X Rig up HES E-line with Lubricator and pump in sub. Make up EV camera. 09:30 10:00 0.50 347 347 PROD1 WELLPF ELOG X WLIH with camera while pumping 10 BBLS of 9.4 PPG clean filtered brine. Allow picture to clean up with camera at 347'. Obtain pictures from 347'-350'. Observed no definitive images of big changes. No indication of any sidetrack issues. It seemed that the ramp we are milling on continues to mill away, and we are staying in the center of the hole with the mill.WLOH. 10:00 10:30 0.50 347 347 PROD1 WELLPF ELOG X Lay down camera,and RD E-line equipment-lubricator and pump in sub. Down load pictures and video. Send pictures to town engineer, and discuss plan forward. 10:30 11:15 0.75 347 0 PROD1 WELLPF TRIP X Trip out of hole,standing back DP and lay down mule shoe. 11:15 12:15 1.00 0 350 PROD1 WELLPF MILL X Make up new 5"Stubbing tapered mill,with 45 Deg angle. Smooth OD. TIH to begin reaming and polishing from 346'-350'. Repeat several times. Up/Dn/Rot Weight=34K, pump 5 BPM at 150 psi, Free TQ prior to milling 800 FT/LBS, Milling TQ=950 FT Lbs.WOM 0.5k, 50 rpm. CBU at higher rates,did not observe any iron cuttings across the shakers. 12:15 12:45 0.50 350 0 PROD1 WELLPF TRIP X Trip out of hole standing back DP. Breakout and lay down mill. Inspect mill. Observed approximately 5-10% wear across cutting structure. Good shape, 12:45 13:15 0.50 0 348 PROD1 WELLPF TRIP X Trip in hole 3 stands with mule shoe for camera run. Set Mule Shoe at 348' 13:15 13:30 0.25 348 348 PROD1 WELLPF SFTY X Held PJSM with rig crew and HES E-line crew. Discuss safety and hazard recognition issues. Discuss procedure to rig up E-line with lubricator and pump ion sub. Line up trucks to pump clean filtered 9.4 PPG Brine. 13:30 14:00 0.50 348 348 PROD1 WELLPF ELOG X Rig up HES E-line with Lubricator and pump in sub. Make up EV camera. Page 23 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:00 14:45 0.75 348 348 PROD1 WELLPF ELOG X WLIH with camera while pumping 10 BBLS of 9.4 PPG clean filtered brine. Allow picture to clean up with camera at 347'. Obtain pictures from 347'-350'. Observed definitive images of changes to ramp being milled. No indication of any sidetrack issues. It seemed that the ramp we are milling on continues to mill away,and we are staying in the center of the hole with the mill. WLOH. 14:45 15:15 0.50 348 348 PROD1 WELLPF FLOG X Lay down camera, and RD E-line equipment-lubricator and pump in sub. Down load pictures and video. Send pictures to town engineer, and discuss plan forward. 15:15 15:30 0.25 348 0 PROD1 WELLPF TRIP X Trip out of hole, standing back DP and lay down mule shoe. 15:30 16:00 0.50 0 347 PROD1 WELLPF TRIP X Make up 5 1/8"Bullnose mill with carbide on the OD on the watercourses, along with a stabilizing mill above with smooth OD, flex joint.TIH 3 stands,and tag @ 347', begin milling. 16:00 17:15 1.25 347 351 PROD1 WELLPF MILL X Mill and dress from 347'-350.7'. Up/Dn/Rot Weight=34K, pump 5 BPM at 150 psi, Free TQ prior to milling 800 FT/LBS, Milling TQ=950 - 1200 FT Lbs.WOM 0.5k, 50 rpm. CBU at higher rates,did not observe _ any iron cuttings across the shakers. 17:15 17:45 0.50 351 0 PROD1 WELLPF TRIP X Trip out of hole standing back DP. . 17:45 18:00 0.25 0 0 PROD1 WELLPF BHAH X Breakout and lay down mill. Inspect same. Pick up Camera Run Bullnose. Bullnose smooth with half Muleshoe,thick walled. 18:00 18:15 0.25 0 348 PROD1 WELLPF TRIP X Trip in hole 3 stands with Bullnose for camera. 18:15 18:30 0.25 348 348 PROD1 WELLPF SFTY X PJSM, all involved in E-Line rig up. 18:30 18:45 0.25 348 348 PROD1 WELLPF FLOG X Rig Up E-Line for camera run. 18:45 19:15 0.50 348 348 PROD1 WELLPF FLOG X Downhole camera run. Pictures taken.The"gun sight"is bent down and has scratch marks on it from mill teeth.The mill rode up on top of the sliver of 7"casing that was in the middle of the bullnose mill and pushed it down slightly and milled on its surface. Good progress and the mill successfully milled on the surface we were targeting.WLOH 19:15 19:45 0.50 348 348 PROD1 WELLPF FLOG X Rig Down E-Line to side. Page 24 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:45 20:15 0.50 348 0 PROD1 WELLPF TRIP X Trip out of hole 3 stands with Bullnose for camera run. Contact CPAI Engineer. Decision on next BHA and milling plan for next run. 20:15 22:00 1.75 0 0 PROD1 WELLPF WWWH X Wash Stack and Wellhead of Milling cuttings. Pull wear ring, milled shaving packed behind wear ring.Jet stack and wellhead to ensure no build up of milling material. Put Wear Ring in again. 22:00 22:15 0.25 0 0 PROD1 WELLPF BHAH X Make up 5-1/8"Mill(Carbide face and carbide on side, repeat of last run without stabilizer behind). 22:15 22:30 0.25 0 350 PROD1 WELLPF TRIP X Trip in hole 3 stands with milling BHA. 22:30 23:15 0.75 350 350 PROD1 WELLPF MILL X 20 minutes of milling. Up/Dn/Rot Weight=34K, pump 4.5 BPM at 90 psi, Free Tq prior to milling 500, Milling Tq=700-1000.WOM 0.5k, 45 rpm.WOrked area above tag up multiple times to wear down area. 23:15 23:45 0.50 350 0 PROD1 WELLPF TRIP X Trip out of hole 3 stands with Milling BHA, 23:45 00:00 0.25 0 0 PROD1 WELLPF BHAH X Lay Down mill BHA. (Mill wear significant on outer edge of bullnose towards front. Mill needs to be redressed.) 06/21/2015 00:00 00:30 0.50 0 0 PROD1 WELLPF BHAH X Pick up Camera Run Muleshoe. Muleshoe is 2-7/8"J-55 10'joint 00:30 00:45 0.25 0 345 PROD1 WELLPF TRIP X Trip in hole 3 stands with Muleshoe for camera. 00:45 01:15 0.50 345 345 PROD1 WELLPF ELOG X Rig Up E-Line for camera run. 01:15 01:45 0.50 345 345 PROD1 WELLPF ELOG X Run downhole camera run. Picture taken. Muleshoe 2-7/8"joint had camera along bottom of casing and could not see upper part of casing. 01:45 02:00 0.25 345 345 PROD1 WELLPF FLOG X Rig Down E-Line to side. 02:00 02:15 0.25 345 0 PROD1 WELLPF TRIP X Attempted to drift down with Muleshoe prior to trip out.4k down @ 351', did not force as the camera could not flex around bend if made it around.Trip out of hole 3 stands with Bullnose for camera run. 02:15 02:30 0.25 0 0 PROD1 WELLPF BHAH X Lay Down 2-7/8"Muleshoe. Pick up Milling BHA, carbide faced bullnose with smooth sides. Plan to trip in and then run camera through for pictures, then mill with it. 02:30 02:45 0.25 0 349 PROD1 WELLPF TRIP X Trip in hole 3 stands with Muleshoe for camera. 02:45 03:15 0.50 349 349 PROD1 WELLPF FLOG X Rig Up E-Line for camera run. Page 25 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:15 03:45 0.50 349 349 PROD1 WELLPF FLOG X Run downhole camera run. Picture taken. mill worked on surface casing face. Can see surface casing collar area(joint connection)in pictures. 03:45 04:30 0.75 349 349 PROD1 WELLPF FLOG X Rig Down E-Line to side. Contact CPAI Engineer. Decision to work area with smooth sided carbide faced mill currently on bottom and then to trip out and run caliper log. Mobilize Caliper 1-11/16"caliper tool from Deadhorse. 04:30 05:00 0.50 349 350 PROD1 WELLPF MILL X 18 minutes of milling. Up/Dn/Rot Weight=34K, pump 4.5 BPM at 80 psi, Free Tq prior to milling 500, Milling Tq=700-900.WOM =0.0k, 50 rpm.Worked area above tag up multiple times to wear down area. 05:00 05:30 0.50 349 349 PROD1 WELLPF FLOG X Rig Up E-Line for camera run. 05:30 06:00 0.50 349 349 PROD1 WELLPF ELOG X Run downhole camera run. Picture taken: No significant change. Scratching evident on Surface casing. 06:00 06:15 0.25 349 349 PROD1 WELLPF SFTY X PJSM Rig Down of E-Line and E-Line tools. Rehead of line in cellar. Contact CPAI Engineer. Decision to build custom mills per design from Rig Team and Fishing hands. 06:15 08:00 1.75 349 349 PROD1 WELLPF FLOG X Rig Down E-Line to side. Rig Down tools. Rehead line. 08:00 08:30 0.50 349 0 PROD1 WELLPF TRIP X Trip out of hole 3 stands with Bullnose for camera run. 08:30 08:45 0.25 0 0 PROD1 WELLPF BHAH X Break out and Lay Down Mill. 08:45 09:15 0.50 0 0 PROD1 WELLPF ELOG X Rig Up Dutch Riser for E-Line Caliper Run. 09:15 09:45 0.50 0 0 PROD1 WELLPF SVRG X Service Rig. Clean and Clear Rig Floor. 09:45 11:45 2.00 0 0 PROD1 WELLPF FLOG X Run Caliper Run with E-Line. Caliper run tags up at 352'. POOH logging with calipers. 11:45 12:15 0.50 0 0 PROD1 WELLPF ELOG X Rig Down E-Line and Dutch riser used for E-Line run. 12:15 00:00 11.75 0 0 PROD1 WELLPF WAIT X Wait on mills to be built in Deadhorse at Baker Machine. SIMOPS: Continue to do preventive maintenance on rig and to clean. 36/22/2015 Continue Milling and E-Line picture taking Operations. See report for details.Total fluid losses for the day-34 BBLS 00:00 00:45 0.75 0 0 PROD1 WELLPF WAIT X Wait on mills to be built in Deadhorse at Baker Machine. SIMOPS: Continue to do preventive maintenance on rig and to clean. 00:45 01:15 0.50 0 0 PROD1 WELLPF BHAH X Make up 5"Mill with 3.5"bullnose on front. (Carbide on side from 6" back to 18"back, 5"OD of mill area). Page 26 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:15 01:30 0.25 0 346 PROD1 WELLPF TRIP X Trip in hole 3 stands with milling BHA. 01:30 02:15 0.75 346 351 PROD1 WELLPF MILL X Worked area above tag up multiple times to wear down area. 10 minutes milling to get into place @ 25 rpm and Tq 800-900. 17 minutes of milling through area previously milled,2 minutes at bottom to mark mill location when on bottom. Up/Dn/Rot Weight=34K, pump 4 BPM at 85 psi, Free Tq prior to milling 300 at 40 rpm, Milling Tq= 900-1100.WOM 1k, 40 rpm. 02:15 02:30 0.25 351 0 PROD1 WELLPF TRIP X Trip out of hole 3 stands with Milling BHA, 02:30 02:45 0.25 0 0 PROD1 WELLPF BHAH X Lay Down mill BHA. (Mill wear mostly on leading edge of mill blades.)Pick up Camera Run Bullnose. Bullnose smooth with half Muleshoe,thick walled. 02:45 03:00 0.25 0 348 PROD1 WELLPF TRIP X Trip in hole 3 stands with Muleshoe for camera. 03:00 03:45 0.75 348 348 PROD1 WELLPF ELOG X Rig Up E-Line for camera run. 03:45 04:00 0.25 348 348 PROD1 WELLPF ELOG X Run downhole camera run. Picture taken. mill worked on surface casing face. Can see surface casing collar _area(joint connection)in pictures. 04:00 04:15 0.25 348 348 PROD1 WELLPF ELOG X Rig Down E-Line to side. 04:15 04:30 0.25 348 0 PROD1 WELLPF TRIP X Trip out of hole 3 stands with Bullnose for camera run. Contact CPAI Engineer.Approval for another run with same mill BHA. 04:30 04:45 0.25 0 0 PROD1 WELLPF BHAH X Lay Down Camera Run Smooth Bullnose. Pick Up 5"Mill with 3.5" bullnose on front. (Carbide on side from 6"back to 18"back, 5"OD of mill area). Contact CPAI ENgineer, approval for running same assembly again to gain—3". 04:45 05:00 0.25 0 351 PROD1 WELLPF TRIP X Trip in hole 3 stands with milling BHA. 05:00 05:30 0.50 351 351 PROD1 WELLPF MILL X Mill—2.0". 25 minutes of milling. Up/Dn/Rot Weight=34K, pump 4 BPM at 70 psi, Milling Tq= 1000-1300.WOM 1-3k,45-60 rpm. Mill stopped milling(worn out)CBU at higher rates. 05:30 05:45 0.25 351 0 PROD1 WELLPF TRIP X Trip out of hole standing back DP. Breakout and lay down mill. Inspect same. MIII was spent and sent back to BOT for redress. 05:45 06:00 0.25 0 348 PROD1 WELLPF TRIP X Make up Mule shoe, and TIH to set at 347.5'. Page 27 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 06:15 0.25 348 348 PROD1 WELLPF SFTY X Held PJSM with rig crew and HES ' E-line crew. Discuss safety and hazard recognition issues. Discuss procedure to rig up E-line with lubricator and pump in sub. Line up trucks to pump clean filtered 9.4 PPG Brine. 06:15 06:45 0.50 348 348 PROD1 WELLPF ELOG X Rig up E-line equipment with Lubricator and pump in sub. Make up EV camera assembly and pressure test Lubricator to 500 PSI. 06:45 07:15 0.50 348 348 PROD1 WELLPF FLOG X WLIH with camera after pumping 10 BBLS of 9.4 PPG clean filtered brine to clean up hole.Work camera through milled area obtaining pictures verifying the performance of the mill. Observed hole opening as expected and no indications of sidetracking. Camera stop depth at 351', on the side wall of 7"casing. WLOH 07:15 07:30 0.25 348 348 PROD1 WELLPF ELOG X Rig down HES Lubricator and pump in sub. Set equipment to side for rerun. Download pictures and send to Town engineers. Discuss plan forward. 07:30 07:45 0.25 348 0 PROD1 WELLPF TRIP X Trip out of hole standing back DP. Breakout and lay down Mule Shoe. 07:45 08:00 0.25 0 12 PROD1 WELLPF BHAH X Make up new 6"Watermelon mill with smooth OD on the nose, and flex joint. Note,this is a step up in the OD's of mills used. We expect to have to begin dressing the casing higher, and working back down to 351'. 08:00 08:15 0.25 12 345 PROD1 WELLPF TRIP X Trip in hole with 6" Mill assembly and tag at 344.5'. 08:15 09:45 1.50 345 351 PROD1 WELLPF MILL X Obtain parameters and begin reaming from 344.5'-351'. Mill 3.0".20 minutes of milling. Up/Dn/Rot Weight=34K, pump 4 BPM at 70 psi, Free TQ prior to milling 800 FT/LBS, Milling TQ= 1200-1300.WOM 0.5K, 30-50 rpm. Work mill to dress the milled area. CBU at higher rates, did not observe any iron cuttings across the shakers. 09:45 10:00 0.25 351 0 PROD1 WELLPF TRIP X POOH standing back DP. Breakout and lay down mill. Inspect mill. Mill indicated approximately 50-60% spent on lead end. 10:00 10:15 0.25 0 348 PROD1 WELLPF TRIP X Make up Mule Shoe.Trip in hole 3 stands with Muleshoe for camera. Page 28 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:15 10:30 0.25 348 348 PROD1 WELLPF SFTY X Held PJSM with rig crew and HES E-line crew. Discuss safety and hazard recognition issues. Discuss procedure to rig up E-line with lubricator and pump in sub. Line up trucks to pump clean filtered 9.4 PPG Brine. 10:30 11:00 0.50 348 348 PROD1 WELLPF ELOG X Rig up E-line equipment with Lubricator and pump in sub. Make up EV camera assembly and pressure test Lubricator to 500 PSI. 11:00 11:30 0.50 348 348 PROD1 WELLPF FLOG X WLIH with camera after pumping 10 BBLS of 9.4 PPG clean filtered brine to clean up hole.Work camera through milled area obtaining pictures verifying the performance of the mill. Observed hole opening as expected and no indications of sidetracking. Camera stop depth at 351', on the side wall of 7"casing. WLOH 11:30 11:45 0.25 348 348 PROD1 WELLPF FLOG X Rig down HES Lubricator and pump in sub. Set equipment to side for rerun. Download pictures and send to Town engineers. Discuss plan forward. 11:45 12:15 0.50 348 348 PROD1 WELLPF SVRG X Service Top Drive, and grease packing. 12:15 12:30 0.25 348 0 PROD1 WELLPF TRIP X Trip out of hole 3 stands with Bullnose for camera run. Contact CPAI Engineer.Approval for another run. 12:30 13:00 0.50 0 344 PROD1 WELLPF TRIP X Make up 6" Upper Watermelon Mill with bullnose and flex joint.TIH and tag at 344'. Obtain parameters. 13:00 13:30 0.50 344 346 PROD1 WELLPF MILL X Begin milling/reaming from 344'- 346'. Mill—0". Up/Dn/Rot Weight= 34K, pump 5 BPM at 140 psi, Free TQ prior to milling 800 FT/LBS, Milling TQ= 1200-1300.WOM 0.5K, 30-50 rpm.Work mill to dress casing.We believe this assembly had a bullnose assembly that was too long and would not allow the mill itself to get down far enough, and kicked the mill into the wall of the casing up higher than we have been working. CBU at higher rates. 13:30 13:45 0.25 346 0 PROD1 WELLPF TRIP X Trip out of hole standing back DP. Inspect and lay down mill and bullnose and upper watermelon mill assembly. Observed that the bullnose was polished up with no effect on the OD. The upper watermelon mill indicated little or no wear. Page 29 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:45 14:00 0.25 0 10 PROD1 WELLPF BHAH X Make up the Carbide dressed rough OD bullnose mill assembly with flex joint. Sent the new 6" OD mill back to BOT for redress. 14:00 14:15 0.25 10 347 PROD1 WELLPF TRIP X Trip in hole with Bullnose BHA. Obtain parameters and begin reaming from 347' 14:15 15:15 1.00 347 351 PROD1 WELLPF MILL X Ream& Mill from 347'to 351'. Up/Dn/Rot Weight=34K, pump 4 BPM at 70 psi, Free TQ prior to milling 800 FT/LBS, Milling TQ= 1200-1300.WOM 0.5K, 30-50 rpm. Work mill to dress the milled area. CBU at higher rates,did not observe any iron cuttings across the shakers. 15:15 15:45 0.50 351 0 PROD1 WELLPF TRIP X Trip out of hole standing back DP. Breakout&inspect mill. Observed little or no damage to mill cutting structure. 15:45 16:00 0.25 0 342 PROD1 WELLPF TRIP X Make up Mule Shoe on DP and TIH to set at 342'. 16:00 16:15 0.25 342 342 PROD1 WELLPF SFTY X Held PJSM with rig crew and HES E-line crew. Discuss safety and hazard recognition issues. Discuss procedure to rig up E-line with lubricator and pump in sub. Line up trucks to pump clean filtered 9.4 PPG Brine. 16:15 16:45 0.50 342 342 PROD1 WELLPF ELOG X Rig up E-line equipment with Lubricator and pump in sub. Make up EV camera assembly and pressure test Lubricator to 500 PSI. 16:45 17:30 0.75 342 342 PROD1 WELLPF FLOG X WLIH with camera after pumping 10 BBLS of 9.4 PPG clean filtered brine to clean up hole.Work camera through milled area obtaining pictures verifying the performance of the mill. Observed hole opening as expected and no indications of sidetracking. Camera stop depth at 351', on the side wall of 7"casing. WLOH 17:30 17:45 0.25 342 342 PROD1 WELLPF ELOG X PJSM. Rig down Lubricator and set to side.Wireline to side and then rig back up. Close the FOSV. 17:45 18:45 1.00 342 342 PROD1 WELLPF SFTY X Held Safety Stand down and recognition dinner as planned. 18:45 19:15 0.50 342 347 PROD1 WELLPF TRIP X Reposition the drill string to set the mule shoe at 347', 19:15 19:45 0.50 347 347 PROD1 WELLPF ELOG X Rig Up E-Line Lubricator and pump in sub for camera run. 19:45 20:30 0.75 347 347 PROD1 WELLPF ELOG X Run downhole camera run. Obtain pictures, and video.WLOH 20:30 21:00 0.50 347 347 PROD1 WELLPF ELOG X Rig Down E-Line to side. Page 30 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 21:15 0.25 347 0 PROD1 WELLPF TRIP X Trip out of hole 3 stands with Bullnose for camera run. CPAI Engineers present on rig and approves 5"custom mill with bullnose and 6"string mill behind for next run. 21:15 21:30 0.25 0 0 PROD1 WELLPF BHAH X Lay Down Camera Run Smooth Bullnose. Pick Up 5"Mill with 3.5" bullnose on front(Carbide on side from 6"back to 18"back, 5"OD of mill area),6"string mill and flex joint. 21:30 21:45 0.25 0 344 PROD1 WELLPF TRIP X Trip in hole 3 stands with milling BHA. 21:45 22:15 0.50 344 347 PROD1 WELLPF MILL X 40 minutes of milling from 343.6 to 347.0". Up/Dn/Rot Weight=34K, pump 4 BPM at 80 psi, Free Tq 500, Milling Tq= 1000-1400.WOM 1-4k, 45 rpm. Mill stopped making headway(mill surface worn). 22:15 22:45 0.50 347 0 PROD1 WELLPF TRIP X Trip out of hole standing back DP. 22:45 23:00 0.25 0 0 PROD1 WELLPF BHAH X Lay Down mill BHA. (Breakout and lay down mill. Inspect same. 5" Custom Mill showed wear on leading 3-4"of carbide near front of Mill, 6" String Mill showed wear along side with leading 4-6"worn out,will need to be sent for redress.)Pick up Camera Run Bullnose. Bullnose smooth with half Muleshoe, thick walled. 23:00 23:30 0.50 0 344 PROD1 WELLPF TRIP X Trip in hole 3 stands with Muleshoe for camera. 23:30 00:00 0.50 344 344 PROD1 WELLPF FLOG X Rig Up E-Line for camera run. 06/23/2015 Continue Milling and E-Line picture taking Operations. Daily fluid loss=41 bbls.217 total loss. 00:00 00:30 0.50 344 344 PROD1 WELLPF FLOG X Run downhole camera run. Picture taken.Surface casing exposed at 343.5'. 7"casing milled away significant portions of remainder of it down to 347.5'. Camera cannot see past damage at 347.5'. Potential separation of 7"from casing with 7" collar behind it. 00:30 00:45 0.25 344 344 PROD1 WELLPF ELOG X Rig Down E-Line to side. 00:45 01:00 0.25 344 346 PROD1 WELLPF TRIP X Reposition Bullnose to hopefully be able to see past damage at 347.5'. 01:00 01:30 0.50 346 346 PROD1 WELLPF FLOG X Rig Up E-Line for camera run. 01:30 02:00 0.50 346 346 PROD1 WELLPF ELOG X Run downhole camera run. Picture taken. 02:00 02:15 0.25 346 346 PROD1 WELLPF ELOG X Rig Down E-Line to side. 02:15 02:30 0.25 346 0 PROD1 WELLPF TRIP X Trip out of hole 3 stands with Bullnose for camera run.Contact CPAI Engineer, approves 5"custom mill with bullnose and flex joint for next run. Page 31 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 02:45 0.25 0 0 PROD1 WELLPF BHAH X Lay Down Camera Run Smooth Bullnose. Pick Up 5"Mill with 3.5" bullnose on front(Carbide on side from 6"back to 18"back, 5"OD of mill area)and flex joint. 02:45 03:00 0.25 0 347 PROD1 WELLPF TRIP X Trip in hole 3 stands with milling BHA. 03:00 03:15 0.25 347 347 PROD1 WELLPF MILL X Attempt to get mill into collar area at 347'dpmd. Bullnose will not go in. Rotation shows no torque. Bullnose spinning on ledge.Attempt to get in again. No joy. Contact CPAI Engineer. Decision to Tirp out and pickup Carbide faced and sided mill. 03:15 03:30 0.25 347 0 PROD1 WELLPF TRIP X Trip out of hole 3 stands with 5" Custom Mill BHA. 03:30 03:45 0.25 0 351 PROD1 WELLPF BHAH X Lay Down 5" Mill with 3.5"bullnose on front(Carbide on side from 6" back to 18"back, 5"OD of mill area) and flex joint. Pick Up 1.5' Bullnose with Carbide on end and 1' up sides along with Felx Joint. 03:45 04:00 0.25 351 0 PROD1 WELLPF TRIP X Trip in hole 3 stands with milling BHA. 04:00 05:00 1.00 347 347 PROD1 WELLPF MILL X Get the carbide bullnose after tagging the ledge at the assumed 7" collar it got into the 7"wihtout issue. Time milled on the collar for—10 minutes moving the mill 2-3"every few minutes to get fresh carbide on the casing. Then went down and lightly tagged bottom. Then milled the collar location again as pulled up through it. 05:00 05:15 0.25 347 351 PROD1 WELLPF TRIP X Trip out of hole 3 stands with Carbide bullnose BHA. 05:15 05:30 0.25 351 0 PROD1 WELLPF BHAH X Lay Down Bullnose with Carbide on end and 1'up sides along with Flex Joint. Observed that this mill is 100% spent. Pick Up new custom 5" watermelon mill with Smooth bullnose. 05:30 05:45 0.25 0 351 PROD1 WELLPF TRIP X Trip in hole 3 stands with milling BHA. 05:45 06:00 0.25 351 351 PROD1 WELLPF MILL X Tag and mill at 351', for 15 minutes, to dress the milled area of the 347' mark. 06:00 06:30 0.50 351 0 PROD1 WELLPF TRIP X Trip out of hole standing back the 3 stands of drill pipe. Breakout and lay down the mill. 06:30 06:45 0.25 0 346 PROD1 WELLPF TRIP X Make up mule shoe and TIH on 3 stands of Drillpipe to set at 346' Page 32 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:45 07:00 0.25 346 346 PROD1 WELLPF SFTY X Held PJSM with rig crew and HES E-line crew. Discuss safety and hazard recognition issues. Discuss procedure to rig up E-line with lubricator and pump in sub. Line up trucks to pump clean filtered 9.4 PPG Brine. 07:00 07:30 0.50 346 346 PROD1 WELLPF ELOG X Rig up E-line equipment with Lubricator and pump in sub. Make up EV camera assembly and pressure test Lubricator to 500 PSI. 07:30 08:15 0.75 346 346 PROD1 WELLPF ELOG X WLIH with camera after pumping 10 BBLS of 9.4 PPG clean filtered brine to clean up hole.Work camera through milled area obtaining pictures verifying the performance of the mill. Observed hole opening as expected and no indications of sidetracking. Camera stop depth at 352.3', on the side wall of 7"casing. WLOH 08:15 08:30 0.25 346 346 PROD1 WELLPF FLOG X Rig Down E-Line, Set Lubricator and pump in sub to side for reuse. Download pictures and video to S drive. Discuss plan Forward options with engineer. 08:30 08:45 0.25 346 0 PROD1 WELLPF TRIP X Trip out of hole standing back 3 stands of DP. Breakout and lay down mule shoe assembly. 08:45 09:00 0.25 0 10 PROD1 WELLPF BHAH X Make up BHA#55, 6"Custom mill with smooth bullnose.Total length of BHA- 10'. 09:00 09:15 0.25 10 345 PROD1 WELLPF TRIP X Trip in hole with BHA#55-Tag at _ 344.5'. 09:15 10:15 1.00 345 351 PROD1 WELLPF MILL X Ream&Mill from 344.5'to 351'. Up/Dn/Rot Weight=34K, pump 4 BPM at 70 psi, Free TO prior to milling 800 FT/LBS, Milling TQ= 1200-1300.WOM 0.5K,40-60 rpm. Work mill to dress the milled area, until mill quit cutting. No Torque observed. CBU at higher rates,did not observe any iron cuttings across the shakers. 10:15 10:30 0.25 351 0 PROD1 WELLPF TRIP X Trip out of hole standing back DP. Breakout and lay down mill. Inspect mil to 90%used. Observed groove cut in mill at 1.5'up from the nose. 10:30 11:00 0.50 0 0 PROD1 WELLPF SVRG X Service wash pipe on top drive. Inspect same. 11:00 11:15 0.25 0 10 PROD1 WELLPF BHAH X Make up BHA#56,6"Custom mill with smooth bullnose.Total length of BHA- 10'. 11:15 11:30 0.25 10 345 PROD1 WELLPF TRIP X Trip in hole with BHA#56-Tag at 344.5'. Page 33 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:30 12:15 0.75 345 351 PROD1 WELLPF MILL X Ream&Mill from 344.5'to 351'. Up/Dn/Rot Weight=34K, pump 4 BPM at 70 psi, Free TQ prior to milling 800 FT/LBS, Milling TQ= 1200-1300.WOM 0.5K,40-60 rpm. Work mill to dress the milled area, until mill quit cutting. No Torque observed. CBU at higher rates,did not observe any iron cuttings across the shakers. Repeat of last run. 12:15 12:30 0.25 351 0 PROD1 WELLPF TRIP X Trip out of hole standing back DP. Breakout and lay down mill. Inspect mil to 90%used. Observed groove cut in mill at 1.5'up from the nose. 12:30 12:45 0.25 0 346 PROD1 WELLPF TRIP X Make up Mule shoe assembly and TIH to set at 346'. 12:45 13:00 0.25 346 346 PROD1 WELLPF SFTY X Held PJSM with rig crew and HES E-line crew. Discuss safety and hazard recognition issues. Discuss procedure to rig up E-line with lubricator and pump in sub. Line up trucks to pump clean filtered 9.4 PPG Brine. 13:00 13:15 0.25 346 346 PROD1 WELLPF ELOG X Rig up E-line equipment with Lubricator and pump in sub. Make up EV camera assembly and pressure test Lubricator to 500 PSI. 13:15 14:00 0.75 346 346 PROD1 WELLPF ELOG X WLIH with camera after pumping 10 BBLS of 9.4 PPG clean filtered brine to clean up hole.Work camera through milled area obtaining pictures verifying the performance of the mill. Observed hole opening as expected and no indications of sidetracking. Camera stop depth at 352.3', on the side wall of 7"casing. WLOH NOTE: Best pictures to date. 14:00 14:15 0.25 346 346 PROD1 WELCTL ELOG X Rig Down E-Line, Set Lubricator and pump in sub to side for reuse. Download pictures and video to S drive. Discuss plan Forward options with engineer. 14:15 14:30 0.25 346 0 PROD1 WELCTLTRIP X Trip out of hole standing back 3 stands of DP. Breakout and lay down Mule shoe assembly. 14:30 15:00 0.50 0 6 PROD1 WELLPF BHAH X Lay down Flex joint. Make up BHA# 58. 6" Roundnose Junk Mill asssembly. 15:00 15:15 0.25 6 348 PROD1 WELLPF TRIP X Trip in hole with BHA#58. Tag at 348'. Page 34 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:15 16:15 1.00 348 351 PROD1 WELLPF MILL X Ream&Mill from 348'to 350.7'. Up/Dn/Rot Weight=34K, pump 4 BPM at 70 psi, Free TQ prior to milling 800 FT/LBS, Milling TQ= 1200-1300.WOM 0.5K,40-60 rpm. Work mill to dress the milled area. CBU at higher rates,did not observe any iron cuttings across the shakers. 16:15 16:30 0.25 351 6 PROD1 WELLPF TRIP X TOOH with BHA#58. 16:30 17:00 0.50 6 6 PROD1 WELLPF BHAH X Laid down BHA#58. Plck up BHA# 59 Mule shoe 17:00 17:15 0.25 6 346 PROD1 WELLPF TRIP X RIH W/BHA#59 17:15 17:45 0.50 346 PROD1 WELLPF ELOG X PJSM.RU& PT lubicator. To 500 psi. 17:45 18:45 1.00 346 352 PROD1 WELLPF ELOG X RIH with Camera. Circulate with filtered 9.4 brine. Recorded milling to 350 ft Sat down @ 352 ft. 350+ft still shows a bend in the casing. POOH with camera 18:45 19:00 0.25 352 0 PROD1 WELLPF ELOG X Hang back Eline lubicator: 19:00 19:15 0.25 0 PROD1 WELLPF TRIP X RIH with mule shoe tagged @ 352 ft unable to turn and get any additional depth. 19:15 19:30 0.25 352 6 PROD1 WELLPF TRIP X POOH W/BHA#59 19:30 20:00 0.50 6 11 PROD1 WELLPF BHAH X Laid down BHA#59& Picked up BHA#60. 5"custom mill assembly. 20:00 20:45 0.75 11 351 PROD1 WELLPF MILL X Began milling FT @ 50 RPM=620 Engaged torque @ 900-965. Circulaing @ 5BPM @ 1500 PSI. Tried torque milling for 10 min's no fall off in the torque @ 980 FT/Lbs. 20:45 21:00 0.25 351 11 PROD1 WELLPF TRIP X POOH W/BHA#60 21:00 21:15 0.25 11 10 PROD1 WELLPF BHAH X Lay down 5"custom mill and pick up 5"45°tapper mill. 21:15 21:30 0.25 10 351 PROD1 WELLPF TRIP X RIH with BHA#61 21:30 22:00 0.50 351 351 PROD1 WELLPF MILL X Tagged @ 351'.Reamed from 347 to 351 ft @ 5 BPM circulation and 650 FT LBs torque. 22:00 22:15 0.25 351 10 PROD1 WELLPF TRIP X POOH W/BHA#61 22:15 22:30 0.25 0 3 PROD1 WELLPF BHAH X Lay dfown BHA#61 and pick up BHA#62 Mule shoe 22:30 22:45 0.25 3 346 PROD1 WELLPF TRIP X RIH with BHA#62 22:45 23:15 0.50 346 346 PROD1 WELLPF ELOG X RU Eline&PT lubicator to 500 psi. 23:15 23:45 0.50 346 353 PROD1 WELLPF ELOG X RIH with camera. record from 347 ft to 352 ft tagged down @ 352.9 ft.POOH with camera. 23:45 00:00 0.25 353 346 PROD1 WELLPF ELOG X Hung back lubricator. 06/24/2015 Continue camera/milling operations to 351.5 ft.Test BOPE 00:00 02:15 2.25 346 346 PROD1 WELLPF SVRG X Change out saver sub and PT due to pin wear. Normal wear and tear. Page 35 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:15 02:30 0.25 346 0 PROD1 WELLPF TRIP X POOH with BHA#62 02:30 02:45 0.25 0 33 PROD1 WELLPF BHAH X Make up BHA#63. 5"Bull nose assembly W/1 DC. 02:45 03:00 0.25 33 346 PROD1 WELLPF TRIP X RIH with BHA#63. 03:00 03:45 0.75 346 351 PROD1 WELLPF MILL X Est circulation @ 5 BPM @ 90 psi. FT/@ 35 RPM's=850 worked mill from 346 down to 350 ft.with torque @ 850- 1100. Slid thru 347 to 350 ft 3K down and up. continue to ream torque reduced to 750-900 FT/LB's 03:45 04:00 0.25 351 33 PROD1 WELLPF TRIP X POOH with BHA#63. 04:00 04:15 0.25 33 0 PROD1 WELLPF BHAH X Laid down BHA#63. 04:15 04:30 0.25 0 3 PROD1 WELLPF BHAH X Make up mule shoe BHA#64 04:30 04:45 0.25 3 346 PROD1 WELLPF TRIP X RIH with BHA#64 04:45 07:30 2.75 346 346 PROD1 WELLPF ELOG X Pick up lubicator and PT to 500 psi. Change out Camera tools, and rehead. 07:30 08:30 1.00 346 346 PROD1 WELLPF ELOG X WLIH with camera.Work camera through milled area obtaining pictures verifying the performance of the mill. Observed hole opening as expected and no indications of sidetracking. Camera stop depth at 353', on the side wall of 7"casing. Observed camera hung up in the hole at the 350'depth.Work to free camera pulling 1000 lbs on the wireline.WLOH. Observed very small pieces of iron hung up in the centralizer of the camera tool. 08:30 09:00 0.50 346 0 PROD1 WELLPF TRIP X POOH, breakout and lay down the mule shoe assmbly. 09:00 09:15 0.25 0 4 PROD1 WELLPF BHAH X Make up Custom 6" Pilot Mill with crossover and staright to DP for flexibility. 09:15 09:30 0.25 4 349 PROD1 WELLPF TRIP X Trip in hole with BHA#65.Tag up at 348.5'. 09:30 10:45 1.25 349 352 PROD1 WELLPF MILL X Begin milling/reaming from 348.5'- 351.5'. Up/Dn/Rot Weight=34K, pump 5 BPM at 75 psi, Free TQ prior to milling 500-800 FT/LBS, Milling TQ= 1100-1800.WOM 1-5K, 30-50 rpm.Work mill to dress casing. Work mill to dress side of milled area, and attempt to increase the opening to downhole.We did not mill deeper, but opened the ramp up. Continued milling until torque diminished. CBU at higher rates. Page 36 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:45 11:00 0.25 352 0 PROD1 WELLPF TRIP X POOH with BHA#65 standing back DP. Breakout and lay down mill. Inspect same. Observed mill worn on side of mill with no wear or damage to the leading end of the mill. This is what we expected out of this mill. The mill still has 50-60%life in it. 11:00 11:15 0.25 0 0 PROD1 WELLPF SVRG X Service top drive,greasing and inspecting wash pipe. 11:15 11:30 0.25 0 10 PROD1 WELLPF BHAH X Make up BHA#66, 5"Smooth OD Bullnose mill.with flex joint. 11:30 11:45 0.25 10 351 PROD1 WELLPF TRIP X Trip in hole with BHA#66.Tag at 351.25'. 11:45 12:15 0.50 351 351 PROD1 WELLPF MILL X Begin milling/reaming from 351.25'- 351.5'. Up/Dn/Rot Weight=34K, pump 5 BPM at 75 psi, Free TQ prior to milling 500-800 FT/LBS, Milling TQ= 1100-1800.WOM 1-5K, 30-50 rpm.Work mill to dress casing ledge.Work mill to dress side of milled area, and attempt to increase the opening to downhole.We did not mill deeper, but attempted to continue to open the ramp up. Milling until torque diminished. CBU at higher rates. 12:15 12:30 0.25 351 0 PROD1 WELLPF TRIP X POOH with BHA#66.Breakout and lay down mill. Observed no damage to mill. 12:30 12:45 0.25 0 7 PROD1 WELLPF BHAH X Make up BHA#67. 6" Upper watermelon mill with short smooth OD bullnose. 12:45 13:15 0.50 7 351 PROD1 WELLPF TRIP X Trip in hole with BHA#67.Tag at 350.5' 13:15 14:00 0.75 351 351 PROD1 WELLPF MILL X Begin milling/reaming from 350.5'- 351.47'. Up/Dn/Rot Weight=34K, pump 5 BPM at 75 psi, Free TQ prior to milling 500-800 FT/LBS, Milling TQ=2000-3600.WOM 1-5K, 30-60 rpm.Work mill to dress casing ledge.Work mill to dress side of milled area, and attempt to increase the opening to downhole.We did not mill deeper, but attempted to continue to open the ramp up. Milling until we could see torque falling off, but small bites. 14:00 14:15 0.25 351 351 PROD1 WELLPF CIRC X CBU at higher rates. Circulate 20 BBLS clean 9.4 PPG Brine. Observed little or no iron cuttings on shakers. 14:15 14:30 0.25 351 0 PROD1 WELLPF TRIP X Trip out of hole with BHA#67 standing back 3 stands of DP. Breakout&inspect mill and bullnose. 14:30 14:45 0.25 0 347 PROD1 WELLPF TRIP X Make up Mule Shoe(BHA#68)on DP and trip in hole to set at 347' Page 37 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:45 15:00 0.25 347 347 PROD1 WELLPF SFTY X Held PJSM with rig crew and HES E-line crew. Discuss safety and hazard recognition issues. Discuss procedure to rig up E-line with lubricator and pump in sub. Line up trucks to pump clean filtered 9.4 PPG Brine. 15:00 15:30 0.50 347 347 PROD1 WELLPF FLOG X Rig up E-line equipment with Lubricator and pump in sub. Make up EV camera assembly and pressure test Lubricator to 500 PSI. 15:30 16:00 0.50 347 347 PROD1 WELLPF ELOG X WLIH with camera after pumping 10 BBLS of 9.4 PPG clean filtered brine to clean up hole.Work camera through milled area obtaining pictures verifying the performance of the mill. Observed hole opening as expected and no indications of sidetracking. Camera stop depth at 353.97', on the side wall of 7"casing. WLOH 16:00 17:00 1.00 347 347 PROD1 WELLPF ELOG X Rig down HES Lubricator and pump in sub. Set equipment to side for rerun. Download pictures and send to Town engineers. Discuss plan forward. 17:00 17:15 0.25 347 0 PROD1 WELLPF TRIP X Trip out of hole with Mule shoe assembly BHA#68. Breakout and lay down mule shoe. 17:15 19:45 2.50 0 PROD1 WELLPF WWWH X Prep floor equipment.wash BOPE stack 19:45 21:00 1.25 PROD1 WHDBO RURD XT Attempt to pull wear ring. having trouble with lock downs. Metal packed as well. after removal 21:00 21:30 0.50 PROD1 WHDBO WWWH XT Wash stack once more to clear all metal shavings 21:30 22:30 1.00 PROD1 WHDBO RURD XT Installed test plug. unable to get all LDS engaged. 22:30 00:00 1.50 PROD1 WHDBO BOPE XT BOPE test: Witness of test waived by Matt Herrera AOGCC.on 6-22-15 @ 14:15 hrs. Test: Shell test to 2500 psi. leaking LDS packing gland leaking.tighten gland and re test.wait on new packing glands. 06/25/2015 Continue to test BOPE. Continue milling and camera ops. 00:00 01:45 1.75 0 0 PROD1 WHDBO BOPE XT Changed out 3 LDS. Shell test 250/ 2500 psi. good test. Page 38 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:45 07:30 5.75 0 0 PROD1 WHDBO BOPE X Continue BOPE test: 1)BR, Choke 1,2,3,16 RF kill outer test spool HCR TD. pass 2)Choke 4,5,6,HCR kill, Inner test spool, Man TD. Pass. 3)Choke 7,8,9,Man kill, HT 38 dart. pass 4)Super chk, Man choke,flow check &test. pass 5)Choke 10,11, HT 38 FOSV. pass 6)Choke 12,13,15. Pass. 7)Annular W/3.5"TJ, 3.5"8rd FOSV. choke 14. 8) UPR, HCR choke 9)Man choke. 10)Lower pipe rams. Draw down: Observed initial 200 PSI obtained in 20 seconds,with full 3000 PSI obtained in 96 seconds. Observed 5 Nitrogen bottles with an average pressure of 1900 PSI. 07:30 08:30 1.00 0 0 PROD1 WHDBO RURD X Blow down and rig down all test equipment. 08:30 08:45 0.25 0 0 PROD1 WELLPF BHAH X Pull tools to rig floor and prepare for BHA. 08:45 09:00 0.25 0 34 PROD1 WELLPF BHAH X Make up BHA#69. 6" Rough OD Bullnose assembly with a 4 3/4" Drill collar.This decision has been made to dress the trough or belly, and remain a stiffer assembly. 09:00 09:15 0.25 34 351 PROD1 WELLPF TRIP X Trip in hole with BHA#69.Tag at 350.5', as expected. 09:15 10:00 0.75 351 351 PROD1 WELLPF MILL X Begin milling/reaming from 350.5'- 351.2'. Up/Dn/Rot Weight=34K, pump 5 BPM at 75 psi, Free TQ prior to milling 500-800 FT/LBS, Milling TQ= 1100-1300.WOM 0-1K, 30-60 rpm.Work mill to dress casing ledge. We did not mill deeper, but attempted to continue to open the ramp up. Milling until we could see torque falling off, but small bites. CBU at higher rates. Observed no iron cuttings on the shakers. 10:00 10:15 0.25 351 0 PROD1 WELLPF TRIP X Trip out of hole with BHA#69 standing back 3 stands of DP. 10:15 10:45 0.50 0 34 PROD1 WELLPF BHAH X Breakout and lay down the mill. Inspect same, observed mill in good shape,with minimal wear. ready for re-run Make up BHA#70, 5" Custom Pilot Mill with Drill collar. 10:45 11:00 0.25 34 352 PROD1 WELLPF TRIP X Trip in hole with BHA#70. Tag @ 351.75'. Page 39 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 11:30 0.50 352 353 PROD1 WELLPF MILL X Begin milling/reaming from 351.8'- 352.5'. Up/Dn/Rot Weight=34K, pump 5 BPM at 75 psi, Free TQ prior to milling 500-800 FT/LBS, Milling TQ= 1100-1300.WOM 0-1K, 30-60 rpm.Work mill on the casing ramp and deepened the hole to round the bend. Milling until we achieved a godd 3/4 of a foot. Stopped milling. CBU at higher rates. Observed no iron cuttings on the shakers. 11:30 11:45 0.25 353 353 PROD1 WELLPF CIRC X CBU at higher rates. Observed no iron cuttings on the shakers. Pump 20 BBLS of clean 9.4 PPG filtered brine to clean up the hole. Note:We do not need to pull the assembly at this time, as the camera will go through the ID of the tools. 11:45 12:00 0.25 353 353 PROD1 WELLPF PULD X Lay down a single of DP, and position the drill string to allow the end of the mill to set at 347.5'. 12:00 12:15 0.25 353 353 PROD1 WELLPF SFTY X Held PJSM with rig crew and HES E-line crew. Discuss safety and hazard recognition issues. Discuss procedure to rig up E-line with lubricator and pump in sub. Line up trucks to pump clean filtered 9.4 PPG Brine. 12:15 13:15 1.00 353 353 PROD1 WELLPF ELOG X Rig up E-line equipment with Lubricator and pump in sub. Make up EV camera assembly and pressure test Lubricator to 500 PSI. Note: The wireline was reheaded and changed out to a bigger line of 5/16".Along with new sheaves etc... 13:15 14:00 0.75 353 353 PROD1 WELLPF FLOG X WLIH with camera after pumping 10 BBLS of 9.4 PPG clean filtered brine to clean up hole.Work camera through milled area obtaining 9 pictures verifying the performance of the mill. Observed hole opening as expected and no indications of sidetracking. Camera stop depth at 353.97', on the side wall of 7"casing. WLOH 14:00 14:15 0.25 353 325 PROD1 WELLPF FLOG X Rig down HES Lubricator and pump in sub. Set equipment to side for rerun. Download pictures and send to Town engineer. Discuss plan forward. 14:15 14:30 0.25 325 0 PROD1 WELLPF TRIP X POOH with BHA#70, standng abck DP. Inspect and lay down mill. 14:30 17:30 3.00 0 0 PROD1 WELLPF SVRG X Change out washpipe on Top Drive. 17:30 18:00 0.50 0 352 PROD1 WELLPF TRIP X RIH with BHA#71 Mule shoe. Tagged with shoe @ 352 ft. 18:00 18:30 0.50 352 352 PROD1 WELLPF CIRC X Circulated in 20 BBLs of filtered 9.4 brine Page 40 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:30 19:00 0.50 352 338 PROD1 WELLPF TRIP X Spaced out DP tail to place mule shoe @ 338 ft. 19:00 20:00 1.00 338 338 PROD1 WELLPF ELOG X RU Eline. PT lubicator to 500 psi. 20:00 20:30 0.50 338 PROD1 WELLPF FLOG X RIH with camera to 336 ft water did not clear up while circulating @ 3 BPM. after pumping 22 BBLS. Pulled sample off of vacuum truck unable to see thru it. 20:30 00:00 3.50 338 352 PROD1 WELLPF WAIT XT Wait on truck from Deadhorse with clean filter brine.do to the fact that the unit that had been changed out today was not a ultra clean trailer. and the none use of the agitators was not communicated as well. Held discussion with supervisor on site for improved communication. 06/26/2015 Continued mill and Camera operations 00:00 01:00 1.00 352 352 PROD1 WELLPF CIRC X Il Changed well over to clean filtered brine.25 bbl's 01:00 01:15 0.25 352 338 PROD1 WELLPF FLOG X Pulled DP tail to 338 ft ru lubicator and PT to 500 psi. 01:15 02:15 1.00 338 338 PROD1 WELLPF ELOG X RIH with camera. Unable to get a clear picture with camera @ 341ft with pump rates adjust from .5 BPM to 4 BPM . Rebooted camera. still no change. 75 BBL of brine pump past _camera. POOH 02:15 02:45 0.50 338 346 PROD1 WELLPF ELOG XT Hung back lubricator lower pipe to 346 ft 02:45 03:15 0.50 346 346 PROD1 WELLPF ELOG X Pick up lubricator and PT 500 psi. 03:15 04:15 1.00 346 346 PROD1 WELLPF ELOG X RIH with camera. Logged from 346 to 359 ft up and down. Camera slid down to 359'without issue. POOH . 04:15 04:30 0.25 346 346 PROD1 WELLPF FLOG X Hung back lubicator and pump in sub assembly. 04:30 06:30 2.00 346 346 PROD1 WELLPF SLPC X Slip&cut DL. Inspect dra works and brakes. 06:30 06:45 0.25 346 0 PROD1 WELLPF TRIP X POOH with BHA#71 standing back DP. 06:45 07:15 0.50 0 34 PROD1 WELLPF BHAH X Breakout and lay down the 5" Custom mill assembly. Make up the 6"Custom mill assembly on a drill collar. 07:15 07:30 0.25 34 352 PROD1 WELLPF TRIP X Trip in hole with BHA#72. Tag at 351.5'. 07:30 10:00 2.50 352 354 PROD1 WELLPF MILL X Begin milling/reaming from 351.5'- 353.8. Up/Dn/Rot Weight=34K, pump 5 BPM at 75 psi, Free TQ prior to milling 500-800 FT/LBS, Milling TQ= 1100-2000.WOM 0-2K, 30-60 rpm. Work mill to dress casing ledge. Milling until we could see torque falling off. Pick up and slack off with no rotation to tag at 353.5'. Page 41 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:00 10:15 0.25 354 354 PROD1 WELLPF CIRC X CBU at higher rates. Spot clean filtered brine on bottom. Recovered 1 1/2 lbs of iron on magents in shaker trough.. 10:15 10:30 0.25 354 0 PROD1 WELLPF TRIP X Trip out of hole with BHA#72 standing back DP. 10:30 10:45 0.25 0 0 PROD1 WELLPF BHAH X Breakout and lay down mill. Inspect mill observing that the leading end has no milling damage, and the sides are worn 60-70%as expected. This indicates that we are still dressing the ledge area, and milling it out to the center of the hole. Make up the 4 3/4" Mule shoe 10:45 11:15 0.50 0 349 PROD1 WELLPF TRIP X Trip in hole with BHA#73, mule shoe, and tag at 353.5'. Circulate 20 BBLS of 9.4 PPG filtered brine. Pick up to spot the Mule shoe at 349'. 11:15 11:30 0.25 349 349 PROD1 WELLPF SFTY X Held PJSM with rig crew and HES E-line crew. Discuss safety and hazard recognition issues. Discuss procedure to rig up E-line with lubricator and pump in sub. Line up trucks to pump clean filtered 9.4 PPG Brine. 11:30 12:00 0.50 349 349 PROD1 WELLPF ELOG X Rig up E-line equipment with Lubricator and pump in sub. Make up EV camera assembly and pressure test Lubricator to 500 PSI. Note: The wireline was reheaded and changed out to a bigger line of 5/16".Along with new sheaves etc... 12:00 14:15 2.25 349 349 PROD1 WELLPF ELOG X WLIH with camera after pumping 10 BBLS of 9.4 PPG clean filtered brine to clean up hole.Work camera through milled area obtaining pictures verifying the performance of the mill. Observed hole opening as expected and no indications of sidetracking. Camera stop depth at 353'.WLOH 14:15 14:30 0.25 349 0 PROD1 WELLPF TRIP X POOH with BHA#73 14:30 15:00 0.50 PROD1 WELLPF SVRG X Service Top drive&inspect. 15:00 15:30 0.50 PROD1 WELLPF ELOG X Install Dutch riser. 15:30 18:30 3.00 PROD1 WELLPF ELOG X RIH with MFC assembly log from 200 ft to 385 ft Top of tbg stump @ 358.5 ft. POOH. 18:30 19:00 0.50 PROD1 WELLPF FLOG X Pulled Dutch riser. 19:00 19:15 0.25 0 10 PROD1 WELLPF BHAH X Pick up BHA#74, 5" Pilot mill assemby 19:15 19:30 0.25 10 352 PROD1 WELLPF TRIP X RIH with BHA#74. 19:30 20:15 0.75 352 354 PROD1 WELLPF MILL X Sat down @ 353.8 ft worked mill down to 354.4 ft back reamed. unable to get back to 354.4 Page 42 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:15 20:30 0.25 354 10 PROD1 WELLPF TRIP X POOH with BHA#74. 20:30 20:45 0.25 10 0 PROD1 WELLPF BHAH X Lay down BHA 20:45 21:00 0.25 0 6 PROD1 WELLPF BHAH X Make up BHA#75 Bull nose 21:00 21:15 0.25 6 351 PROD1 WELLPF TRIP X RIH with BHA#75 21:15 21:45 0.50 351 351 PROD1 WELLPF ELOG X Pick up Lubicator and PT 500 psi. 21:45 22:30 0.75 351 351 PROD1 WELLPF ELOG X Run camera to 354 ft sat down on ledge. Made 3 attempts to get lower with out success. POOH 22:30 22:45 0.25 351 351 PROD1 WELLPF ELOG X Hung back lubricator. 22:45 23:00 0.25 351 0 PROD1 WELLPF TRIP X POOH with BHA#75 23:00 23:30 0.50 0 PROD1 WELLPF WAIT X Discussion next milling run with town. 23:30 23:45 0.25 0 8 PROD1 WELLPF BHAH X Make up BHA#76. Bull nose W/" watermelon mill 23:45 00:00 0.25 8 350 PROD1 WELLPF TRIP X RIH with BHA#76 06/27/2015 Continued milling operations W/camera runs Fluid loss today=25 BBLs. Total loss=334 00:00 02:00 2.00 0 354 PROD1 WELLPF MILL X Tagged with Mill @ 342ft reamed to 344ft. 30 RPM @ 600 FT/IBs torque. Continued to rotate down to 351.4 mill depth setting 5 K down. Increased RPM's to 50 @ 1050- 1300 FT/LB's torque. Milled down to 351.8 Mill depth. Bull nose @ 353.8. Circulating @ 5 BPM @ 80 PSI. Circulated clean and displaced with 12 BBL's filtered brine. 02:00 02:15 0.25 354 8 PROD1 WELLPF TRIP X POOH with BHA#76 02:15 02:30 0.25 8 0 PROD1 WELLPF BHAH X Laid down BHA 76. 02:30 03:15 0.75 0 PROD1 WELLPF SVRG X Service&inspect TD 03:15 03:30 0.25 0 350 PROD1 WELLPF TRIP X RIH with Bull nose asssembly BHA# 77 03:30 04:15 0.75 350 350 PROD1 WELLPF ELOG X Pick up lubricator&PT to 500 psi. 04:15 05:00 0.75 350 350 PROD1 WELLPF ELOG X RIH with Camera logged from 350.0 ft to 05:00 05:15 0.25 350 350 PROD1 WELLPF ELOG X Rig down Eline equipment. Down load video and snapshots. Discuss milling options with engineer. 05:15 05:30 0.25 350 0 PROD1 WELLPF TRIP X POOH with BHA#77. Stand back DP. 05:30 05:45 0.25 0 10 PROD1 WELLPF BHAH X Breakout and lay down Mule shoe assembly. Make up BHA#78, 5" Smooth OD Bullnose mill. 05:45 06:00 0.25 10 3 PROD1 WELLPF TRIP X Trip in hole with BHA#78, 06:00 06:30 0.50 3 354 PROD1 WELLPF MILL X Tag at 353.8'. Milled to 354.2',with little or no WOB. Made 4-5" in depth. 06:30 07:00 0.50 354 0 PROD1 WELLPF TRIP X Trip out of hole with BHA#78. Page 43 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:00 07:15 0.25 0 0 PROD1 WELLPF BHAH X Breakout and lay down Mill. Make up 4 3/4"Mule Shoe assembly. BHA# 79 07:15 07:30 0.25 0 350 PROD1 WELLPF TRIP X Trip in hole with BHA#79 to set shoe at 350'. 07:30 07:45 0.25 350 350 PROD1 WELLPF SFTY X Held PJSM with rig crew and HES E-line crew. Discuss safety and hazard recognition issues. Discuss procedure to rig up E-line with lubricator and pump in sub. Line up trucks to pump clean filtered 9.4 PPG Brine. 07:45 08:15 0.50 350 350 PROD1 WELLPF ELOG X Rig up E-line equipment with Lubricator and pump in sub. Make up EV camera assembly and pressure test Lubricator to 500 PSI. Note:The wireline was reheaded and changed out to a bigger line of 5/16".Along with new sheaves etc... 08:15 08:45 0.50 350 350 PROD1 WELLPF ELOG X WLIH with camera after pumping 10 BBLS of 9.4 PPG clean filtered brine to clean up hole.Work camera through milled area obtaining pictures verifying the performance of the mill. Observed hole opening as expected and no indications of sidetracking. Camera stop depth at 353'.WLOH 08:45 09:15 0.50 350 350 PROD1 WELLPF FLOG X Rig down HES Lubricator and pump in sub. Set equipment to side for rerun. Download pictures and send to Town engineer. Discuss plan forward. 09:15 09:30 0.25 350 0 PROD1 WELLPF TRIP X POOH with BHA#79. 09:30 09:45 0.25 0 6 PROD1 WELLPF BHAH X Breakout and lay down BHA#79 Mule Shoe. Make up BHA#80. 5" Short Tapered Mill assembly 09:45 10:00 0.25 6 354 PROD1 WELLPF TRIP X Trip in hole with BHA#80. 10:00 10:45 0.75 353 354 PROD1 WELLPF MILL X Begin milling/reaming from 352.8- 354.65'. Up/Dn/Rot Weight=34K, pump 5 BPM at 75 psi, Free TQ prior to milling 500-800 FT/LBS, Milling TQ= 1100-2000.WOM 0-2K, 30-60 rpm.Work mill to dress casing ledge. Milling until we could see torque falling off. Milled 6". 10:45 11:00 0.25 354 0 PROD1 WELLPF TRIP X Trip out of hole with BHA#80, standing back DP. 11:00 11:15 0.25 0 5 PROD1 WELLPF BHAH X Breakout and lay down the 5" tapered MITI. Make up BHA#81, magnet assembly. 11:15 11:30 0.25 0 354 PROD1 WELLPF TRIP X Trip in hole with magnet and tag at 354.6'. CBU. POOH with Magnet assembly. Observed iron cuttings on the magnet. 11:30 12:00 ' 0.50 354 0 PROD1 WELLPF BHAH X POOH, breakout and lay down magnet, and recover iron in a bucket. Page 44 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 13:00 1.00 0 0 PROD1 WELLPF WWWH X Make up stack washing tool on bottom of magnet. RIH with tool to wear bushing, and flush bushing and stack. Pull wear bushing and flush iron. Observed wear bushing was packed and tight in hole. Install wear bushing and RILDS. Lay down stack washing tool, and magnet. 13:00 13:15 0.25 0 350 PROD1 WELLPF BHAH X Make up BHA#82,4 3/4" Mule Shoe assembly. 13:15 13:30 0.25 350 350 PROD1 WELLPF TRIP X TIH to set Mule Shoe at 351'. 13:30 13:45 0.25 350 350 PROD1 WELLPF SFTY X Held PJSM with rig crew and HES E-line crew. Discuss safety and hazard recognition issues. Discuss procedure to rig up E-line with lubricator and pump in sub. Line up trucks to pump clean filtered 9.4 PPG Brine. 13:45 14:15 0.50 350 350 PROD1 WELLPF FLOG X Rig up E-line equipment with Lubricator and pump in sub. Make up EV camera assembly and pressure test Lubricator to 500 PSI. Note:The wireline was reheaded and changed out to a bigger line of 5/16".Along with new sheaves etc... 14:15 14:45 0.50 350 350 PROD1 WELLPF FLOG X WLIH with camera after pumping 10 BBLS of 9.4 PPG clean filtered brine to clean up hole.Work camera through milled area obtaining pictures verifying the performance of the mill. Observed hole opening as expected and no indications of sidetracking. Camera stop depth at 355'.WLOH 14:45 15:00 0.25 350 350 PROD1 WELLPF FLOG X Rig down HES Lubricator and pump in sub. Set equipment to side for rerun. Download pictures and send to Town engineer. Discuss plan forward. 15:00 15:15 0.25 350 0 PROD1 WELLPF TRIP X POOH with BHA#82. 15:15 15:30 0.25 354 0 PROD1 WELLPF BHAH X Breakout and lay down BHA#82 Mule Shoe. Make up BHA#83.6" _ Short Tapered Mill assembly 15:30 15:45 0.25 0 354 PROD1 WELLPF TRIP X Trip in hole with BHA#83 15:45 16:15 0.50 354 354 PROD1 WELLPF MILL X Obtain parameters as above, and attempt to mill off csing at 354'.Observed pressure increase when tapered mill set on botrttom, not allowing us to gain any cutting structure on the obstruction. Retry to gain milling,without success. 16:15 16:30 0.25 354 0 PROD1 WELLPF TRIP X POOH with BHA#83. 16:30 16:45 0.25 0 6 PROD1 WELLPF BHAH X Breakout and lay down the Tapered Mill. Make up the BHA#84. Rough OD 6" Bullnose assembly. 16:45 17:00 0.25 6 354 PROD1 WELLPF TRIP X Trip in hole with BHA#84 Page 45 of 67 7 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 17:00 17:45 0.75 354 354 PROD1 WELLPF MILL X Obtained parameters. Tagged @ 354.65 ft with bull nose.Attempted to make hole with mill with Torque @ 1100- 1300 FT mad approx.10 of a foot. 17:45 18:00 0.25 354 11 PROD1 WELLPF TRIP X POOH with BHA#84 18:00 18:30 0.50 0 11 PROD1 WELLPF BHAH X Changed out BHA#84 to 85. 5" Bull nose mill. 18:30 18:45 0.25 11 355 PROD1 WELLPF TRIP X RIH with BHA#85 tagged©354.8 18:45 19:15 0.50 355 PROD1 WELLPF MILL X Est parameters:tagged @ 354.8 ft. 30 RPM @ 500.-850 Torque. Seen a pressure increase of 30 psi .each time bull nosed tagged. unable to get nose past that point. displaced 12 bbls of filtered brine. 19:15 19:30 0.25 355 11 PROD1 WELLPF TRIP X POOH wth BHA 85 19:30 19:45 0.25 11 11 PROD1 WELLPF BHAH X Changed out mill to bull nose. 19:45 20:00 0.25 11 351 PROD1 WELLPF TRIP X RIH with BHA 86 Bullnose. 20:00 20:30 0.50 351 351 PROD1 WELLPF ELOG X Pick up lubricator and PT to 500 psi. 20:30 21:00 0.50 351 351 PROD1 WELLPF ELOG X RIH with Camera. logged from 351 to 354 ft and record. POOH with Camera 21:00 21:15 0.25 351 351 PROD1 WELLPF ELOG X Hung back lubricator 21:15 21:30 0.25 351 0 PROD1 WELLPF TRIP X POOH with BHA#86 21:30 22:00 0.50 0 PROD1 WELLPF WAIT X Discuss next mill run with town Eng. 22:00 22:15 0.25 0 9 PROD1 WELLPF BHAH X Picked up BHA#87 2 5/16 X 4 3/4 Mill assembly 22:15 22:30 0.25 9 353 PROD1 WELLPF TRIP X RIH with BHA#87. 22:30 23:30 1.00 353 355 PROD1 WELLPF MILL X Est parameters: Tagged with 2 5/16 tip @ 354.75 ft Began milling ops milled down to 354.88 ft qiuit making any hole.with weight adjustments from 2K-5K no additional torque. 23:30 23:45 0.25 355 0 PROD1 WELLPF TRIP X POOH with BHA#87. Milled only showed wear inside of the circulation port on 2 5/16" nose. 23:45 00:00 0.25 0 0 PROD1 WELLPF WAIT X Discussed mill run option with town. 06/28/2015 Continued milling/camera operation. Fluid loss today: 9 BBLS Total loss:343 BBLS 9.4 Brine 00:00 00:15 0.25 0 5 PROD1 WELLPF BHAH X Make up BHA#88. 5"Concaved mill 00:15 00:30 0.25 5 354 PROD1 WELLPF TRIP X RIH with BHA#88 00:30 01:30 1.00 354 355 PROD1 WELLPF MILL X EST. parameters:450 FT/LB's torque @ 50 RPM's circulating @ 5 BPM© 185 PSI. Tagged @ 354.5 ft top of tip sticking up. Milled off tip continue milling Torque @ 750 FT/ LB's Page46of67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:30 01:45 0.25 355 355 PROD1 WELLPF CIRC X Pumped 10 BBL Hi-Vis sweep, 10 9.4 Brine from rig followed by 10 BBLs filtered brine. 01:45 02:00 0.25 355 0 PROD1 WELLPF TRIP X POOH with BHA#88. Mill showed center wear and out edge wear. 02:00 02:45 0.75 0 PROD1 WELLPF SVRG X Service and inspect TD 02:45 03:00 0.25 0 351 PROD1 WELLPF TRIP X RIH with BHA#89 Bull nose 03:00 03:15 0.25 351 351 PROD1 WELLPF FLOG X Picked up Lubricator and PT to 500 psi. 03:15 03:45 0.50 351 351 PROD1 WELLPF ELOG X RIH with camera logged from 351 to 355.0. log show both casings are now under mill. POOH. 03:45 04:00 0.25 351 351 PROD1 WELLPF FLOG X Hung back lubricator. 04:00 04:15 0.25 351 0 PROD1 WELLPF TRIP X POOH with BHA#89 04:15 06:00 1.75 0 0 PROD1 WELLPF WAIT X Discuss Video and snapshot pictures with town engineer. Crew Change 06:00 06:15 0.25 0 1 PROD1 WELLPF BHAH X Make up BHA#90. 5"Concave Junk Mill. 06:15 06:30 0.25 1 354 PROD1 WELLPF TRIP X Trip in hole with BHA#90. 06:30 07:00 0.50 354 356 PROD1 WELLPF MILL X Tag up at 355'. Obtain parameters, and mill off 3",to 355.45'. 07:00 07:30 0.50 356 356 PROD1 WELLPF CIRC X CBU at higher rates. Pump 10 BBLS Hi Visc sweep. Observed iron cuttings at surface. Chase with 20 BBLS of clean filtered 9.4 PPG Brine. 07:30 07:45 0.25 356 0 PROD1 WELLPF TRIP X Trip out of hole with BHA#90, standing back DP. 07:45 08:15 0.50 0 0 PROD1 WELLPF BHAH X Breakout and lay down the mill. Inspect same. Minimal wear on OD. Inside shows signs of 40-50%wear. Make up BHA#91, Bullnose for camera run. 08:15 08:30 0.25 0 351 PROD1 WELLPF TRIP X Trip in hole with BHA#91, and set bullnose at 351'. 08:30 08:45 0.25 351 351 PROD1 WELLPF SFTY X Held PJSM with crew and E-line. 08:45 09:30 0.75 351 351 PROD1 WELLPF FLOG X Rig up E-line lubricator an dpump in sub. Insta;ll camera,and pressure test to 500 PSI. 09:30 10:00 0.50 351 351 PROD1 WELLPF FLOG X Wireline in hole with camera, observed damged casing and performance of mill. There still is s ledge in the center of the hole, suspect made up of the 7"and 9 5/8" casing together.WLOH 10:00 10:15 0.25 351 351 PROD1 WELLPF ELOG X Rig down lubricator and pump in sub. Download pictures and video. Discuss options with town engineer. 10:15 10:30 0.25 351 0 PROD1 WELLPF TRIP X Trip out of hole with BHA#91, standing back DP. 10:30 11:00 0.50 0 0 PROD1 WELLPF SVRG X Service top drive. Inspect same. Grease blocks. Page 47 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 12:30 1.50 PROD1 WELLPF OTHR X Discuss options with town Eng. for plan forward 12:30 13:00 0.50 0 354 PROD1 WELLPF TRIP X Make up full Mule shoe, (BHA#92). Trip in hole, attempt to work mule shoe into either side of the split ledge in the hole, for verification of hole. No success in entering either sid eof ledge. Set Mule shoe at 354'. 13:00 13:15 0.25 354 354 PROD1 WELLPF SFTY X Held PJSM with crew and E-line. 13:15 13:30 0.25 354 351 PROD1 WELLPF ELOG X Rig up E-line lubricator and pump in sub. Install camera, and pressure test to 500 PSI. 13:30 14:00 0.50 354 354 PROD1 WELLPF ELOG X Wireline in hole with camera, observed damged casing and performance of mill. There still is s ledge in the center of the hole, suspect made up of the 7"and 9 5/8" casing together. Pictures were not as accurate but still indicated the ledge obstruction.WLOH 14:00 14:15 0.25 354 354 PROD1 WELLPF ELOG X Rig down lubricator and pump in sub. Download pictures and video. Discuss options with town engineer. 14:15 14:30 0.25 354 0 PROD1 WELLPF TRIP X Trip out of hole with BHA#92, standing back DP. Discuss Video and snapshot pictures with town engineer and plan forward. 14:30 15:00 0.50 0 46 PROD1 WELLPF BHAH X Strap and make up BHA#93. 15:00 15:30 0.50 46 350 PROD1 WELLPF TRIP X Trip in hole with BHA#93. This assembly was put together to dress the area of damaged casing form 350"-355',without engaging the ledge at 355.45'. 15:30 17:00 1.50 350 355 PROD1 WELLPF MILL X Obtain parameters as above. Mill and dress casing form 350'-355'.30-60 RPM @ 600-900 FT/'Bs torque. Continued to rotate down to 355' mill depth. 17:00 17:45 0.75 355 355 PROD1 WELLPF CIRC X Pumped 10 BBL Hi-Vis sweep, 10 9.4 Brine from rig followed by 10 BBLs filtered brine. 17:45 18:00 0.25 355 46 PROD1 WELLPF TRIP X POOH with BHA 93 18:00 18:30 0.50 46 0 PROD1 WELLPF BHAH X Laid down BHA#93 mill show extensive wear. 18:30 18:45 0.25 0 347 PROD1 WELLPF TRIP X RIH with BHA#94 Mule shoe. 18:45 19:15 0.50 347 347 PROD1 WELLPF ELOG X Pick up lubricator and PT to 500 psi. 19:15 20:15 1.00 347 347 PROD1 WELLPF ELOG X Ran log from 347 to 355 ft. mills are tracking the low side of the well. POOH 20:15 21:00 0.75 347 0 PROD1 WELLPF ELOG X Attempted to rotate mule shoe into 7"casing W/O success.POOH with BHA#94. 21:00 23:15 2.25 0 0 PROD1 WELLPF WAIT X wait on town to discuss well plan forward. Page 48 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:15 00:00 0.75 0 PROD1 WELLPF BHAH X Upload equipment. Make up BHA# 95. 2 7/8 mule shoe. 06/29/2015 Continue to clean out Tbg with Eline. Fluid loss daily=9 Total loss=352 00:00 00:15 0.25 0 13 PROD1 WELLPF BHAH X Continue to make up BHA#95 00:15 00:30 0.25 13 355 PROD1 WELLPF TRIP X RIH with BHA#95 00:30 01:00 0.50 355 359 PROD1 WELLPF OTHR X Attempt to get mule shoe to drop into 7"casing stump.Tagged @ 359 ft. 01:00 01:30 0.50 359 357 PROD1 WELLPF CIRC X Pumped 10 BBL hi-vis sweep. followed with 10 bbls 98.4 brine, 10 bbls 9.4 filtered brine. 01:30 02:00 0.50 357 357 PROD1 WELLPF ELNE X Pick up lubricator&PT 500 psi. 02:00 03:45 1.75 357 357 PROD1 WELLPF ELNE X RIH with Camera logged tbg. coupling @ 359 ft looks good. continue down with camera. sat down @ 440 ft. POOH with Camera. remove camera and install 1 11/16" CCL with bull nose for tbg drift. 03:45 04:45 1.00 357 357 PROD1 WELLPF WAIT X Wait on 2" slickline magnet. Possible milling junk in tbg @ 440 ft 04:45 05:00 0.25 357 357 PROD1 WELLPF FLOG X Make up magnet and RIH to 359 ft. Worked magnet. Unable to get into the tbg stump. POOH 05:00 05:15 0.25 357 357 PROD1 WELLPF FLOG X Hung back lubicator 05:15 05:30 0.25 357 0 PROD1 WELLPF TRIP X POOH with 2 7/8 Mule shoe 05:30 07:15 1.75 0 359 PROD1 WELLPF TRIP X RIH with 2 7/8 EUE 8rd pup on DP. Attempt to get the tread end past the ledge.Work string with rocking, right and left hand turns, and pump pressure to get past the ledge, no success. POOH, inspect the 2 7/8" pup threads on pin end. Good shape. Run back in hole of a second attempt,with no success. 07:15 07:30 0.25 359 0 PROD1 WELLPF TRIP X POOH with 2 7/8 pup assembly 07:30 08:00 0.50 0 0 PROD1 WELLPF WAIT X Discuss options with Town Eng. 08:00 08:30 0.50 PROD1 WELLPF FLOG X Rig down flow nipple on stack. Install dutch riser assembly, lock down same. 08:30 08:45 0.25 PROD1 WELLPF SFTY X Held PJSM with Crew and E-line reps. Discuss safety and hazard recognitio issues. Discuss procedure to rig up and run MFC run. Page 49 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:45 11:30 2.75 0 0 PROD1 WELLPF ELOG X Make up Wireline tools. Breakout and lay down camera run assembly, and make up MFC caliper assembly. Wireline in hole with centralizer assembly, and could not get past 356'.WLOH. Drop centralizer and run with rigid assembly. Stopped at 356'.WLOH.Attempt one more run adding a knuckle assembly to the MFC run.Wireline stopped again at 356'. WLOH, breakout and lay down MFC tools. 11:30 12:00 0.50 PROD1 WELLPF RURD X Nipple down the dutch riser assembly, and rig up flow nipple. 12:00 14:00 2.00 0 0 PROD1 WELLPF TRIP X We cut a cut lip guide in a pin end of the 2 7/8"pup jnt. Trip in hole with pup,and set down on ledge at 355'. Work cut lip to the right and observe pin end fall off. Continue down to tag on top of the 2 7/8"box looking up at 359'. Break circulation and pump 5 BBLS to wash the top off.Attempt to screw into box, with 2 1/2 threads caught,working right torque to 1200 FT/lbs, and observed pin end,twisted out. Pick up and verify not screwed in. POOH, inspect pin end of pup observing that the pin end indicated screwed in, but threads had rounded out. Cut lip damaged. NOTE: Last camera run indicated with sideview snapshots that the 2 7/8"collar at 359',was intact and could be screwed into. 14:00 15:00 1.00 PROD1 WELLPF BHAH X Lay down damaged 2 7/8" pup. Make a new cut lip guide on a new pup joint. Make up to DP. 15:00 17:00 2.00 0 359 PROD1 WELLPF TRIP X Trip in hole with secong cut lip guide on 2 7/8"pup jont.Work through ledge again at 355', and slack off to attempt to engage 2 7/8"collar looking up. screwed into tbg stump. 17:00 18:00 1.00 359 359 PROD1 WELLPF ELNE X Pick up lubricator and PT to 500 psi. 18:00 18:30 0.50 359 359 PROD1 WELLPF ELNE X RIH with 2.0 slick line magnet. worked @ 359.0 ft to attempt to clear debris from Tbg. Taking 800 lbs over..POOH 18:30 19:00 0.50 359 359 PROD1 WELLPF ELNE X RD Eline. 19:00 00:00 5.00 359 359 PROD1 WELLPF WAIT X Call out slick line to complete cleaning out of the tbg.Wait on crew do to timed out work limits. 36/30/2015 run slick line to attempt to clear debris out of Tbg Fluid loss daily= 17 BBLS Total Loss=369 BBLs. Page 50 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 07:00 7.00 359 359 PROD1 WELLPF WAIT X Continue to wait on slick line crew 07:00 11:00 4.00 359 359 PROD1 WELLPF SLKL X Spot slick line up to rig and rig up. 11:00 12:00 1.00 361 361 PROD1 WELLPF SLKL X PJSM RIH with 2.21"Magnet on a 1 x 15-ft Tool String. Set down at 361-ft slmd. Attempt several times to pass through. Unable to get deeper. POOH. 12:00 13:00 1.00 361 383 PROD1 WELLPF SLKL X Change the bottom tool string. Run in with a 1,73"LIB. Set down at 383-ft slmd. POOH. Nothing note-worthery observed on the LIB. 13:00 16:00 3.00 383 385 PROD1 WELLPF SLKL X Change Tool String to 1 1/4"x 20-ft. Run in with a 1.42"LIB. Set down at 385-ft slmd. POOH. Recovered pipe dope, mettal chips, and fillings on the face of the LIB. Discuss findings with Anchorage Engineering. 16:00 17:00 1.00 385 1,792 PROD1 WELLPF SLKL X Make-up a 1.50"Drive Down Bailer. Run in to 387-ft slmd. Broke through bridge. Continue down to 420-ft slmd. Broke through. Saw bobble at 1,105-ft slmd. Continue down to 1,792-ft(SSSV area). Unable to pass by. Work BAiler several time. POOH. 17:00 18:00 1.00 0 361 PROD1 WELLPF SLKL X RIH with 2.12 magnet unable to get past361 ft. POOH 18:00 19:30 1.50 361 1,792 PROD1 WELLPF SLKL X RIH with 1.5 magnet. No recovery 19:30 20:00 0.50 0 1,792 PROD1 WELLPF SLKL X RIH with 1.5 tbg broch. small metal shavings on broch 20:00 20:45 0.75 0 1,796 PROD1 WELLPF SLKL X RIH with 2 prong 1.5 spear.worked down to 1796 from 1792.got a good over pull. POOH prongs twisted and chipped one prong. 20:45 00:00 3.25 1,792 1,792 PROD1 WELLPF SLKL X RIH with 1.5 magnet. recovering metal shavings. Made multiable runs with same recovering shavings 07/01/2015 Continue to cleanout tubing with slick line. bailing out fill 00:00 01:30 1.50 1,792 1,792 PROD1 WELLPF SLKL X Continue to run 1.5 mag net @ 1792 ft recovering metal shavings 01:30 02:30 1.00 1,792 1,793 PROD1 WELLPF SLKL X RIH with side shaft 1"spear.worked down to 1793 ft.working mill cuttings ball. 02:30 03:30 1.00 0 1,793 PROD1 WELLPF SLKL X RIH with 1.5 magnet.worked at 1793 ft POOH 03:30 04:00 0.50 0 388 PROD1 WELLPF SLKL X RIH with 1.75 pump bailer.worked bailer. Recovered a small amount of formation gravel. 04:00 07:00 3.00 0 1,793 PROD1 WELLPF SLKL X RIH with 1.5 bailer.worked bailer POOH recovered sand and metal shavings. continue to run bailer Page 51 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:00 10:00 3.00 1,793 1,793 PROD1 WELLPF SLKL X S-Line Crew Change. Tie new rope socket. Run in with a"slick"Spear and attempt to knock debris free at 1,793-ft slmd. POOH. Run in with a 1.42" Magnet. Set down at 1,793-ft. POOH. Recovered metal fillings. Re-run same to 1,793-ft. POOH recovered metal fillings 10:00 12:00 2.00 1,793 0 PROD1 WELLPF SLKL X Pick-up a 1.50"Hydrostatic Bailer. Run in 385-ft. Work to pass buy. Set down at 1,793-ft. Work Bailer. POOH. Bailer empty...most likely sheared earlier up hole at 385-ft. Observed"dings"on the end of the Bailer. Run back in with the 1.50" Pump Bailer while re-dressing the Hydrostatic Bailer. POOH with the Pump Down Bailer. Recovered pea-size and larger sized pieces of gravel. 12:00 13:30 1.50 1,793 1,794 PROD1 WELLPF SLKL X Run in with 1.50"Drive Down Bailer. Set down at 1,793-ft slmd. "Hand-Spang"to work the Drive Down Bailer. Gained—1-ft. POOH. Recovered tea-cup of mud, sand, and a few metal slivers. Run with a 1.50" Hydrostatic Bailer. Set down at 1,794=ft. Work bailer. POOH. Recovered several rocks. Run in with the 1.50" Drive Down Bailer. "Hand Spang"to work the Drive Down Bailer. POOH. Recovered a coffee cup of mud,sand, and a few pebbles. Run in with the 3/4" Slick-Spear. Set down at 1,794-ft. Work Spear and attempt to poke a _ hole into the debris.. 13:30 15:00 1.50 1,794 1,794 PROD1 WELLPF SLKL X RIH with pcket poker worked @ 1794 ft POOH 15:00 16:00 1.00 1,794 1,794 PROD1 WELLPF SLKL X RIH with pump bailer 1.5"worked @ 1794 ft POOH. Rocks and metal _ recovered 16:00 17:00 1.00 1,794 0 PROD1 WELLPF SLKL X RIH with drive down bailer worked @ 1794 ft. POOH recovered rocks/ metal shavings 17:00 18:15 1.25 0 1,792 PROD1 WELLPF SLKL X RIH with 1.5" Hydostatic bailer. worked baiker 1792 ft. POOH with bailer no recovery 18:15 19:15 1.00 1,792 1,794 PROD1 WELLPF SLKL X RIH with Pocket poker worked from 1792'to 1794'. POOH 19:15 21:15 2.00 1,792 1,792 PROD1 WELLPF SLKL X Made multiable runs with pump bailer 1.5"X 10 ft bbl.worked bailer @ 1792 ft. POOH recovered sand and metal 21:15 22:15 1.00 1,792 1,794 PROD1 WELLPF SLKL X RIH with pocket poker worked from 1792 to 1794 ft. POOH Page 52 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:15 00:00 1.75 1,792 1,792 PROD1 WELLPF SLKL X RIH with 1.5"pump bailer worked @ 1792.0 ft POOH recovered. sand and metal shavings 07/02/2015 Continue to clean out Tbg with slick line. Current depth= 1793.0 ft. line parted with 2.18 mule shoe @ 392 ft. 00:00 01:30 1.50 1,792 1,792 PROD1 WELLPF SLKL X Continue to run 1.5"pull pump bailer working @ 1792. ft. Recovering formation and metal shavings 01:30 02:00 0.50 1,792 1,792 PROD1 WELLPF SLKL X RIH with 1.5 magnet small amount of shavings recovered. 02:00 03:00 1.00 1,792 1,792 PROD1 WELLPF SLKL X RIH with Pocket poker worked down to 1796 ft. POOH 03:00 05:00 2.00 1,793 1,793 PROD1 WELLPF SLKL X RIH with 1.5 pump bailer.worked at1793 ft. Multiable runs recovering formation gravel/sand and metal shavings. 05:00 06:00 1.00 1,794 1,796 PROD1 WELLPF SLKL X RIH with pocket poker.Worked down from 1793 ft. to 1,796-ft slmd. POOH. 06:00 07:00 1.00 1,793 1,793 PROD1 WELLPF SLKL X Run in with the 1.50"Pump Down Bailer. Set down at 1,793-ft slmd. Work Bailer. POOH. Recovered a few pebbles. Ding marks on the end of the Bailer. 07:00 10:30 3.50 1,793 1,796 PROD1 WELLPF SLKL X S-Line Crew change-out. Run in with the 1.50" Drive Down Bailer. Set down at 1,793-ft. Hand spang and work down to 1,795-ft. POOH. No recovery. The end of the Bailer had ding marks on it. Decide to try the 1.750"Sample Bailer(larger throat ID). Run in with same. Saw a "bobble"at 387-ft. Set down at 1,795-ft. Hand spang and worked hard to get down to 1,796-ft. POOH. No recovery. Leading edge of the Bailer had a flattened section. It appears that we are"spanging"down on something hard and too large to enter the bailer. 10:30 12:30 2.00 1,797 1,800 PROD1 WELLPF SLKL X Make-up a 3-ft x 0.62" Pocket-Poker (aka, paraffin scratchier)with several braided wire whiskers sticking out the sides. Run in with same. Got the end to pass by the obstruction at 1,797-ft down to 1,800-ft pass. However,the 1.50" top of the Pocket Poker set down at 1,797-ft. Attempt to move the obstruction by working the 3-ft section back and forth. POOH. Page 53 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:30 13:30 1.00 0 0 PROD1 WELLPF WAIT X Discuss a couple of other tool options with the Anchorage Engineer and HES S-Line support. Also decided to address the possibility of getting a swage through and slightly open up the 2 7/8"tubing kink at —364-ft. This would allow for a larger and a heavier tool string to be used and hopefully get down to the obstruction at 1,794-ft. This would give us more size options and weight to work with. 13:30 14:30 1.00 0 1,794 PROD1 WELLPF SLKL X Run in with a 2.24"Tapered Swage. Set down at 364-ft. Hand spang through and continue on down to 1,794-ft slmd. POOH. Add a 3-ft piece of 2.125"Weight Bar just above the 2.24"Swage. Run in to 364-ft. Hand Spang through and continue down to 1,793-ft. POOH. 14:30 15:00 0.50 0 0 PROD1 WELLPF SLKL X Cut off 300-ft of wire. Tie on a new rope socket. Swap the tool string from 1 1/4"over to 1 1/2". 15:00 16:00 1.00 360 1,795 PROD1 WELLPF SLKL X Run in with a 2.35"Swage an attempt to further open the"kink". No-Go. Abort any further attempt. Run in with a 2"Drive Down Bailer. Set down at 1,793-ft Hand spand down to 1,795-ft. POOH. No recovery. End of the Bailer was flatten and rolled over. 16:00 17:30 1.50 1,795 1,795 PROD1 WELLPF SLKL X RIH with 1.45 pocket broch.Worked spank jars a1795 ft POOH broch show side impact. 17:30 19:00 1.50 1,793 1,795 PROD1 WELLPF SLKL X RIH with center guide wire cutter. worked down to 1795.5 ft pooh wires bent 19:00 20:00 1.00 1,793 1,794 PROD1 WELLPF SLKL X RIH with side wire rope spear.tagged @ 1793 worked to 1794. POOH 20:00 21:00 1.00 1,793 1,793 PROD1 WELLPF SLKL X RIH with 2.18 Bell guide with 1.75 3 prong spear insde.worked @ 359 ft to get into tbg. continue to RIH tagged and worked @ 1793 ft POOH. 1 prong on wire grab is bent out. 21:00 22:00 1.00 1,793 1,801 PROD1 WELLPF SLKL X RIH with 10 ft of 1"bar&split shot drift.worked down from 1793 to 1801 ft.tight in and out.. POOH end of bar bent in. 22:00 23:00 1.00 1,793 1,794 PROD1 WELLPF SLKL X RIH with 1.25"X 10 sinker bar drift asemmbly. Tagged @ 1793 ft worked down tp 1793.5 150 lb over pull to get free. POOH. Bar bent in Page 54 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:00 00:00 1.00 1,793 392 1PROD1 WELLPF SLKL X RIH with 2.81 bell guide.Worked down @ 1793 ft and jarred free with spank jars. POOH dragging at Tbg couplings. got tool string to 392 ft. rope socket @ 365-.tools hung up attempted to work spanks. No action at spanks pulled 500 over pulled out of rope socket. 37/03/2015 Attempted to fish lost slick line tool string. Unable to get past 1794 ft tools not at that level. RD slick line. RU Eline RIH with string shot. Shot from 468.5 to 472.5. RIH with RCT mad cut @ 471 ft. POOH tools hung up strip tools out of hole Daily fluid loss= 14 bbls Total loss=412 bbls 9.4 brine 00:00 00:30 0.50 392 PROD1 WELLPF SLKL XT Laid down lubicator. all of the tool string is in hole. 00:30 02:30 2.00 PROD1 WELLPF SLKL XT Collect new slick line tools and addtional lubicator sections. Off pad 02:30 06:00 3.50 PROD1 WELLPF SLKL XT Re pack stuffing box to except.125 line.Re-head rope socket on .125 line.Add section to lubricator. make up 2.0" RS pulling tool assembly actual OD of the pulling tool is 1.75"). 06:00 07:30 1.50 PROD1 WELLPF SLKL XT Run in with the 2" RS Pulling Tool looking for the top of the fish(OAL= 31.5-ft...expected top of the fish= 1,762-ft). Did not find top fish at the expected depth. Continue on in. Set down at 1,791-ft slmd. Hand spang fishing tools...no spang jar action...mushey. Continue to work fishing tool. POOH. Lip of the RS Pulling Tool pinched in ward from the tight area in the tubing. Unable to find the fish. It appears at this point that the dropped tool string,due to the high speed free fall, passed through the tight section in the tubing and has continued on down hole...however,we are un able to get passed the tight spot with the fishing tools to find the top of the fish. 07:30 12:00 4.50 PROD1 WELLPF SLKL XT Rig down S-Line equipment and release Unit. (SIMOPS...clear and clean floor. Perform Top Drive inspection). 12:00 15:00 3.00 PROD1 WELLPF ELNE X Move in and rig up HES E-line Unit and equipment. Transport explosives for the string shot from Deadhorse. 15:00 15:15 0.25 PROD1 WELLPF SFTY X PJSM with AII. Discuss the Hazards with rigging up the Lubricator, Tool String. Encourage the use of "hand-free"tools during the rig-up. 15:15 17:00 1.75 PROD1 WELLPF ELNE X Continue with E-Line rig-up. PT lubricator to 500 psi. Page 55 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 20:00 3.00 0 471 PROD1 WELLPF ELNE X RIH with string shot.set shot @ 468.5 to 473.5 ft POOH. Pick up 1.64 RCT cutter. RIH Made cut© 471 ft. POOH tool string hung up© 361.5 ft. Unable to work free. Circulated @ 5 BPM @ 360 psi to attempt to dislodge tool string without success. 20:00 21:00 1.00 PROD1 WELLPF WAIT XT Discussed option with town. 21:00 22:30 1.50 PROD1 WELLPF WAIT XT Wait on wire rope clamps for stripping out. 22:30 00:00 1.50 471 440 PROD1 WELLPF OTHR XT PJSM with all personal. Began stripping out of hole with DP/wire line 07/04/2015 recovere Eline tools. attempted to spear tbg stump @ 359 ft W/O success. RIH with 2 7/8 X 4"poorboy string mill. unable to get into casing stump©355. ft. Fluid loss daily=3 bbls. Total loss=415 bbls 9.4#Brine 00:00 01:30 1.50 440 260 PROD1 WELLPF OTHR X Continue to strip out of hole with DP &wire line. Tools out @ 00:45 hrs. Broken stabilizer band. Clear floor of E-line tools 01:30 02:30 1.00 260 0 PROD1 WELLPF TRIP X Continue to POOH with drill pipe and 2 7/8 EUE 8rd tbg. No addtional tbg recovered. Pin pull on mule shoe pup. 02:30 03:00 0.50 0 PROD1 WELLPF WWWH X Wash BOPE 03:00 04:30 1.50 PROD1 WHDBO RURD X Pull wear ring set test plug. 04:30 05:30 1.00 PROD1 WHDBO BOPE X Shell test BOPE 250/2500: 05:30 10:30 5.00 PROD1 WHDBO BOPE X Perform the weekly BOPE test as per ConocoPhillips/AOGCC requirements at 250/2,500 psi with a 3 1/2"Test Joint. Perform Koomey drawdown test. Test gas alarms. The State's right to witness the test was waived by AOGCC Field Inspector J. Jones. 10:30 12:00 1.50 PROD1 WHDBO RURD X Pull test plug. Install wear bushing. (SIMOPS rig down test equipment) 12:00 12:30 0.50 0 16 PROD1 WELLPF BHAH X Pick-up BHA#99...2 7/8"Tubing Spear. 12:30 13:00 0.50 16 355 PROD1 WELLPF TRIP X Trip in BHA with 3 1/2"Drill Pipe. Tag to damaged 7"Casing section at 355-ft dpmd. 13:00 13:30 0.50 355 359 PROD1 WELLPF FISH X Work passed the damaged casing. Tagged the top of the 2 7/8"Fish(?) at 359-ft dpmd. Work to get Spear inside of the fish. Spear swallowed —1-ft...unable to get deeper. 13:30 13:45 0.25 359 16 PROD1 WELLPF TRIP X Trip out with BHA standing the 3 1/2" back in the derrick. Page 56 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:45 14:15 0.50 16 0 PROD1 WELLPF BHAH X BHA at surface. No recovery. Inspect Spear. Grapple packed with drilling mud (quite possible Spear went beside the fish). Clean grapple. 14:15 14:30 0.25 0 355 PROD1 WELLPF TRIP X Trip back in with same BHA on 3 1/2"Drill Pipe. Tagged the damaged 7"Casing. 14:30 15:30 1.00 355 359 PROD1 WELLPF FISH X Work past the 7"damage casing. Once again tagged the top of the 2 7/8"fish at 359-ft dpmd. Continue to work to find the right angle to spear the 2 7/8"Tubing. (order out a Spear Assembly Mule Shoe and a 2 7/8" 8rd box X 2 7/8"Reg pin from BFT). 15:30 15:45 0.25 359 0 PROD1 WELLPF TRIP X Trip out with the BHA, standing back the 3 1/2"Drill Pipe in the Derrick. 15:45 16:00 0.25 PROD1 WELLPF BHAH X BHA at surface. No recovery. Inspect Spear Assembly. Once again Grapple area was packed with drilling mud. Clean up Grapple. Load a joint of 2 7/8"Tubing in the Pipe Shed. 16:00 21:00 5.00 PROD1 WELLPF WAIT X Wait on Mule Shoe and XO to re-configure the Spear Assembly. 21:00 22:00 1.00 0 359 PROD1 WELLPF TRIP X RIH with BHA# 101 C-spear assembly with mule shoe. &2.44 grapple. Attempted to get spear on Tbg side of 7"casing with out success. 22:00 22:15 0.25 359 0 PROD1 WELLPF TRIP X POOH spear stop indicated that it had been setting on the casing ledge. 22:15 22:30 0.25 0 19 PROD1 WELLPF BHAH X measure and pick up 2 7/8 mule shoed/poor boy string mill 4" 22:30 22:45 0.25 18 358 PROD1 WELLPF TRIP X RIH with BHA#102 22:45 00:00 1.25 358 364 PROD1 WELLPF MILL X Tag with mill @ 356 ft. Shoe @ 358.0 sat 3 K on mill. Est Parameters. FT @ 45 RPM's=550 Ft/Lb's. Circulating @ 3BPM @ 56 psi. Engadged torque @ 600-650 FT/LB's Got back formation . 37/05/2015 Ran camera to guide in mill to 356 ft casing stump dress up 354-356 w/3 1/8 Mill. RIH with Tbg spear. attempt to fish Tbg stump. Changed out spear assembly to flush set up.Attempt to fish tubing. Daily fluid loss=6 BBIs Total loss=421 BBL's of 9.4 Brine 00:00 00:30 0.50 352 352 PROD1 WELLPF WAIT X Wait on HES and EV 00:30 03:30 3.00 352 352 PROD1 WELLPF ELOG X RU HES to run camera to assit in guiding mule shoe into 7"casing. 03:30 04:15 0.75 352 352 PROD1 WELLPF ELOG XT Had to trouble shoot EV camera 04:15 05:00 0.75 352 357 PROD1 WELLPF ELOG X RIH with Camera. Mule shoe slid down the out side of the 9 5/8 casing. POOH hung back lubricator 05:00 05:15 0.25 352 355 PROD1 WELLPF TRIP X Adsjust drill pipe down to 355 ft Page 57 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:15 06:15 1.00 355 355 PROD1 WELLPF ELOG X Pick up lubricator and RIH with camera to 355.29-ft. Record clear pictures of the 7"Casing damage (ledge). However,when easing deeper with the camera, it follows the path to the out side of the ledge. Attempted several times to get the camera to go inside the 7"Casing with no success. POOH. 06:15 07:00 0.75 355 355 PROD1 WELLPF ELOG X Set back Tools String and Lubricator. 07:00 07:15 0.25 355 357 PROD1 WELLPF TRIP X Adjust Drill Pipe depth. Tagged the ledge and attempt to"roll"the mule shoe over the 7"Casing ledge and into the 7"Casing to 357-ft. 07:15 08:00 0.75 357 359 PROD1 WELLPF ELOG X Stab Tool String, Camera, and Lubricator back on Drill Pipe. Run back in with Camera to the end of the Mule Shoe at 357-ft. Ease Camera below the Mule Shoe to 358-ft. Record the top of the 2 7/8" Tubing Collar. Ease down to the top of the 2 7/8"fish at 359-ft. Clear video/pictures recorded. The off centered tubing collar has a few minor dings on the top, but other wise in good condition. POOH. _ 08:00 09:45 1.75 359 359 PROD1 WELLPF ELOG X Set back Tools String and Lubricator. Down load video/pictures. Discuss finding with Anchorage Engineer and a plan forward. 09:45 10:30 0.75 359 0 PROD1 WELLPF TRIP X Trip out with BHA #102...4"Carbide Mule Shoe Joint. Scribe Drill Pipe. Stand the 3 1/2"Drill Pipe back in the Derrick. 10:30 11:00 0.50 0 0 PROD1 WELLPF BHAH X Change BHAs Lay down the 4" Carbide Mule Shoe Joint and pick up the 3 1/4"Carbide Mule Shoe Joint. 11:00 11:30 0.50 358 PROD1 WELLPF TRIP X Trip in with BHA#103 on 3 1/2"Drill Pipe...follow the scribe marks to align Mule Shoe past the 7"Casing damage. Did not see the 7" damage...it appears we entered the 7"Casing with no problem. 11:30 12:30 1.00 358 358 PROD1 WELLPF ELOG X Stab Tool String, Camera, and Lubricator back on Drill Pipe. Run back in with Camera to the end of the Mule Shoe at 358-ft. Ease Camera to 359-ft. Record the top of the 2 7/8"Fish and confirm that we have entered the 7"Casing once again. POOH. 12:30 14:00 1.50 358 358 PROD1 WELLPF ELOG X Rig down EV Camera,Tool String and Lubricator. Clear floor. (Prep for milling operations). Send E-line Crew back to camp. Page 58 of 67 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 14:00 15:30 1.50 358 358 PROD1 WELLPF MILL X Mill on the 7"Casing ledge at 355-ft with the 3 1/4"Carbide Poor-Boy Mule Shoe joint. Milling parameters as follows: RPMs=63, Torque= 500 ft/lbs, Pump Rate=3.0 bpm/50 psi. Shave off the ledge out to 3 1/4". Reciprocate the 2-ft Carbide section across the ledge several times. Never saw any aggressive work or torque. 15:30 16:00 0.50 358 19 PROD1 WELLPF TRIP X Trip out with BHA#103, standing the 3 1/2" Drill Pipe back in the Derrick. BHA to surface. 16:00 16:15 0.25 0 15 PROD1 WELLPF BHAH X Lay down BHA#103. Inspect the carbide section of the Poor-Boy Mule Shoe joint(no wear noted on the Carbide section...condition remains like new). Make up BHA#104 as follows: C-Spear, Spear Extension, Spear Extension,XO,XO. 16:15 16:30 0.25 15 359 PROD1 WELLPF TRIP X Align the Spear mule shoe with the Drill Pipe scribe lines. Trip BHA #104 in on 3 1/2"Drill Pipe from the Derrick. 16:30 17:30 1.00 359 359 PROD1 WELLPF FISH X Enter the 7"Casing with the Spear Assembly. Work to find the top of the 2 7/8"Fish and plant the Spear. No success. 17:30 18:00 0.50 359 0 PROD1 WELLPF TRIP X POOH with BHA#104 18:00 18:45 0.75 0 13 PROD1 WELLPF BHAH X Load tally and pick up BHA#105. flush spear assembly. 18:45 19:00 0.25 13 355 PROD1 WELLPF TRIP X RIH wth BHA 105. 2 5/16 ITCO spear assembly with 2.44 Nom.graple. 19:00 20:15 1.25 355 362 PROD1 WELLPF FISH X Attempted to engage spear with out success. dropping down to 362 ftable to rotate above TOF @ 359.5 ft once along side we torque up. 360.5 to 362' 20:15 20:30 0.25 362 0 PROD1 WELLPF TRIP X POOH with BHA#105. Spear packed with mud 20:30 23:15 2.75 0 0 PROD1 WELLPF WAIT X Wait on cross over from 9ES 23:15 23:45 0.50 0 49 PROD1 WELLPF BHAH X Reconfigure spear assembly W/a jt of 2 7/8 8rd above. 23:45 00:00 0.25 49 355 PROD1 WELLPF TRIP X RIH with BHA 106 07/06/2015 Spaced out tbg. Tail @ 6026 ft. Pumped Hi-vis sweep Cal depth=seals on .Wait on Cementers. RU Schlumberger Daily fluid loss= 12 BBLS Total loss=433 BBL's 9.4 Brine 00:00 01:45 1.75 355 362 PROD1 WELLPF FISH X Engaged Tbg stump set grapple. Picked up on Tbg. No cut made. Work string up 110 K with block weight 80%of pulling cap.on J-55 Tbg.Worked 80K-110 K jarring on seals. Pulled free. Up weight 68 K. ����� Page 59 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:45 02:00 0.25 362 129 PROD1 WELLPF TRIP X POOH with 3 std dp. 02:00 03:30 1.50 129 129 PROD1 WELLPF WAIT X Wait on GBR tong hand. 03:30 04:30 1.00 129 0 PROD1 WELLPF RURD X RU GBR tongs and handling equipment. 04:30 05:00 0.50 6,004 5,583 PROD1 WELLPF PULL X Laid down the top 4 jts of 2 7/8 8rd to remove the cut area. 05:00 07:45 2.75 5,583 5,583 PROD1 WELLPF PULD X Pick up 5 jts of 2 7/8 EUE 8rd tbg. Discuss plan forward with Anchorage Engineer. 07:45 08:00 0.25 5,583 5,583 PROD1 WELLPF CIRC X Break circulations as follows: 1.0 bpm/115 psi. 2.0 bpm/330 psi. 08:00 08:45 0.75 5,583 6,026 PROD1 WELLPF TRIP X Crossover to Drill Pipe. Run stands from the Derrick and ease in the hole to the PBR. Bring pump on line at 1/0 bpm/119 psi. Observe pump pressure increase to 158 psi and the Seals entered the PBR. End pump. Set back the working stand of Drill Pipe. Leave the end of the Seal Assembly parked at 6,026-ft(top of the PBR at 6,057-ft) 08:45 11:45 3.00 6,026 6,026 PROD1 WELLPF CIRC X Circulate well bore 1 1/2 times with 9.4 lb/gal Brine at 3.8 bpm/955 psi (observe some drilling mud, gravel, and mill cuttings at bottoms-up). Total bbls pumped=326.Total fluid loss"0"bbls. Re-zero stroke counter. Bring pump on line with a Hi-Vis Gel sweep. 3.9 bpm/733 psi. Hi-Vis sweep start out the end of the tubing at 4.0 bpm/670 psi. End Hi-Vis sweep with 41.8 bbls pumped. Continue to displace sweep back to surface with 9.4 lb/gal Brine at 3.8 bpm/935 psi. Observe a trace(-1% volume)of early sweep returns after a total stroke count of 1,600 sks(92 bbls...Sweep plus 9.4 lb/gal Brine). Observe lead sweep returns at shaker with 100 strokes early(5.7 bbls). Returns=mill cuttings, sludge, small gravel/sand. Continued displacing until clean. Shut down pump. 11:45 23:30 11.75 6,026 6,026 PROD1 WELLPF WAIT X Discuss circulating results with Anchorage Engineer. Anchorage Engineering Team developing a Cementing program. Order out Cement Silos. and cementing equipment. 23:30 00:00 0.50 6,026 6,026 PROD1 WELLPF RURD P RU Schlumberger to cement 07/07/2015 Pumped a balanced Cement Plug with an expected top at 1,800-ft.Wait on cement. Daily fluid loss=0 BBLS Total loss=433 BBL's 9.4 Brine Page 60 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:00 2.00 6,026 1,800 PROD1 WELLPFCMNT P PJSM: Balanced plug 6026 ft to 1800 ft. Pumped 5 BBLS of Mud flush ahead. PT 1500 psi./3500. continue with 10 more BBLs of mud flush, 152 bbls of G cement W/.2%D046, .3% D065,.4% D167, .015 Gal/sx D177. Displaced with 5 BBIs mud flush, 5 bbls 9.4 Brine. Cement in place @ 01:55 hrs. Pump Pressure thru job @ 2 BPM @ 250 PSI. 02:00 03:30 1.50 0 0 PROD1 WELLPF RURD P RD Schlumberger cementers. 03:30 00:00 20.50 0 0 PROD1 WELLPF WOC P Wait on cement 07/08/2015 Wait on cement. Rig-up Digital S-Line. Tag Cement top @ 1675'witnessed by AOGCC Rep Lou Grimaldi. Jet cut 2 7/8"Tubing. Rig-down Digital S-Line. POOH 1 Drill Pipe joint. Spot SLB trucks. 00:00 12:00 12.00 0 0 PROD1 WELLPF WOC P Continue to wait on cement. Digital S-Line Unit arrives on Location. 12:00 12:15 0.25 0 0 PROD1 WELLPF SFTY P PJSM. Discuss rig-up hazards. Review the planned operations. 12:15 15:00 2.75 0 0 PROD1 WELLPF SLKL P Spot Unit. Off load equipment and bring to the floor. Make up Lubricator and Tool String(max O.D. 2 1/4"Gauge Ring). 15:00 17:30 2.50 0 0 PROD1 WELLPF SLKL P Pick up tool string. Stab Lubricator on the Tubing(pressure test same). Run in with 2 1/4"Gauge Rig. Found the Top of Cement at 1,675-ft (expected calculated TOC= 1,800-ft). The tag was witnessed by AOGCC Field Inspector, Lou Grimaldi. Pull out and log tubing collars. 17:30 19:30 2.00 0 1,660 PROD1 WELLPF SLKL P PU 2-1/8"cutter and RIH. Collar @ 1642'elmd. Next collar at 1674'(not logged). contact CPAI Engineer decision to cut at 1660'elmd. Positive indications of cut in DSL unit. Log collars out of hole. 19:30 20:00 0.50 1,660 1,660 PROD1 WELLPF SLKL P Rig Down DSL Lubricators and equipment. 20:00 20:30 0.50 1,660 1,633 PROD1 WELLPF FISH P POOH w 1 joint of Drill Pipe to 1633' and set in slips.Worked up to 80% of tubing. on second time cut pulled in two at—90k.Attempted to circulate, no path and held 1100 psi.Attempted to pull and Observed 35k drag and after—20' it went to about 5k-10k overpull. Set in slips with cut location at 1632'. Page 61 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:30 21:45 1.25 1,633 1,633 PROD1 WELLPF CIRC P Circulated at 1.5 bpm and observed circulation established at 240psi. Continued to work rate up to 6 bpm. Contacted CPAI Engineer decision to circulate 3 hole volumes to open up circulation path in cement on backside above cut. Contact SLB Cementers to mobilize to location. Circulate 190 bbls @ 6 bpm ICP 575 psi FCP 530psi. 3 bpm FCP 140 psi. 21:45 22:15 0.50 1,633 1,633 PROD1 WELLPF SLKL P Rig Down remainder of DSL equipment and lubricator. 22:15 23:45 1.50 1,633 1,633 PROD1 WELLPF WAIT P Wait on SLB Cementers on way from Deadhorse. 23:45 00:00 0.25 1,633 1,633 PROD1 WELLPF RURD P Spot up Cement trucks and lines.. 37/09/2015 Rig Up SLB Cementers. Pump balanced plug from 1633'to 400'. Rig Down SLB Cementers. Wait on Cement. Rig-up Digital S-Line. Tag Cement top @ 491'witnessed by AOGCC Rep Matt Herrera. Jet cut 2 7/8"Tubing. Rig-down Digital S-Line. POOH. Rig-up GBR. Lay down 2 7/8"Tubing. Rig-down GBR. PU 7"MSC and RIH. Cut 7". POOH and Lay Down MSC Cutter. Nipple Down BOP stack and Tubing Head. Remove packoff. Nipple Up BOP Stack. 00:00 01:30 1.50 1,633 1,633 PROD1 WELLPF RURD P Rig Up Cement Trucks and cement lines for pumping balanced plug. 01:30 01:45 0.25 1,633 1,633 PROD1 WELLPFSFTY P PJSM for pumping balanced plug 01:45 02:30 0.75 1,633 1,633 PROD1 WELLPF CMNT P Pump balanced cement plug from 1633'to 400' MD. PT lines to 1500/3500 psi. pump 12.1 bbls lead water 2 bpm @ 210 psi, 42 bbls 15.7 ppg class"G"AS-1 cement 3 bpm @ 220 psi,4 bbls chase water 3 bpm @ 370 psi. Cement in place at 02:33. 02:30 04:00 1.50 1,633 1,633 PROD1 WELLPF RURD P Rig Down SLB Cementers and lines. Monitor well during rig down, no significant U-Tubing from original placement of balanced plug. 04:00 08:00 4.00 1,633 1,633 PROD1 WELLPF WOC P Wait on Cement to set up. Page 62 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:00 12:00 4.00 1,633 491 PROD1 WELLPFSLKL P Rig up DSL. Pick-up Lubricator. Pick-up Tool String. Pressure test Lubricator at 1,500 psi. Rub in with a 2 1/4"Gauge Ring. Tagged the top of cement at 493-ft, (-0.54 bbls deeper than the expected calculated TOC o 400-ft.). Pull back up into the Lubricator. AOGCC Inspector arrived on Location. Run back in and tag once again at 493-ft. Pull up hole to 300-ft and park Gauge ring. Pressure test the cement plug inside of the tubing at 1,000 psi x 15 minutes(record on chart). Bleed off pressure. Run back in and re-tag the top of the cement 491-ft. TOC tags and the pressure test were witnessed by AOGCC Field Inspector, M. Herrera. Pull out while record tubing collars. 12:00 13:15 1.25 491 360 PROD1 WELLPF SLKL P Lay down the 2 1/4"Gauge Ring and re-configure tool string. Make-up 2 1/8"Jet Cutter. Run in with the Jet Cutter. Re-cord collar tie-in pass. Position Jet Cutter to cut the 2 7/8" Tubing at 360-ft Pull out. 13:15 14:30 1.25 360 360 PROD1 WELLPF SLKL P Jet cutter fired. Lay down Tool String. Set back Lubricator. Pick-up on Tubing...free. Rig down and release Digital S-Line. 14:30 15:00 0.50 360 360 PROD1 WELLPF RURD P Rig up GBR to handle the 2 7/8" Tubing. 15:00 15:30 0.50 360 0 PROD1 WELLPF TRIP P Trip out Standing back 3 1/2" Drill Pipe in the Derrick. Single down 2 7/8"Tubing(3 Joints and a cut-off piece). 15:30 15:45 0.25 0 0 PROD1 WELLPF RURD P Rig down GBR equipment. 15:45 16:00 0.25 0 9 PROD1 CSGRC'BHAH P Make up BHA#107, Baker MS Cutter, Stabilizer,XO 16:00 16:15 0.25 9 318 PROD1 CSGRC'TRIP P Run in with BHA#107 on 3 1/2" Drill Pipe. 16:15 17:00 0.75 318 318 PROD1 CSGRC'CPBO P Position MS Cutter at 318-ft. Establish parameters RPMs=85, Initial pump rate=5.0 bpm/1,100 psi. Made cut in 20 minutes. 17:00 17:30 0.50 318 9 PROD1 CSGRC'PULD P Single down 3 1/2"Drill Pipe. 17:30 18:00 0.50 9 0 PROD1 CSGRC'BHAH P BHA to surface. Inspect knives, knives show normal wear(positive indication of cut). Lay down MS Cutter Assembly. 18:00 19:00 1.00 0 0 PROD1 CSGRC'RURD P Suck out stack. Pull Wear Ring. 19:00 21:00 2.00 0 0 PROD1 CSGRC'NUND P Nipple Down BOP Stack and stand Back on stump 21:00 23:00 2.00 0 0 PROD1 CSGRC'NUND P Nipple Down Tubing Head. Pull Packoffs and inspect slips. Nipple Up two adapter flanges and a spool. Page 63 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:00 00:00 1.00 0 0 PROD1 CSGRC'NUND P Nipple Up BOP Stack. 37/10/2015 Nipple Up BOP Stack. Spear 7"Casing stump. Remove slips. Nipple Up BOP. Lay Down Spear and 7" Casing. Attempt to Test Break in stack. PU Cement Retainer. RIH on 2-7/8"work string. Set Cement Retainer. Pump cement plug squeeze below. Pump Surface cement plug. LD 2-7/8"work string. Nipple Down BOP. Cement Top Job. 00:00 01:15 1.25 0 0 PROD1 CSGRC'NUND P Continue Nipple Up BOP Stack. Tighten bolts. 01:15 01:45 0.50 0 0 PROD1 CSGRC'RURD P Rig Up GBR equipment. 01:45 02:15 0.50 0 0 PROD1 CSGRC'BHAH P Pick Up Spear on drill pipe joint. 02:15 02:30 0.25 0 318 PROD1 CSGRC'FISH P Engage 7""stump with grapple and pull. Observe cut pull free at 80k. Up Wt 37k." 02:30 04:15 1.75 318 318 PROD1 CSGRC'NUND P Break stack and remove slips. set stack back down and torque up bolts on flange. 04:15 04:45 0.50 318 318 PROD1 CSGRC'CIRC P Circulate 75 bbls @ 12 bpm to clear arctic pack and diesel. 9.4 ppg coming out. 04:45 05:15 0.50 318 318 PROD1 CSGRC'BHAH P Lay Down BHA#107-7"casing spear. 05:15 06:30 1.25 318 0 PROD1 CSGRC'PULL P Lay Down 7"Casing joints. Recovered 6 full Joints, one top cut-off joint(36.90-ft), and the bottom cut-off stub(9.50-ft). Total length of 7"Casing recovered=290.96-ft. Note:the cut-off cut was"ragged" but that is because the cut was made at a shallow depth with very little string weight causing the MS Cutter bounce and chatter. 06:30 07:15 0.75 0 0 PROD1 CSGRC'RURD P Rig down GBR 7"equipment. (SIMOPS...Spot and rig up cementers. Load the 9 5/8"Cement Retainer in the pipe shed). Page 64 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:15 10:00 2.75 0 0 PROD1 CSGRC'BOPE P Set the 11"test plug. Attempted several times to get a BOP body break test at 250/2,500 psi. No-Joy. No visible surface flange leaks on the Stack. Test Plug seals are good...it appears that the pressure fall-off is bypassing the plug and going down hole. Discuss with Anchorage Engineer and request a waiver from the AOGCC so we can proceed with the final surface cement plug. Waiver granted by the Anchorage AOGCC Office(e-mail received)...moving forward once again! (an attempt was made to notify one of the AOGCC Field Inspectors on the Slope. No responce...left message on their office phone. Forwarded a copy of the waive correspondence to their North Slope e-mail address). 10:00 10:30 0.50 0 0 PROD1 WELLPF RURD P Rig up GBR 2 7/8"tubing handling equipment. 10:30 11:30 1.00 0 262 PROD1 WELLPF PUTB P Pick-up the Baker 9 5/8"K-1 Mechanical Cement Retainer. Flushed the retainer on surface with fresh water. Single in on 2 7/8" Tubing...found a tight spot in the 9 5/8"Casing (33-ft in from the Rig Floor). Gently rotate and work through (the tight spot depth is very close to kink depth observed in the 7"Casing,just below surface). Continue running in...moving forward once again...! 11:30 11:45 0.25 262 262 PROD1 WELLPF CIRC P Stop at setting depth. Bring pump on line. Confirm circulations at 5.0 bpm/190 psi x 8.0 bbls. 11:45 12:00 0.25 262 262 PROD1 WELLPF PACK P String weight 31,700 Ibs...includes 30K Block weight. Set Cement Retainer...mark pipe, puck up 4-ft, rotate 10 turns to the right, rapidly slack-off down to the setting mark Cement Retainer set. Pick up 25K over string weight. Slack off. Pick-up 40K over string weight. Stack off to neutral. Make-up TIW Valve. 12:00 12:30 0.50 262 262 PROD1 WELLPF SFTY P Pre job safety and operatiions meeting with all. Page 65 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:30 15:30 3.00 262 262 PROD1 WELLPF CMNT P Complete rig-up. Schlumberger on line with fresh water to pressure test line. However, after pumping 0.8 bbls 2600 psi was reached. Trouble shoot surface flow path. Break of from the tubing. Bring C-Pump on line...have full returns. Make back up to the tubing. Tubing pressured up at 800 psi with nil fluid movement. End any further attempt. Un-sting tubing from the Cement Retainer. Bring rig pump on line at 2.0 bpm/55 psi. Good returns x 8.0 bbls. Sting back in. Bring rig pump on at 1.5 bpm/90 psi...trash in stinger??? Rig back up with cement line to the tubing. Bring Schlumberger pump on line with fresh water....moving forward once again! Pump 5.0 bbls Fresh Water, Pressure test line at 2,000 psi, Pump 10 bbls Fresh Water, Start retainer squeeze at 2.2 bpm/50 psi WHP. Continue pumping cement at 2.2 bpm density, 15.78 bl/gal. WHP after 55 bbls pumped, 125 psi. treating pressure,250 psi. No sign of squeezing cement behind the 9 5/8"Casing...just drinking it. Continue mixing and pumping cement. End pumping after 100 bbls away. Final WHP 140 psi, max observed pressure, 150 psi., final rate 2.2 bpm, final density, 15.78 lb/gal(monitored well cellars on either side of 2T-07 and the reserve pit area in front of the well during pumping for any sign on cement broaching to surface...all good). 14:45 hrs...Pick-up and sting out of the cement retainer. Bring cement pump back on line at 2.3 bpm/250 psi treating pressure,40 psi WHP. Cement density 15.8 lb/gal. Saw cement in the returns at 18 bbls away. Continue pumping an additional 2bbls of clean cement. Final sample caught= 15.7 Ib/gal....15:08hrs end. Wash up. 15:30 16:00 0.50 262 0 PROD1 WELLPF PULD P Single down 2 7/8"Tubing. Lay down the Baker Snap Latch Setting Tool. Page 66 of 67 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 20:00 4.00 0 0 PROD1 WELLPF RURD P Flush stack with jetting tool. Pull floor plate and clean rotary table. Clean out under Rotary. Steam table. Blow Down surface equipment. SIMOPS: Rig Down Cementers. 20:00 21:30 1.50 0 0 PROD1 WHDBO NUND P Nipple Down BOPE. Set Stack on pedastal. 21:30 00:00 2.50 0 0 PROD1 WHDBO CMNT P Observe cement—7'below wellhead. Mix Top Job Cement. Fill well with cement until cement is—1.5'from OA Valve. Take Pictures to document top of surface cement plug. 07/11/2015 Nipple Up Tubing Spool and tree. RDMO. RIG RELEASED @ 06:00 00:00 03:30 3.50 0 0 PROD1 WHDBO NUND P Nipple Up Tubing Head, Spool and Dry hole tree. 03:30 06:00 2.50 0 0 DEMOB MOVE RURD P Bridle Up, Blow Down all lines. Complete cleaning pits. Prep for rig move to 1Y-07. RIG RELEASED @ 06:00 Page 67 of 67 , / '''''‘',:::',,,..„ "k\ fi V u Eu h .• 3 N • i n • u •— n. rup 0 _0 O C u :� U O Q. O -- C V L C v, N O (6 bO An 4--• "\,41,,,t Ai . fl) ) " (E x.. •— O 4 ,• � _,1 O O O . r . '# u c ,` • 1i �• �� I r 0 � ` v, -0 a) r -ilk .' F- rad • • a�/ - • rtiY.W '� ; ' ?3 t pt k „ 1 'a :::1'.r::,'-144i.:+°. ,kAA . p;'1.�5i A , ,; -;•• •z,.;£ acre" " r'k} 4ym 4i...4vr r, ir' .i • � ' .y r"s• .�. 3a'" • !�. . t i ,_*. .....,t , ,'''.:( ''' "..k....444.° t . . ' ' * , : . I '� �. +.,. ' \.t< gid/' _ .. r •f .#. �t r • ss ' �3.. Y. ,t� a '} H� 4.•.rt. t ..ei t fit . .4 . i ..-1! r . 1 k- Amy 4 :- ` 1'`.'�t.;L„ . 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(114) '4'''. 1."1";', '''r • R* ,e7 ' - • :., CI, . k 4.• a• ) — r _ i, II s IP _t gip..,•„0`,0' a' :4+ .SMR s'•-•• f YA i 4. ) 1). . • ,, '''' 164 t ; #/ 4 ` ft Lil `�. i i Ka y ,.. ih J aY A. c 1 , \- -' •‘•' ' k r ..' �` 1 �' • �� w 4 qtr f„1 srw w, , > z . tlit r ..+ • I • r dt r' •T ;A 3 f a ' ' .f r 1,' PTD f - /a c( Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Wednesday,July 29, 2015 1:12 PM To: 'Allsup-Drake, Sharon K' Subject: RE: 2T-07 completion report That is fine- From: Allsup-Drake, Sharon K[mailto:Sharon.K.Allsup-Drake@conocophillips.com] Sent: Wednesday, July 29, 2015 12:53 PM To: Loepp, Victoria T(DOA) Cc: Packer, J.Brett; Kane, Danny; Simek, Jill Subject: 2T-07 completion report SC ►NN6) Victoria— We are compiling all the data for the recent workover and plug & abandon of KRU 2T-07 to send to AOGCC. During the workover and plug operations, we submitted 4 sundry applications—#315-275, #315- 374, #315-416, #315-417, each of which requires a subsequent form 10-407. We are requesting that we send one completion report for all the work performed during the workover and plug/abandon operations. Please let us know if this is acceptable. Thank you, Sharon 263-4612 1 i•<OF Tk1t /'\\ 7 THE STATE Alaska Oil and Gas OfA LAsKi6iConservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS'' Fax: 907 276 7542 www aogcc alaska.gov foe& Danny Kane + 8(J Sr. Wells Engineer 1. ConocoPhillips Alaska, Inc. SCANNED , LI ; 2015 P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2T-07 Sundry Number: 315-416 Dear Mr. Kane: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair 14 day of July,this 2015 Encl. STATE OF ALASKA A. ..KA OIL AND GAS CONSERVATION COM., .310N APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing pi, Operations Shutdow n li Suspend Perforate r Other Stimulate r Alter Casing r - Change Approved Program ✓A,S, Plug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well F - r 1� 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r DeveloprrentI 186-108 3.Address: Stratigraphic r Service r-' 6.API Number. P.O. Box 100360,Anchorage,Alaska 99510 50-103-20069-00 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No (✓ ✓ KRU 2T-07 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25569 V Kuparuk River Field/Kuparuk River 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): 6975 ' 6087• 6897' 6032' 6555' none Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 110' 110' SURFACE 2740 9 625 2773' 2772' PRODUCTION 6419 7 6449' 5724' RECEIVED LINER 747 5 6975' 6087' JU 0 9 7n15 7 X5-115 A Perforation Depth MD(ft): Perforation Depth TVD(ft)• Tubing Size: Tubing Grade: Tubing MD(ft): 6524-6539,6571-6613' - 5776-5786,5808-5837 2.375 J-55 6566 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BROWN HB-1 PACKER MD=6076 TVD=5472 • PACKER-BAKER DB PACKER W5'SEAL BORE EXT MD=6551 TVD=5795 + SAFETY VLV-CAMCO TRDP-1A-SSA MD=1786 TVD=1786 ' 12.Attachments: Description Summary of Proposal r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development F7_ Service r 14.Estimated Date for Commencing Operations. 15. Well Status after proposed work: 7/9/2015 OIL r WIND r WDSPL r Suspended P`- 16.Verbal Approval. Victoria Loepp Date: 7/8/2015 GAS r WAG r GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned rr 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Danny Kane @ 265-6048 Email: Daniel.Kane@conocophillips.com Printed Name Danny Kane Title: Sr. Wells Engineer Signature r Phone:265-6048 Date -3 2dmS Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 3I- 1-(1 Plug Integrity BOP Test VMechanical Integrity Test r Location Clearance r Other: 3 op ¢e571- fp 2500 /23 ( N+p5p rs 2/ZOp5i Ak)O to db C civv?C.M 71 c c-1-,-)r pi t iv o f f' i� or n n v 1, El f v,1:,, i'v,q Al'e•ii•f`./ 'IDA CG 24- hp-5fr1 vet v.,1✓5ce. ./-o W� tv,CS5 plv PT Lr 743 Spacing Exception Required? Yes ❑ No Subsequent Form Required: JO — 4-6? J APPROVED BY Approved by COMMISSIONER THE COMMISSION Date.7/9fAS vTL 77/ Approved applicafion Is varidtor 12�m�onth tx;the date of approval. Submit Form and Form 10-403 Revised 5/2015 oRIGINAL • L1 Atta a is in Duplicate 7��/� RBDM3 JUL 1 5 2015 ConocoPhillips RECEIVED Alaska .JUL 0 9 2015 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 .AOGCC July 08,2015 AOGCC Cathy Forester State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc. hereby submits an Application for Sundry Approval to continue working over Kuparuk Producer KRU 2T-07(PTD# 186-108,Original Sundry#315-275,and Revised Sundry#314-374). Well KRU 2T-07 was drilled and completed as Kuparuk A- & C-sand selective producer in 1986. The A-sand was fracture stimulated in 1988 with primary production since being from the A-sand along with intermittent C-sand production from 1988-1995. In March 1995 IA x OA communication was observed and the inner casing pack-offs were plastic-packed to mitigate. In 2000 an OA leak was observed and LLR logging determined the leak to be at 350' MD—subsequent repair attempts have been unsuccessful. In 2002 the inner casing pack-offs failed to test and because of the plastic packing,remedial work has been unsuccessful. Subsidence was first observed starting in the early 2000s. In 2010, the A-sand perforations were plugged back with cement in order to prepare the well for a slot recovery program. After the cement was pumped, slickline was unable to drift (1.15")the tubing to tag-up on the estimated TOC at 6555'MD;however,a MIT-T did pass. In 2013,subsequent MIT-Ts failed and the subsidence had worsened to the point that the slickline is unable to drift the tubing past—350' MD with a 1"custom split shot. Nabors 7ES moved onto the well 06-Jun-2015 and was unable to regain tubing wireline drift access despite bringing the tubing to neutral weight and growing&stretching the production casing. After attempting to pull the tubing seals free, the tubing parted (pin jumped connection) at —350' MD. Subsequent milling work was performed on the 7" production&9-5/8" surface casing and tubing access was regained and a deep circulation point was obtained when the seals were pulled free of the PBR above the production packer 06-Jul-2015. A 15.8 ppg Class G balanced plug was pumped from 6,026'to—1,800'MD and the AOGCC Slope Inspector will witness the TOC tag later today. The proposed continuation of this work-over will be to complete plug & suspension operations to surface. After tagging the TOC in the 2-7/8" tubing, the tubing will be cut above TOC, picked-up 5', & a 15.7 ppg Arctic Set I balanced plug will be pumped into the TxIA from—1,700'to 400'MD. The AOGCC Slope Inspector will be notified and after WOC, the cement will be pressure-tested &tagged inside the tubing. The tubing will be cut above TOC, pulled to surface, and the 7" production casing will be cut& pulled from the milled interval to surface. A cement retainer will be set within the 9-5/8"surface casing—250'MD. A 15.7 ppg Arctic Set I plug will be squeezed beneath the retainer and through the surface casing leaks. After un-stinging from the retainer, a 15.7 ppg Arctic Set I surface plug will be laid on top of the retainer. After WOC, cement will be confirmed to surface in all annuli,witnessed by the AOGCC, &photo-documented. After ND the BOPE and NU a dry-hole tree,Nabors 7ES will move off and the suspended well will be handed over to the Well Integrity group to complete final surface abandonment. This Sundry is intended to document the proposed work on KRU 2T-07 because of the intent to Change Approved Program while continuing plug&suspension operations on this well. If you have any questions or require any further information,please call me at 265-6048 or email danny.kane@conocophillips.com. Sincerely, Danny Kane Wells Engineer/CPAI Drilling&Wells KRU 2T-07 Rig Workover Plug & Suspend (PTD #:186-108 / Original Sundry #:315-275 / Revised Sundry #315-374) Current Status: Nabors 7ES moved onto KRU 2T-07 under Sundry#315-275. After pulling the 2-7/8"tubing to neutral weight and growing&stretching the 7"production casing,wireline drift access was not restored past—350'MD. In an attempt to pull the 2-7/8"seals free from the PBR at 6,056'MD,the tubing parted(pin jumped)at 350'MD when the tubing connection was being pulled across a section of damaged 7"production casing and subjected to high side-loading. A revised Sundry#315-374 was then submitted&approved and work has continued under that sundry to date. The severely buckled/deformed 7"production&9-5/8"surface casing were milled from—345' to 355.5'MD where the mills started to exit both the production&surface casing strings. While performing diagnostic work to determine the casing orientation,we were able to thread a 2-7/8"cut-lip guide muleshoe into the tubing stump collar looking up at 359'MD. Slickline drift operations were unable to pass through an obstruction at 1794'MD(SSSV),and a slickline toolstring was lost down the tubing while tripping out through a known severe tubing buckle at—361'MD. The fishing assembly was unable to find the lost toolstring and was unable to pass the obstruction within the SSSV at 1,791'MD. The tubing 2-7/8"tubing was cut at 471' MD in order to remove the severe tubing buckle and allow room for a tubing entry guide for additional milling runs that were planned to regain full-bore access down to the new tubing stub at 471' MD. While attempting to pull the 3-1/2 joints of 2-7/8"tubing to the new cut at 471'MD,the seals were pulled free from the PBR at 6,056' MD above the production packer(bad tubing cut). After confirming our circulation point out the tubing tail,a 152 bbl 15.8 ppg Class G balanced permanent plug was pumped&placed from 6,026'to—1,800'MD. The rig is currently WOC to perform an AOGCC-witnessed TOC tag on that balanced plug. Scope of Work: Continue WOC&have AOGCC Slope Inspector witness TOC tag for Balanced Plug#1. Cut the 2-7/8"tubing above TOC, pick-up 5', & pump a 15.7 ppg Arctic Set I balanced plug in the TxIA from —1,700' to 400' MD. Notify AOGCC Slope Inspector and WOC to build compressive strength for pressure test&tag(tubing). Cut tubing above TOC, pull tubing to surface,ND BOPE, & cut&pull 7" production casing from milled interval—340-350' MD to surface. NU BOPE&set a Baker 9-5/8"K-1 cement retainer at—250'MD. Establish circulation/injectivity&squeeze a 15.7 ppg Arctic Set I plug beneath retainer and through surface casing leaks. Unsting from retainer& lay-in a 15.7 ppg Arctic Set I surface plug on top of the retainer. WOC as required,confirm cement to surface in OA&OOA,& photo document same. ND BOPE,NU dry hole tree,move off Nabors 7ES&hand well over to Well Integrity. General Well Info: Well Type: Producer MPSP: 2,120 psi using MASP=(PP-(0.1*TVD)),assuming dry gas gradient to surface. Reservoir Pressure/TVD: Kuparuk C—2,500 psi/5,776' TVD(8.4 ppg EMW) Kuparuk A—2,700 psi/5,808' TVD(9.0 ppg EMW) Wellhead Type/Pressure Rating: CIW Gen IV(5M Tubing Head/3M Casing Head) BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT results: MIT-T Failed 02-May-2013 Last Passed 19-Dec-2010 MIT-OA Failed 01-Nov-2003 Leak Identified at—350'RKB NOTE:IA x OA communication identified after growing&stretching 7" production casing during this work-over. Earliest Estimated Start Date: Nabors 7ES MIRU 06-Jun-2015 Production Engineer: Tommy Nenahlo Workover Engineer: Danny Kane (907)265-6048 danny.kane@conocophillips.com KRU 2T-07 Rig Workover Plug & Suspend (PTD #:186-108 / Original Sundry #:315-275 /Revised Sundry #315-374) Summary of RWO to Date(08-Jul-2015): 1) Sundry#315-275 Approved–Plug&Suspend of KRU 2T-07 2) MIRU Nabors 7ES 3) Kill Well w/9.4 ppg Brine, Flow Check(Static), ND Tree,NU& Test BOPE 4) Pulled tubing to neutral weight(5'stretch), attempted to drift tubing damage at–350'MD–unable to pass. 5) Cut 2-7/8"tubing at 314'MD, set RBP at 256'MD. 6) ND BOPE,grew&stretched casing 50 klbs tension at surface. 23-5/8"Growth, <1"Stretch. NU BOPE. 7) Retrieve RBP, TIH&latch onto 2-7/8"tubing stub with overshot assembly. 8) Pulled tubing to neutral weight, attempted to drift tubing damage at–350'MD–unable to pass. a) Picked-up to 90%2-7/8"J-55 tensile capacity,parted tubing when pin jumped connection at 359'MD. b) Pin jumped when it was bent across casing buckle at–351'MD(8'tubing movement before pin jumped). 9) Attempted to drift overshot/muleshoe to tubing stub–unable to pass casing damage at–350'MD. 10) RU E-Line& confirmed severe casing buckling/deformation at–350'MD. Tubing muleshoe drift attempt past casing damage severely deforms muleshoe. Larger OD tools will not drift past 7"production casing damage. 11) Perform well diagnostics while deciding plan forward,MIT-IA fails–IA x OA x Formation Communication exists. a) Work on milling plan forward&prepare to submit to AOGCC. 12) Submitted&Sundry#315-374 Approved–Revised Plug&Suspend of KRU 2T-07 13) Milled 7"&9-5/8"Production Casing Damage/Severe Buckling from–345'to 355.5'MD a) Exited outside 9-5/8"casingfrom–348'-350'MD&started to exit again at 355.5'MD. b) Can only drift –3.25" OD past ledge where we exited the 7" & 9-5/8" casing strings at 355.5' MD. Continued milling appeared to sidetrack outside of casing even further–milled 'ledge'only 3.5'from top of tubing stub. Concerned additional milling down would prevent us from being able to get on the tubing stub. Only option would be to re-align the mill centerline by performing additional milling above ledge to `realign' mill drift path close to center of production casing at 355.5'MD. 14) Attempted to Screw into 2-7/8"tubing stump collar looking up–successful. Unable to fully engage threads— did not have tensile capacity/pressure-tight seal at connection a) Decision made to attempt slickline work to open up circulation point while we had access to the tubing. 15) Perform Slickline Drift Work in attempt to open up deep circulation point to pump balanced plug. a) Buckle in tubing immediately below tubing stump collar limited toolstring size/configuration. b) Unable to work past obstruction at–1,794'MD(SSSr). c) Lost slickline toolstring while TOH when rope socket pulled free when it was at the tubing buckle beneath the tubing stump collar. d) Attempt to fish lost toolstring, did not find,fishing assembly stacking out at the SSSV.. i) Decision made to try to remove some tubing so that we could open up more milling opportunities to get an overshot to the tubing stub. 16) Cut the 2-7/8"tubing at 471'MD(3-1/2 jts beneath the tubing stump coupling at 359'MD). 17) Attempt to engage spear–unable to get clear shot into tubing stump collar. 18) Perform additional remedial milling to give more room for spear to move around&engage stump. 19) Attempt to engage spear–reconfigured BHA a couple times, but able to walk spear into tubing stump&engage. 20) Picked up on tubing–tubing cut at 471'MD unsuccessful&did not pull free. a) Decision made to work pipe at 80%2-7/8"tubing tensile capacity while spear was engaged for at least a few hours. Started planning additional cut&milling plan forward. 21) After 1.75hrs working pipe at 80% tubing tensile capacity, pulled the seals free from the PBR above the production packer. a) Confirmed seals were pulled free by pumping a high-vis pill. Pill came back within 100 strokes of calculated but showed there was a small leak(-1%total flow)in the tubing from–1,600-1,900'MD. b) Decision made to proceed ahead with pumping balanced plug. KRU 2T-07 Rig Workover Plug & Suspend (PTD #:186-108 / Original Sundry #:315-275 /Revised Sundry #315-374) 22) Pumped 152bb1 15.8ppg Class G balanced plug from 6,026'to 1,800'MD in tubing x IA (2-7/8"tubing& 7" production casing). a) Job pumped as planned. WOC time for 100 psi compressive strength estimated 35 hrs—notified AOGCC Slope Inspector for tag witness. b) NOTE: Unable to pressure test IA. Tubing leak discovered before pumping balanced phug means tubing may not be able to be pressure tested. Proposed Remainder of RWO to Plug& Suspend KRU 2T-07: 1. Continue WOC for sufficient compressive strength to tag. AOGCC Slope Inspector to witness. 2. After tag TOC,cut 2-7/8"tubing with jet cutter mid joint at least one full joint above tagged TOC. 3. Pick-up tubing 5' & set in slips (to space out tubing from new cut). Circulate in/out volume to confirm good circulation for second balanced plug. 4. Pump 15.7ppg Arctic Set 1 balanced plug from —1,700' to 400' MD in tubing x IA (2-7/8" tubing & 7" production casing). a. Base of plug to be determined by TOC tag&subsequent tubing cut. b. Top of plug spaced out beneath milled casing interval. This will act as a base to prevent our surface squeeze from trying to swap down the production casing. 5. WOC for sufficient compressive strength to tag&pressure tests(on the tubing). Notify AOGCC Slope Ins esctor to witness. 6. After tag TOC,cut 2-7/8"tubing with jet cutter above tagged TOC. 7. Pull 2-7/8"tubing&drill pipe to surface,lay-down same. 8. ND BOPE and cut&pull 7"production casing from milled interval&lay-down same. a. If unable to pull free,cut 7"casing at—340'MD above milled interval. b. NOTE: In all previous surface plug options, we had difficulties being able to guarantee the quality of cement and not knowing how much the cement would drop in the OA with the 7"remaining in the well (two annuli with holes). Removing the 7"eliminates one annuli and allows us to squeeze the surface casing holes and get a solid surface plug that won't drop. 9. NU BOPE,test BOPE to 250/2,500 psi,&M/U and set Baker 9-5/8"K-1 cement retainer at—250' MD in the 9-5/8"surface casing. 10. Establish circulation/injection rate beneath the retainer. 11. Squeeze 15.7ppg Arctic Set 1 beneath retainer and into 00A/surface casing holes. 12. Unsting from K-1 retainer&lay-in cement on top of the K-1 retainer from 250'MD to surface. 13. WOC for sufficient compressive strength to tag&document cement to surface. Notify AOGCC Slope Inspector to witness. 14. Notify AOGCC&document cement to surface in IA,OA,&OOA. a. If cement is not within 5'of surface of any annulus,perform top-off job,&photo document to surface. 15. ND BOPE&NU dry-hole tree. 16. RDMO Nabors 7ES. Proposed Post-Rig Work: 1. Turn suspended well over to Well Integrity. a. Remainder of surface abandonment to be performed under a separate Sundry. KU P 2T-07 ConocoPhillips if Well Attributes Max Angle&MD TD Alaska.�t1.. Wellbore API/UWI Field Name Well Status Incl(°) MD(ftKB) Act Btm(kKB) 0 501032006900 KUPARUK RIVER UNIT ___ PROD 49.68 5,400.00 6,975.0 _ ""` Comment H2S(ppm) Date Annotation End Date KB-Grd(k) Rig Release Date SSSV:LOCKED OUT 40 1/11/2009 Last WO: 40.00 8/28/1986 WellConrp:-2T-07,1_,31.012 10.0731 AM ______-___ - Schemat caval Annotation Depth(kKB) End Date Annotation Last Mod...End Date Last Tag_ 6,573.0 2/7/2004 Rev Reason.WELL REVIEW osborl 1/31/2012 Casing Strings HAN,CR 23 ,,. Casing Description String 0... String ID...Top(k)<B) Set Depth(f...Set Depth(TVD)...String WL..String...String Top Thrd CONDUCTOR 16 15.062 33.0 110.0 110.0 62.50 H-40 WELDED Casing Description String 0... String m„.Top(KKB) Set Depth(1.„Sat Depth(TVD)„,String WL.String._String Top Thrd SURFACE 95/8 8.765 33.0 2,772.5 2,772.4 36.00 J-55 BUTT -SI Casing Description String 0... String ID...Top(MB) Set Depth(1.-Bat Depth(TVD)„,String WL_String._String Top Thrd PRODUCTION 7 6.276 30.1 6,448.6 5,724.2 26.00 J-55 BTC jr Casing Description String 0... String ID...Top(kKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd III SURFACE 5 4.151 6,228.5 6,975.0 6,087.1 18.00 S-140 LTC Liner Details CONDUCTOR, Top Depth 33-110 (ND) Top Incl Komi... Top(ftKB) (kKB) (1 Item Description Comment ID(In) SAFETY VLV, _ 1-17:"=. 6,228.5 5,574.5 47.49 HANGER BAKER LINER HANGER 5.000 1.788 Tubing Strings GAS LIFT, Tubing Description String 0... String ID...Top(kKB) Set Depth(i...Set Depth(TVD)...String Wt...String...String Top Thrd 2,562 --- TUBING 27/8 2.441 28.3 6,565.9 5,804.9 6.50 J-55 EUE8rdABMOD t-= 2.8751(2.375" J Completion Details Top Depth (ND) Top Incl Nomi... Top(kKB) PO) C') Item Description Comment ID(In) SURFACE, 28.3 28.3 0.11 HANGER CIW TUBING HANGER 2.441 33-2,772 1,785.6 1,785.5 0.25 SAFETY VLV CAMCO TRDP-1A-SSA(LOCKED OUT 9/3/1993) 2.312 GAS LI,090FT. ti6,056.8 5,459,4 48.16 PBR BROWN PBR 2.500 1 6,076.0 5,472,3 48.11 PACKER BROWN HB-1 PACKER 2.750 GAS LIFT, 6,135.6 5,512.1 47.96 SLEEVE-C OTIS XA SLIDING SLEEVE(CLOSED 4/2/1995) 2.310 1,957 6,154.5 5,524.8 47.91 NIPPLE CAMCO D NIPPLE 2.250 GAS LIFT, 6,156.4 5,526.0 47.91 XO reducing XO reducing 2.875x2.375,4.704,N-80,1.995 2.375 5,319 6,512.0 5,767.8 46.53 BLAST RING CARBIDE BLAST RING 1.995 6,550.0 5,793.9 46.54 LOCATOR BAKER LOCATOR 1.995 GAS LIFT, 5,897 6,551.0 5,794.6 46.54 PACKER BAKER DB PACKER w5'SEAL BORE EXT. 3.250 j■ 6,563.0 5,802.9 46.54 NIPPLE CAMCO D NIPPLE NO GO 1.812 GAS LIFT, B.. 6,565.3 5,804.5 46.54 SOS CAMCO SHEAR OUT 1.995 8,016 B Other In Hole reline retrievable plugs,valves,pumps,fish,etc.) PER,6,057 Top Depth (TVD) Top incl PACKER,8.076 Top(MB) tamr) Description Comment Run Date ID(in) 6,555.0 5,797,4 46.54 CMT PLUG Pumped 15 bbls of 15.8 ppg Class G cement slung .12/16/2010 0.000 T.-- - GAS LIFT, Perforations&Slots 8,114 Shot r Top(TVD) Btm(TVD) Dens Top(kKB)Btm(1KB) (MB) (KKB) Zone Data (ah... Type Comment SLE gB.C. 11 6,524.0 6,539.0 5,776.1 5,786.4 C4,Unit B, 10/30/1986 12.0 IPERF 3 3/8'HyperJet II;60 deg.Ph 38 IIP 21-07 NIPPLE,8,155 IN 6,571.0 6,613.0 5,808.4 5,837.2 A-3,21-07 10/30/1986 12.0 IPERF 3 3/8"HyperJet I1;60 deg.Ph Notes:General&Safety End Date Annotation 2/7/2004 NOTE:HEAVY, ERRATIC PICKUP WEIGHTS SUGGEST CORKSCREW TBG FROM TTL-500' 11/30/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 ., PRODUCTION, A aL 30.0449 I 111 6,5248.539 IPERF, I 1 -- II II LOCATOR, 6.550 PACKER.8.551 NIPPLE.6,563 -I- I I Mandrel Details Top Depth Top Port SOS 6,565 4 (1KB) ir) Make Model (M) Sera Type TYPO (n) TRps)un Run Date Com... CMT PLUG. Stn TOp(KKB)_ 6,555 1 2,582.2 2,5821 0.30 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,336.0 10/30/2004 IPERF, 6,571-6,813 ® 2 4,090.0 4,015.0 31.48 CAMCO KBMG f GAS LIFT GLV BK 0.188 1,334.0 10/30/2004 Cement Plug. 3 4,956.9 4,718.6 37.88 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 10/31/1986 6555 4 5,318.6 4,977.0 49.92 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,327.0 10/30/2004 5 5,697.2 5,223.0 49.53 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 10/31/1986 6 6,016.0 5,432.3 48.26 MMH HTC 1 1/2 GAS LIFT OV RK 0.250 0.0 3/4/2006 7 6,113.6 5,497.4 48.02 CAMCO KBMG 1 PROD DMY BK 0.000 0.0 10/31/1986 Closed LINER, 8226-8,975N TO,8,975 • Dry Hole Tree KRU 2T-07 ConocoPhillips Suspended Producer r 5 Plug&Suspend—07-Jul-2015 16"62.5#H-40 WLD,110'MD -IP- Compromised ►Compromised 9-5/8"Surface Casing- :f 4 1-Cut 2-7/8"Tubing-1700'MD,PU 5'MD Partially Milled Through-348'to 355'MD 2-Pump Balanced Plug 1700'to 400'MD ,Cut 2-7/8"/PTTubing WOC 3— , a (Occurred while milling to regain access to tubing stub) g Above 4-Cut&Pull 7"Casing(-340-350'to Surf) '_ = 5-Set 9-5/8"Cement Retainer at-250'MD 6-Squeeze OOA/Surface Casing Holes Primary Surface Casing7-Lay In Cement Above Retainer Cement, 18bbl Top Job ► `; ; 8-Document Cement to Surface 1= 9-Install Dry-Hole Tree 1785'MD,Camco TRDP-1A SSA Top Arctic Set I-1784'MD I (Locked Out 1991,Flapper Locked 1993) I 2582'MD,Camco KBMG GLV-BK 9-5/8"36#J-55 BTC,2772'MD 15.8ppg Class G Balanced Plug 6026'MD to-1800'MD Pumped 07-Jul-2015 11110;1 '` 4090'MD,Camco KBMG GLV-BK Planned Tag 08-Jul-2015 2-7/8"6.5#,J-55 Tubing Deepest Possible 7"Casing TOC-4400'MD-► (NOTE:Lost returns during job,document lost circulation zone 3800'to 4400'MD while dulling) 111161_ f 4956'MD,Camco KBMG DMY-BK Oniling Mud(Existing) Cement(Existing) Arctic Pack(Existing) Brine WI Wellbore Fluids (Existing) i`' 4 5318'MD,Camco KBMG GLV-BK KW Brine(9.4ppg) PrpppSEil Cetgent: 5697'MD,Camco KBMG DMY-BK Pulled Seals Free 06-Jul-2015 4 6016'MD,MMH HTC OV-RK Spaced Tubing Tail to 6026'MD NOTE:All upper completion depths should be adjusted-45'MD shallower. 4 6056'MD,Brown PBR F 6076'MD,Brown HB-1 Packer [i1:3 4 6113'MD,Camco KBMG DMY-BK 6136'MD,OTIS XA Sliding Sleeve (Closed 1995) 4 6155'MD,2.250"Camco D Nipple 2-7/8"x 2-3/8"Crossover 6228'MD,Baker Mod'A'Liner Hanger 7"26#J-55 BTC,6448'MD ► 2'/e"4.7#N-80 Tubing 6524'-6539'MD,C Perforations 6551'MD,Baker DB Packer w/5'SBE 6563'MD,1.812"Camco D Nipple )I ( 6565'MD,Camco Shear-Out Sub 6571'-6613'MD,A Perforations (Cement Plugged in 2010) 5"18#S-140,6975'MD 10 1 L I Date: 07-Jui-2015 Drawn By: Danny Kane i-4 Z,'T—e 7 PIN j%%IOco Regg, James B (DOA) From: Nabors 7ES Company Man <n2364@conocophillips.com> Sent: Saturday, July 11, 2015 6:17 AM c`�a 7011 To: DOA AOGCC Prudhoe Bay t I Cc: Herrera, Matthew F (DOA); Grimaldi, Louis R(DOA); Kane, Danny a Subject: RE: KRU 2T-07 - N7ES BOP Stack Test Variance Request(PTD.-2G-1-,5-177) t{b Attachments: IMG_3285.JPG;IMG_3286.JPG;IMG_3287.JPG " aajl". °I Gentlemen, Pics of cement in the wellhead at surface for 2T-07.Thanks for your assistance and understanding during this well. LeeHinkelEdwardOglesby / E d a Rig Supervisor/ Nabors 7ES Office 659-7844 Rig 659-7247 From: Nabors 7ES Company Man Sent: Friday, July 10, 2015 4:14 PM To: 'doa.aogcc.prudhoe.bay@alaska.gov' Subject: KRU 2T-07 - N7ES BOP Stack Test Variance Request(PTD 201-507) FYI Matt...Retainer Squeeze and surface cement plug completed... tks, Lee H Lee Hinkel/ Edward Oglesby Rig Supervisor/Nabors 7ES Office 659-7844 Rig 659-7247 From: Kane, Danny Sent: Friday, July 10, 2015 10:04 AM To: Loepp, Victoria T(DOA) Cc: Regg, James B (DOA); Schwartz, Guy L (DOA); Nabors 7ES Company Man; Rauchenstein, Rock D Subject: RE: KRU 2T-07 - N7ES BOP Stack Test Variance Request(PTD 201-507) Victoria, Thank you for being able to look into this for us provided such short notice. I will send an update later today/tomorrow morning on the final P&S scope. Regards, - Danny Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1709 1 Office: +1 907 265-6048 Mobile: +1 907 227-6037 danny.kane@conocophillips.com From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Friday,July 10, 2015 9:59 AM To: Kane, Danny Cc: Regg,James B (DOA); Schwartz, Guy L(DOA) Subject: [EXTERNAL]RE: KRU 2T-07- N7ES BOP Stack Test Variance Request(PTD 201-507) Danny, You have approval to proceed with the remaining scope of this P&A provided you conduct a visual inspection of the BOP stack. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W, 7th Ave,Ste 100 Anchorage,AK 99501 Work (907)793-1247 Victoria Loeppalaska.qov 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 recipients) It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.gov From: Kane, Danny [mailto:Danny.Kane@conocophillips.com] Sent: Friday, July 10, 2015 9:30 AM To: Regg, James B (DOA) Cc: Loepp, Victoria T(DOA); Schwartz, Guy L (DOA); Nabors 7ES Company Man; Rauchenstein, Rock D Subject: KRU 2T-07 - N7ES BOP Stack Test Variance Request Importance: High Mr.Jim Regg, We are having issues shell testing our BOP stack and we believe that we have fluid bypassing our test plug. Can you provide some guidance as to whether we can proceed ahead with a visual inspection of the BOP stack? Please see below for more information on current well & BOPE status: • Well Status: Please see attached current schematic. o We have pumped our two balanced plugs w/the AOGCC Slope Inspector witnessing the tag of both & pressure test(tubing-side)on the uppermost plug. o The well is full of 9.4ppg KW brine. Losses ceased after the first balanced plug was pumped. • Remaining Scope: Please see attached proposed schematic. o Set 9-5/8" cement retainer at^'250' MD. 2 • o Squeeze 15.7ppg AS1 (w/CemNET LCM)cement beneath retainer and into surface casing leaks. o Un-sting from retainer, lay-in 15.7ppg AS1 on top of retainer to surface. o WOC, photo-document cement to surface (AOGCC Slope Inspector will be notified). o N/D BOPE & N/U Dry-Hole tree. • BOPE Status: We are on diverter status because of the holes in the 9-5/8" casing. o After cutting & pulling the 7" casing, we set the BOPE test plug & attempted to pressure-test the BOPE body. Pressure leaked off. • Inspected BOPE stack—no surface leaks. Suspect leak at the plug. o Pulled the test plug—the plug appears to be in good shape. o Attempted to re-test the BOP body, pressure leaking off. o Pulled the test plug again—no visible damage. o Attempted to re-test the BOP stack w/applied weight, pressure leaking off. • Still suspect we are leaking off past the seals. Suspect new issue with our crooked wellhead (because we haven't had an issue testing our BOPE stack with the same plug to date). Given the above, would the AOGCC give us permission to proceed with the remaining scope (<24hrs)on KRU 2T-07 with a visual inspection of the BOP stack? Regards, - Danny Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1709 Office: +1907 265-6048 Mobile: +1 907 227-6037 danny.kane@conocophillips.com 3 ,. ., , dow pr ,. ,,' '. '1','.,::. . ., ...,., .. :V. 4 ,.. , -., • -.:•• V .,. . .s. . _ .., I . Ik..-- . .. „. \ . , , ( . _ Our A 4 k . 'kift A • . • . ., . • . 'k ' • .. .„.. ..- • .0';', ... ..., ,•-. ,,,- :c • . . ',.`.- ote' "1 7., , ';' , . - • .: ..! i.... -.. - . . . . ..., , , .i. ...... i . „, irit1,11 - --- •.. I f ! 4 ",- .. 'itfr -'"II.f 4 l* e SO' • - - it- . - -t,,- - , ,;;•.---...!-- - , , .„,,„ ,. . _ , . . ::-,-14--,...,• ,,_, .. .. .., _. „ . -,.,... , , 6 .., _i• 4," f. -",. •., ! . , • ..m, ,". V.._ • '.,i, ' . •, 1 *i ., I. y , t e ...,_ . , . _...„,,,.. s, 4 • ....* *or. 4 .... , __.., . ::. .„.,,, , ,...._ , ,• .. . :,..,:.,,... .. . . ... .A..,. ......r,,• ..._ • ...., . .., a - 1 .. , • , ,t;11•-• , • t ..4., - . •• • , : 0 „.. ...• - . * . . . . ;101 ,(144 N. ',.. . • j'''311, . .. 1,.. , • ' 3 { • 4q , , • ... . .. • ',.8.• -'°' . ' 4* • 8 4''''' ''''''4,4c,:.•• ' IF • 4 ti '. •-ab ::1,- . ... - / • .. ... S ' I ; • # .• W 4 t . .4 . . ... .'. . . • 4o , I ... . . 0, 1 . 0 .4' 4 • ; . 4.„ A6 41.dal° , • 1 ilk .14411111 -.4. 1 r ,".. ' Pt . . . ,. Alk , ... ,..,.... ..., ' 4 •. 4. ' nt � 'w-`• _ ''SSS ilk ,.a '' 7`. -,-ti r • • a • I.j M. 4. \ • ar • . , r , 4 -. i' to • • y ' • ' .� F_ . ti r � PO ** •� • ' e * y� y s r 4 , d 4 0 i P a OP . , got r' 1 Loepp, Victoria T (DOA) From: Kane, Danny<Danny.Kane@conocophillips.com> Sent: Friday,July 10, 2015 3:18 PM To: Loepp,Victoria T(DOA) Cc: Schwartz,Guy L(DOA) Subject: RE: KRU 2T-07 - N7ES BOP Stack Test Variance Request(PTD 186-108) Victoria &Guy, I've received word from the rig that we have the final cement plugs in place on KRU 2T-07 as per our proposed plan forward. Pending final photo-documentation of cement to surface, we'll be moving off the well this weekend. Thank you for working with us as the scope of this Plug&Suspend has changed throughout the operation. Regards, - Danny Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1709 Office: +1 907 265-6048 Mobile: +1907 227-6037 danny.kane@conocophillips.com From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Friday,July 10,2015 9:59 AM To: Kane, Danny Cc: Regg,James B(DOA);Schwartz,Guy L(DOA) Subject: [EXTERNAL]RE: KRU 21-07- N7ES BOP Stack Test Variance Request(PTD 201-507) Danny, You have approval to proceed with the remaining scope of this P&A provided you conduct a visual inspection of the BOP stack. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oct&Gas Conservation Commission 333 W 7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria Loepp(a�alaska qov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepo@alaska.gov 1 From: Kane, Danny [mailto:Danny.Kane@conocophillips.com] Sent: Friday,July 10, 2015 9:30 AM To: Regg,James B (DOA) Cc: Loepp, Victoria T(DOA); Schwartz, Guy L(DOA); Nabors 7ES Company Man; Rauchenstein, Rock D Subject: KRU 2T-07 - N7E5 BOP Stack Test Variance Request Importance: High Mr.Jim Regg, We are having issues shell testing our BOP stack and we believe that we have fluid bypassing our test plug. Can you provide some guidance as to whether we can proceed ahead with a visual inspection of the BOP stack? Please see below for more information on current well &BOPE status: • Well Status: Please see attached current schematic. o We have pumped our two balanced plugs w/the AOGCC Slope Inspector witnessing the tag of both& pressure test(tubing-side)on the uppermost plug. o The well is full of 9.4ppg KW brine. Losses ceased after the first balanced plug was pumped. • Remaining Scope: Please see attached proposed schematic. o Set 9-5/8"cement retainer at^'250' MD. o Squeeze 15.7ppg AS1 (w/CemNET LCM)cement beneath retainer and into surface casing leaks. o Un-sting from retainer, lay-in 15.7ppg AS1 on top of retainer to surface. o WOC, photo-document cement to surface(AOGCC Slope Inspector will be notified). o N/D BOPE& N/U Dry-Hole tree. • BOPE Status:We are on diverter status because of the holes in the 9-5/8"casing. o After cutting&pulling the 7"casing,we set the BOPE test plug&attempted to pressure-test the BOPE body. Pressure leaked off. • Inspected BOPE stack—no surface leaks. Suspect leak at the plug. o Pulled the test plug—the plug appears to be in good shape. o Attempted to re-test the BOP body, pressure leaking off. o Pulled the test plug again—no visible damage. o Attempted to re-test the BOP stack w/applied weight, pressure leaking off. • Still suspect we are leaking off past the seals. Suspect new issue with our crooked wellhead (because we haven't had an issue testing our BOPE stack with the same plug to date). Given the above,would the AOGCC give us permission to proceed with the remaining scope(<24hrs)on KRU 2T-07 with a visual inspection of the BOP stack? Regards, - Danny Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1709 Office: +1907 265-6048 Mobile:+1907 227-6037 danny.kane@conocophillips.com 2 Loepp, Victoria T (DOA) From: Kane, Danny <Danny.Kane@conocophillips.com> Sent: Friday,July 10, 2015 10:04 AM To: Loepp,Victoria T(DOA) Cc: Regg,James B (DOA); Schwartz, Guy L(DOA); Nabors 7ES Company Man; Rauchenstein, Rock D Subject RE: KRU 2T-07 - N7ES BOP Stack Test Variance Request(PTD 201-507) Follow Up Flag: Follow up Flag Status: Flagged Victoria, Thank you for being able to look into this for us provided such short notice. I will send an update later today/tomorrow morning on the final P&S scope. Regards, - Danny Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1709 Office: +1 907 265-6048 Mobile: +1 907 227-6037 danny.kane@conocophillips.com From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Friday,July 10,2015 9:59 AM To: Kane, Danny Cc: Regg,James B(DOA);Schwartz,Guy L(DOA) Subject: [EXTERNAL]RE: KRU 21-07-N7ES BOP Stack Test Variance Request(PTD 201-507) Danny, You have approval to proceed with the remaining scope of this P&A provided you conduct a visual inspection of the BOP stack. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W 7th Ave,Ste 100 Anchorage,AK 99501 Work (907)793-1247 Victoria Loeoo ..alaska qov 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 1 information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.dov From: Kane, Danny [mailto:Danny.Kane@conocophillips.com] Sent: Friday, July 10, 2015 9:30 AM To: Regg,James B(DOA) Cc: Loepp, Victoria T(DOA); Schwartz, Guy L(DOA); Nabors 7ES Company Man; Rauchenstein, Rock D Subject: KRU 2T-07 - N7ES BOP Stack Test Variance Request Importance: High Mr.Jim Regg, We are having issues shell testing our BOP stack and we believe that we have fluid bypassing our test plug. Can you provide some guidance as to whether we can proceed ahead with a visual inspection of the BOP stack? Please see below for more information on current well&BOPE status: • Well Status: Please see attached current schematic. o We have pumped our two balanced plugs w/the AOGCC Slope Inspector witnessing the tag of both& pressure test(tubing-side)on the uppermost plug. o The well is full of 9.4ppg KW brine. Losses ceased after the first balanced plug was pumped. • Remaining Scope: Please see attached proposed schematic. o Set 9-5/8"cement retainer at^'250' MD. o Squeeze 15.7ppg AS1(w/CemNET LCM)cement beneath retainer and into surface casing leaks. o Un-sting from retainer, lay-in 15.7ppg AS1 on top of retainer to surface. o WOC, photo-document cement to surface(AOGCC Slope Inspector will be notified). o N/D BOPE& N/U Dry-Hole tree. • BOPE Status:We are on diverter status because of the holes in the 9-5/8" casing. o After cutting&pulling the 7"casing,we set the BOPE test plug&attempted to pressure-test the BOPE body. Pressure leaked off. • Inspected BOPE stack—no surface leaks. Suspect leak at the plug. o Pulled the test plug—the plug appears to be in good shape. o Attempted to re-test the BOP body, pressure leaking off. o Pulled the test plug again—no visible damage. o Attempted to re-test the BOP stack w/applied weight, pressure leaking off. • Still suspect we are leaking off past the seals. Suspect new issue with our crooked wellhead (because we haven't had an issue testing our BOPE stack with the same plug to date). Given the above,would the AOGCC give us permission to proceed with the remaining scope(<24hrs)on KRU 2T-07 with a visual inspection of the BOP stack? Regards, - Danny Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1709 Office: +1907 265-6048 Mobile:+1907 227-6037 2 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ! • I`� I') DATE: July 9, 2015 P.I. Supervisor 1-1":411 I SUBJECT: Well Bore Plug & Abandonment KRU 2T-07 FROM: Matt Herrera CPAI Petroleum Inspector Kuparuk River Unit PTD 1861080 ���� Sundry# 315-374 SCS Section: 1 Township: 11N Range: 8E Meridian: Umiat Drilling Rig. Nabors 7ES Rig Elevation: Total Depth: 6975' MD Lease No.: ADL0025569 Operator Rep: Lee Hinkel Casing/Tubing Data: Casing Removal: Conductor: 16" O.D. Shoe@ 110 Feet Casing Cut@ Feet Surface: 9-5/8" O.D Shoe@ 2773 Feet Casing Cut@ Feet Intermediate: O.D. Shoe@ Feet Casing Cut@ Feet Production: 7" O.D. Shoe@ 6449 - Feet Casing Cut@ Feet Liner: 5" O.D. Shoe@ 6975 Feet Casing Cut@ Feet Tubing: 2-7/8"x 2-3/8" 0 D. Tail@ 6566 Feet Casing Cut@ Feet Plugging Data: Type Plug Bottom of T.O.C. Mud Weight Pressure (bottom up) Founded on Cement T.O.C. Depth Verified? above plug Test Casing - Balanced - 1633 ft • 491 ft - Wireline Tag 9.4ppg • 1000 ' Type Plug Founded on: Verified? Open Hole Bottom Drillpipe tag Perforation Bridge plug Wireline tag Annulus Balanced C.T Tag Casing Stub Retainer No Surface Plug tagged with wireline prior to and after 1000psi test.Approval of well plugging plan from Victoria Loepp(AOGCC)per email and phone conversation. cc: Well File Attachments: none DNR/DOG rev 2-25-14 2015-0709_Plug_Verification_KRU_2T-07_mh xlsx 8/5/2015 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ►`c 710/i5 DATE: July 9, 2015 P. I. Supervisor FROM: Lou Grimaldi SUBJECT: Cement Plug Tag for verification Petroleum Inspector Conoco Phillips Alaska Inc. KRU 2T-07 Kuparuk River Unit/Field PTD #186-108 Sundry 315-374 - Wednesday, July 8, 2015: I witnessed the tag of a balanced cement plug in the tubing of CPAI well KRU 2T-07. The tag was accomplished with a Schlumberger Slickline unit. A 1 5/8-inch tool string with a 2 1/4-inch gage ring on the bottom was used to tag today. The tools were lowered to 1675 feet, zeroed at the rotary table. This rig — Nabors 7ES — has an elevation of 26 • feet from the tubing hanger flange. At 1675 feet RKB the tools fetched up solid. Two more attempts were made to get deeper without success, picking up off the obstruction (plug top?) yielded a straight pickup without any sticking or over-pull noticed. - Plan forward is to lay-in another plug on top of this one. - Attachments: None - scomED Non-Confidential 2015-0709_Plug_Verification_KRU_2T-07_lg.docx Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Wednesday,July 08, 2015 10:23 AM To: 'Kane, Danny' Cc: Schwartz,Guy L(DOA) Subject: RE: KRU 2T-07 - Revised Plug&Suspend Plan Forward for Surface Plugs- PTD 186-108 Danny, We have reviewed your proposed plan forward for the Plug and Suspend of KRU 2T-07 and the plan is approved. Please submit a 10-403 outlining this plan as soon as possible. Thanx for your updates through this operation- Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W 7th Ave,Ste 100 Anchorage,AK 99501 Work (907)793-1247 Victoria Loepp@alaska qov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov From: Kane, Danny [mailto:Danny.Kane@conocophillips.com] Sent: Wednesday, July 08, 2015 9:45 AM To: Loepp,Victoria T(DOA); Schwartz, Guy L(DOA) Subject: KRU 2T-07 - Revised Plug &Suspend Plan Forward for Surface Plugs - 20150708AM Importance: High KRU 2T-07 PTD 186-108 2015 RWO Sundry 315-275 Revised 2015 RWO Sundry 315-374 Victoria&Guy, As I mentioned in my daily update yesterday, I would like to revise our plan forward for the continue plug& suspension of KRU 2T-07. Please call me if you have any questions; I will contact you after lunch if I haven't heard back to verify that this plan forward is good to go. Upon receiving approval, I'll submit another 10-403 outlining this proposed plan forward. • 2T-07 Operational Summary to Date(Please See Current Status Schematic for the current state of the well as of today). o Sundry#315-275 Approved—Plug&Suspend of KRU 2T-07 o MIRU Nabors 7ES 1 o Pulled tubing to neutral weight (5' stretch), attempted to drift tubing damage at"350' MD—unable to pass. o Set RBP at 256' MD, ND BOPE,grew&stretched casing(50klbs over)-"2'total growth &stretch, NU BOPE, retrieve RBP. o Pulled tubing to neutral weight, attempted to drift tubing damage at"350' MD—unable to pass. • Picked-up to 90%2-7/8"1-55 tensile capacity, parted tubing when pin jumped connection at 359' MD. o Submitted &Sundry#315-374 Approved—Revised Plug&Suspend of KRU 2T-07 o Milled 7" &9-5/8" Production Casing Damage/Severe Buckling from 345'to 355.5' MD • Exited outside 9-5/8" casing from^'348'-350' MD&started to exit again at 355.5' MD. • Can only drift"'3.25" OD past ledge where we exited the 7" &9-5/8" casing strings. Continued milling appeared to sidetrack outside of casing even further—milled 'ledge' only 3.5'from top of tubing stub. Concerned additional milling down would prevent us from being able to get on the tubing stub. Only option would be to re-align the mill centerline by milling above. o Attempted to Screw into 2-7/8"tubing stump collar looking up—successful. Unable to fully engage threads and get full tensile capacity/pressure-tight seal. • Decision made to attempt to perform slickline work to open up circulation point while we had access to the tubing. o Perform Slickline Drift Work in attempt to open up deep circulation point to pump balanced plug. • Buckle in tubing immediately below tubing stump collar limited toolstring size/configuration. • Unable to work past obstruction at"'1791' MD (SSSV). • Lost slickline toolstring while TOH when rope socket pulled free when it was at the tubing buckle beneath the tubing stump collar. • Attempt to fish lost toolstring, did not find,fishing assembly stacking out at the SSSV. • Decision made to try to remove some tubing so that we could open up more milling opportunities to get an overshot to the tubing stub. o Cut the 2-7/8"tubing at 471' MD(3-1/2 jts beneath the tubing stump coupling at 359' MD). o Attempt to engage spear—unable to get clear shot into tubing stump. o Perform additional remedial milling to give more room for spear to move around &engage stump. o Attempt to engage spear—reconfigured BHA a couple times, but able to walk spear into tubing stump& fully engage. o Picked up on tubing—tubing cut at 471' MD unsuccessful. • Decision made to work pipe at 80%2-7/8" tubing tensile capacity while spear was engaged for at least a few hours. Started planning additional cut& milling plan forward. o After 1.75hrs working pipe at 80%tubing tensile capacity, pulled the seals free from the PBR above the production packer. • Confirmed seals were pulled free by pumping a high-vis pill. Pill came back within 100 strokes of calculated but showed there was a small leak (-1%total flow) in the tubing from 1600-1900' MD. • Decision made to proceed ahead with pumping balanced plug. o Pumped 152bbl 15.8ppg Class G balanced plug from 6026'to 1800' MD in tubing x IA(2-7/8"tubing&7" production casing). • Job pumped as planned. WOC time for 100psi compressive strength estimated 35hrs—notified AOGCC Slope Inspector for tag witness. • NOTE: Unable to pressure test IA. Tubing leak discovered before pumping balanced plug means tubing may not be able to be pressure tested. • 2T-07 Proposed Plan Forward(Please see proposed schematic for what I am proposing below): o Continue WOC for sufficient compressive strength to tag. AOGCC Slope Inspector to witness. o After tag TOC, cut 2-7/8"tubing with jet cutter mid joint at least one full joint above tagged TOC. o Pick-up tubing 5' &set in slips (tubing is spaced out 5'from new cut). Circulate in/out volume to confirm good circulation for second balanced plug. 2 o Pump"46bbl 15.7ppg Arctic Set 1 balanced plug from 1700'to 400' MD in tubing x IA(2-7/8"tubing& 7" production casing). • Base of plug to be determined by TOC tag&subsequent tubing cut. • Top of plug spaced out beneath milled casing interval. This will act as a base to prevent our surface squeeze from trying to swap down the production casing. o WOC for sufficient compressive strength to tag& pressure tests(on the tubing). Notify AOGCC Slope Inspector to witness. o After tag TOC, cut 2-7/8"tubing with jet cutter above tagged TOC. o Pull 2-7/8" tubing&drill pipe to surface, lay-down same. o Pull 7" production casing from milled interval& lay-down same. • If unable to pull free, cut 7" casing at"'340' MD above milled interval. • NOTE: In all previous surface plug options,we had difficulties being able to guarantee the quality of cement and not knowing how much the cement would drop in the OA with the 7" remaining in the well (two annuli with holes). Removing the 7" eliminates one annuli and allows us to squeeze the surface casing holes and get a solid surface plug that won't drop. o M/U &set Baker 9-5/8" K-1 cement retainer at^'250' MD in the 9-5/8" surface casing. o Establish circulation/injection rate beneath the retainer. o Squeeze 15.7ppg Arctic Set 1 beneath retainer and into 00A/surface casing holes. o Unsting from K-1 retainer& lay-in cement on top of the K-1 retainer from 250' MD to surface. o WOC for sufficient compressive strength to tag&document cement to surface. Notify AOGCC Slope Inspector to witness. o Photo-document cement to surface in all annuli. o ND BOPE, NU dry hole tree. o RDMO N7ES. o Turn well over to Well Integrity. Regards, - Danny Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1709 Office: +1 907 265-6048 Mobile:+1907 227-6037 danny.kane@conocophillips.com 3 Loepp, Victoria T (DOA) From: Kane, Danny <Danny.Kane@conocophillips.com> Sent: Monday,July 06, 2015 4:39 PM To: Schwartz, Guy L(DOA); Loepp,Victoria T(DOA) Subject: RE: KRU 2T-07 - Plug &Suspend Update-06-Jul-2015 Follow Up Flag: Follow up Flag Status: Flagged Persistence and unbelievable patience by the guys in the field to keep this from getting sidetracked. I have a quick update on the balanced permanent plug: We expect to start pumping the plug close to midnight tonight and will have it in place in the early morning hours. We currently expect the WOC time to be 35hrs to gain 100psi compressive strength—so the tag of TOC in the tubing will likely occur Wednesday afternoon/evening (08-Jul-2015). The company man on Nabors 7ES has already sent a notification to the field inspectors so that they can witness the tag. Regards, - Danny Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1709 Office: +1907 265-6048 Mobile: +1907 227-6037 danny.kane@conocophillips.com From:Schwartz,Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent:Monday,July 06,2015 2:44 PM To: Kane, Danny; Loepp,Victoria T(DOA) Subject: [EXTERNAL]RE: KRU 2T-07-Plug&Suspend Update-06-Jul-2015 Good work.. I guess persistence pays off sometimes! Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793-1226 I or(Guv.schwartz@alaska.gov). From: Kane, Danny [mailto:Danny.Kane(aconocophillips.com] Sent: Monday,July 06, 2015 1:50 PM To: Loepp, Victoria T(DOA); Schwartz, Guy L(DOA) Subject: KRU 2T-07 - Plug &Suspend Update-06-)u1-2015 Importance: High KRU 2T-07 PTD: 186-108 Original 2015 RWO Sundry: 315-275 Revised 2015 RWO Sundry: 315-374 Victoria &Guy, We had a stroke of good fortune overnight on the Plug&Suspension of KRU 2T-07. While attempting to pull 3-1/2 jts of tubing to a cut at 471' MD, we actually pulled the seals free from the PBR above the production packer at 6076' MD. We have laid down the spear assembly, removed the joint with the attempted cut at 471' MD, and spaced the tubing tail out at 6026' MD. A high-vis sweep confirmed that we have pulled the seals free and while the majority of the sweep came back on time,we did start seeing some early returns of the sweep from ^'1600-1900' MD; however,the estimated bypass is<1% based upon surface observations. After confirming the cement modeling, we are going to pump our first plug—a 15.8ppg Class G balanced plug from 6026'to 1800' MD later today. Once the plug is in place, we will notify AOGCC to witness a tag on TOC(since we may not be able to pressure test the tubing and definitely not the IA). Concerning the remainder of the plugs to suspend the well, I'm going to be working on a plan that will best guarantee plug placement given the known holes that we have in the 7" &9-5/8" production casing from "'345'-355' MD from our milling activities. If it differs from the approved revised Sundry#315-374, I will consult with you two to make sure that the proposed work is approved by the AOGCC. Regards, - Danny Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1709 Office: +1 907 265-6048 Mobile: +1 907 227-6037 danny.kane@conocophillips.com from: Kane, Danny Sent:Sunday,July 05,2015 10:22 AM To: 'Loepp,Victoria T(DOA)'; 'Schwartz,Guy L(DOA)' Subject: KRU 2T-07-Plug&Suspend Update-05-Jul-2015 All, Here's the recap of the what has occurred the last 48hrs on the plug&suspension of KRU 2T-07. Summary: • R/D slickline(after lost toolstring downhole&failed fishing attempt). • R/U E-line. o Fire string shot&cut 2-7/8"tubing at 471' MD(3-1/2 joints beneath tubing stump at 359' MD). o Attempt to pull RCT cutting tool out,tool string hung up at rope socket at 361.5' MD(same tight spot that we lost the slickline toolstring on). o Called out wireline clamps from Baker fishing. 2 • Strip out w/BHA 97 using wireline clamps to keep from dropping E-line toolstring downhole. o Retrieved E-line tool string—did not recover 3-1/2 joints of cut tubing. • Performed BOPE test(variance granted). • Attempted to spear 2-7/8"tubing stump at 359' MD—unable to walk inside casing. TIH w/spear w/muleshoe, able to walk into casing but not able to fully engage tubing stump. • LID spear assembly&TIH w/poor-boy tubing mill/muleshoe. R/U E-line&get downhole camera shots. Plan Forward: • Burn down inside edge of milled casing ledge at 355.5' MD(7"&9-5/8" strings are pancaked together)to open up drift access for spear&allow more spear movement to engage tubing stump. • Reconfigure spear assembly to fish tubing fish(3-1/2 joints). • TIH w/tubing muleshoe w/string mills above—work casing from 340'down to realign drift path to center of casing at 355' MD. o Once mill drift is realigned,open up to get 2-7/8"tubing body overshot down to tubing stump. Engage& pick-up on tubing. Resume slickline drifting operations. Regards, -Danny 3 Loepp, Victoria T (DOA) From: Schwartz,Guy L(DOA) Sent: Monday,July 06, 2015 2:44 PM To: Kane, Danny; Loepp,Victoria T(DOA) Subject RE: KRU 2T-07 - Plug &Suspend Update-06-Ju1-2015 Follow Up Flag: Follow up Flag Status: Flagged Good work.. I guess persistence pays off sometimes! Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793-1226) or(Guv.schwartz@alaska.aov). From: Kane, Danny [mailto:Danny.KaneCa�conocophillips.com] Sent: Monday,July 06, 2015 1:50 PM To: Loepp, Victoria T(DOA); Schwartz, Guy L(DOA) Subject: KRU 2T-07 - Plug &Suspend Update -06-Jul-2015 Importance: High KRU 2T-07 PTD: 186-108 Original 2015 RWO Sundry: 315-275 Revised 2015 RWO Sundry: 315-374 Victoria &Guy, We had a stroke of good fortune overnight on the Plug&Suspension of KRU 2T-07. While attempting to pull 3-1/2 jts of tubing to a cut at 471' MD, we actually pulled the seals free from the PBR above the production packer at 6076' MD. We have laid down the spear assembly, removed the joint with the attempted cut at 471' MD, and spaced the tubing tail out at 6026' MD. A high-vis sweep confirmed that we have pulled the seals free and while the majority of the sweep came back on time,we did start seeing some early returns of the sweep from 1600-1900' MD; however,the estimated bypass is<1% based upon surface observations. After confirming the cement modeling, we are going to pump our first plug—a 15.8ppg Class G balanced plug from 6026'to 1800' MD later today. Once the plug is in place, we will notify AOGCC to witness a tag on TOC(since we may not be able to pressure test the tubing and definitely not the IA). Concerning the remainder of the plugs to suspend the well, I'm going to be working on a plan that will best guarantee plug placement given the known holes that we have in the 7" &9-5/8" production casing from ""345'-355' MD from our milling activities. If it differs from the approved revised Sundry#315-374, I will consult with you two to make sure that the proposed work is approved by the AOGCC. 4 Regards, - Danny Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1709 Office: +1 907 265-6048 Mobile: +1907 227-6037 danny.kane@conocophillips.com From: Kane, Danny Sent:Sunday,July 05, 2015 10:22 AM To: 'Loepp,Victoria T(DOA)'; 'Schwartz,Guy L(DOA)' Subject: KRU 21-07-Plug&Suspend Update-05-Jul-2015 All, Here's the recap of the what has occurred the last 48hrs on the plug&suspension of KRU 2T-07. Summary: • R/D slickline(after lost toolstring downhole&failed fishing attempt). • R/U E-line. o Fire string shot&cut 2-7/8"tubing at 471' MD(3-1/2 joints beneath tubing stump at 359' MD). o Attempt to pull RCT cutting tool out,tool string hung up at rope socket at 361.5'MD(same tight spot that we lost the slickline toolstring on). o Called out wireline clamps from Baker fishing. • Strip out w/BHA 97 using wireline clamps to keep from dropping E-line toolstring downhole. o Retrieved E-line tool string—did not recover 3-1/2 joints of cut tubing. • Performed BOPE test(variance granted). • Attempted to spear 2-7/8"tubing stump at 359' MD—unable to walk inside casing. TIH w/spear w/muleshoe, able to walk into casing but not able to fully engage tubing stump. • L/D spear assembly&TIH w/poor-boy tubing mill/muleshoe. R/U E-line&get downhole camera shots. Plan Forward: • Burn down inside edge of milled casing ledge at 355.5' MD (7" &9-5/8"strings are pancaked together)to open up drift access for spear&allow more spear movement to engage tubing stump. • Reconfigure spear assembly to fish tubing fish(3-1/2 joints). • TIH w/tubing muleshoe w/string mills above—work casing from 340'down to realign drift path to center of casing at 355' MD. o Once mill drift is realigned,open up to get 2-7/8"tubing body overshot down to tubing stump. Engage& pick-up on tubing. Resume slickline drifting operations. Regards, -Danny 5 Loepp, Victoria T (DOA) From: Kane, Danny <Danny.Kane@conocophillips.com> Sent: Monday,July 06, 2015 1:50 PM To: Loepp,Victoria T(DOA);Schwartz, Guy L(DOA) Subject: KRU 2T-07 - Plug &Suspend Update -06-Jul-2015 Importance: High Follow Up Flag: Follow up Flag Status: Flagged KRU 2T-07 PTD: 186-108 Original 2015 RWO Sundry: 315-275 Revised 2015 RWO Sundry: 315-374 Victoria &Guy, We had a stroke of good fortune overnight on the Plug&Suspension of KRU 2T-07. While attempting to pull 3-1/2 jts of tubing to a cut at 471' MD, we actually pulled the seals free from the PBR above the production packer at 6076' MD. We have laid down the spear assembly, removed the joint with the attempted cut at 471' MD, and spaced the tubing tail out at 6026' MD. A high-vis sweep confirmed that we have pulled the seals free and while the majority of the sweep came back on time,we did start seeing some early returns of the sweep from '1600-1900' MD; however,the estimated bypass is<1% based upon surface observations. After confirming the cement modeling, we are going to pump our first plug—a 15.8ppg Class G balanced plug from 6026'to 1800' MD later today. Once the plug is in place, we will notify AOGCC to witness a tag on TOC(since we may not be able to pressure test the tubing and definitely not the IA). Concerning the remainder of the plugs to suspend the well, I'm going to be working on a plan that will best guarantee plug placement given the known holes that we have in the 7" &9-5/8" production casing from ^'345'-355' MD from our milling activities. If it differs from the approved revised Sundry#315-374, I will consult with you two to make sure that the proposed work is approved by the AOGCC. Regards, - Danny Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1709 Office: +1907 265-6048 Mobile: +1907 227-6037 dannv.kane@conocophillips.com From: Kane, Danny Sent:Sunday,July 05,2015 10:22 AM To:'Loepp,Victoria T(DOA)'; 'Schwartz,Guy L(DOA)' Subject: KRU 2T-07-Plug&Suspend Update-05-Jul-2015 6 All, Here's the recap of the what has occurred the last 48hrs on the plug&suspension of KRU 2T-07. Summary: • R/D slickline(after lost toolstring downhole&failed fishing attempt). • R/U E-line. o Fire string shot&cut 2-7/8"tubing at 471' MD (3-1/2 joints beneath tubing stump at 359' MD). o Attempt to pull RCT cutting tool out,tool string hung up at rope socket at 361.5' MD (same tight spot that we lost the slickline toolstring on). o Called out wireline clamps from Baker fishing. • Strip out w/ BHA 97 using wireline clamps to keep from dropping E-line toolstring downhole. o Retrieved E-line tool string—did not recover 3-1/2 joints of cut tubing. • Performed BOPE test(variance granted). • Attempted to spear 2-7/8"tubing stump at 359' MD—unable to walk inside casing. TIH w/spear w/muleshoe, able to walk into casing but not able to fully engage tubing stump. • L/D spear assembly&TIH w/poor-boy tubing mill/muleshoe. R/U E-line&get downhole camera shots. Plan Forward: • Burn down inside edge of milled casing ledge at 355.5' MD (7" &9-5/8" strings are pancaked together)to open up drift access for spear&allow more spear movement to engage tubing stump. • Reconfigure spear assembly to fish tubing fish (3-1/2 joints). • TIH w/tubing muleshoe w/string mills above—work casing from 340' down to realign drift path to center of casing at 355' MD. o Once mill drift is realigned, open up to get 2-7/8"tubing body overshot down to tubing stump. Engage & pick-up on tubing. Resume slickline drifting operations. Regards, - Danny 7 Loepp, Victoria T (DOA) From: Kane, Danny <Danny.Kane@conocophillips.com> Sent: Sunday,July 05, 2015 10:22 AM To: Loepp, Victoria T(DOA); Schwartz, Guy L (DOA) Subject: KRU 2T-07 - Plug &Suspend Update - 05-Jul-2015 Follow Up Flag: Follow up Flag Status: Flagged All, Here's the recap of the what has occurred the last 48hrs on the plug&suspension of KRU 2T-07. Summary: • R/D slickline (after lost toolstring downhole &failed fishing attempt). • R/U E-line. o Fire string shot&cut 2-7/8"tubing at 471' MD (3-1/2 joints beneath tubing stump at 359' MD). o Attempt to pull RCT cutting tool out,tool string hung up at rope socket at 361.5' MD (same tight spot that we lost the slickline toolstring on). o Called out wireline clamps from Baker fishing. • Strip out w/ BHA 97 using wireline clamps to keep from dropping E-line toolstring downhole. o Retrieved E-line tool string—did not recover 3-1/2 joints of cut tubing. • Performed BOPE test (variance granted). • Attempted to spear 2-7/8"tubing stump at 359' MD—unable to walk inside casing. TIH w/spear w/muleshoe, able to walk into casing but not able to fully engage tubing stump. • L/D spear assembly&TIH w/poor-boy tubing mill/muleshoe. R/U E-line &get downhole camera shots. Plan Forward: • Burn down inside edge of milled casing ledge at 355.5' MD (7" &9-5/8" strings are pancaked together)to open up drift access for spear&allow more spear movement to engage tubing stump. • Reconfigure spear assembly to fish tubing fish (3-1/2 joints). • TIH w/tubing muleshoe w/string mills above—work casing from 340' down to realign drift path to center of casing at 355' MD. o Once mill drift is realigned, open up to get 2-7/8"tubing body overshot down to tubing stump. Engage & pick-up on tubing. Resume slickline drifting operations. Regards, - Danny 8 Loepp, Victoria T (DOA) From: Kane, Danny <Danny.Kane@conocophillips.com> Sent: Friday, July 03, 2015 10:16 AM To: Regg, James B (DOA); Loepp, Victoria T (DOA); Schwartz, Guy L (DOA); DOA AOGCC Prudhoe Bay Cc: Nabors 7ES Company Man; Rauchenstein, Rock D; Kanady, Randall B Subject: RE: KRU 2T-07 - Plug & Suspend Update & Potential BOPE Test Waiver Request - 01- Jul-2015 Follow Up Flag: Follow up Flag Status: Flagged KRU 2T-07 PTD 1861080 All, Last night while trying to clear an obstruction a -1793' MD,we lost a slickline tool string while TOH at"392' MD (pulled out of the rope socket as it tried to pass through a known tubing buckle. We went in with a fishing assembly but were unable to find the lost tool string and were unable to pass 1791' MD with the fishing assembly. Given the restrictions of our 'hand-tight' connection at 359' MD with our cut-lip tubing pup and the buckle immediately beneath that coupling,we are preparing to cut the tubing ("3-1/2 jts beneath the current tubing stub top) and resume milling operations so that we can get a properly-sized overshot to the tubing stub. As soon as we have either successfully pulled the tubing fish to surface (the 3-1/2 joints)or have pulled the cut-lip tubing pup to surface (with no fish), we will start our overdue BOPE test. The test could start as soon as this evening if all goes well. Our company men on Nabors 7ES are going to send out a BOPE test notification as well. Regards, - Danny Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1709 Office: +1 907 265-6048 Mobile:+1907 227-6037 danny.kane@conocophillips.com Original Message From: Regg,James B(DOA) [mailto:jim.regg@alaska.gov] Sent:Thursday,July 02, 2015 11:03 AM To: Kane, Danny; Loepp,Victoria T(DOA); Schwartz,Guy L(DOA); DOA AOGCC Prudhoe Bay Cc: Nabors 7ES Company Man; Rauchenstein, Rock D; Kanady, Randall B Subject: [EXTERNAL]RE: KRU 2T-07- Plug&Suspend Update & Potential BOPE Test Waiver Request-01-Jul-2015 KRU 2T-07 1 PTD 1861080 Danny- I appreciate the summaries and phone discussion this morning updating your progress. Request to delay the weekly BOPE test is approved through Sunday, 7/5. BOPE test results for Nabors 7ES have been good (last witnessed 6/17/15). If you have not met your objective (open up a circulation point above the production packer to set a balanced plug) by Sunday we can consider a further delay. Also, if you lose connection with the 2-7/8"tubing and have to trip the work string to surface you are expected to test before reentry. Please continue to update us throughout the weekend by email; I am also available by phone. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave,Suite 100 Anchorage, AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907-793-1236 or jim.regg@alaska.gov. Original Message From: Kane, Danny [mailto:Danny.Kane@conocophillips.com] Sent:Wednesday,July 01, 2015 6:43 PM To: Loepp,Victoria T(DOA); Schwartz, Guy L(DOA); Regg,James B(DOA) Cc: Nabors 7ES Company Man; Rauchenstein, Rock D; Kanady, Randall B Subject: Re: KRU 2T-07- Plug&Suspend Update& Potential BOPE Test Waiver Request-01-Jul-2015 All, We have continued bailing milled debris and formation down to 1794'SLM and believe we are working down a bridge that formed above the bore upsets within the SSSV. Given our slow progress and unknown timeline until we break through, ConocoPhillips will be formally requesting a variance to extend the start of our BOPE test past the one week cycle Nabors 7ES is currently on. I will call first thing in the morning to discuss this. The purpose of this email is to prevent any confusion,as our company men have submitted the 24-hour notice and have cited that we will be asking for a variance. Please feel free to call me at 227-6037 if you would like to discuss this matter this evening. Regards, - Danny Danny Kane Drilling Engineer-WNS 2 ConocoPhillips Alaska, Inc. +1 (907) 265-6048-Office +1 (907) 227-6037- Mobile danny.kane@conocophillips.com<mailto:danny.kane@conocophillips.com> On Jul 1, 2015, at 11:46, Kane, Danny<Danny.Kane@conocophillips.com<mailto:Danny.Kane@conocophillips.com» wrote: All, Nabors 7ES is currently performing slickline drift operations in an attempt to get back down our 2-7/8"tubing to open up a circulation point above our production packer(needed to set our balanced plug above the packer). We have been bailing mill debris at 1792' MD for the past 12 hours and making very slow—but continued—progress. I wanted to send this email to provide forewarning that we may request a BOPE test waiver to delay the start of the test so that we can complete drift operations, create a circulation point, & possibly pump our balanced plug(within reason). The next weekly BOPE test due for Nabors 7ES is due to start tomorrow. While our hope is that we can finish these operations before the BOPE test,there is as of right now the possibility that we may not have completed the work. Please see below for what would be our reasoning for delaying the start of the test: Background: • We started milling the damaged 7" production casing on 17-Jun-2015 at^'348' MD. The casing was severely buckled and over the course of 49 mill runs (&subsequent camera runs to confirm milling success),we were able to mill through the buckled casing to -355.5' MD where we started to mill outside the 7" production &9-5/8" surface casing on 28-Jun-2015. With the tubing stub only 3.5' beneath where milling stopped and our uncertainty on which direction the casing was turning,we stopped milling ahead&were having trouble getting our mills to walk back inside the casing. Fearing an accidental sidetrack,we ran in with a 2-7/8" muleshoe and were surprised when it drifted down to the tubing stub(this was the first time we had been able to do this). • We then decided to see if we could screw into the tubing stub(box is looking up at us) and after a few tries,we were able to get a 2-7/8"tubing joint with a cut-lip machined into the pin end to walk into the casing—and more importantly—got it screwed in 'hand-tight' into the 2-7/8"tubing box looking up. • Starting yesterday morning (30-Jun-2015),we got 24hr slickline crews on location to start drift operations w/E-line on standby to create a deep circulation point. Reason for Potential Waiver Request • Right now we have drift access to the tubing stub and are working on drifting past 350' MD–the furthest we have been in the past couple years. There is a risk that we could lose access to the tubing stub if we come off of it right now (whether that be we're unable to guide the pup joint back down,that residual stresses start to deform the 7" &9-5/8" casing strings that we've partially milled through,etc.). Barrier Discussion: • We initially killed the well with 9.4ppg NaCI brine and we have been experiencing losses of 1/2 to 1-1/2 bph since; we have kept the well full and there has been no indication of gas migration. Again,this email is more of a forewarning and not a formal request yet. At the time that we do make such a request, I can come down to discuss in further detail what we have done on 2T-07 to date,explain our current situation in better detail, and provide additional details on the plan forward. 3 Regards, - Danny Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1709 Office: +1 907 265-6048 Mobile: +1907 227-6037 danny.kane@conocophillips.com<mailto:danny.kane@conocophillips.com> From: Kane, Danny Sent:Tuesday,June 30, 2015 4:33 PM To:Victoria Loepp (AOGCC); 'Schwartz,Guy L(DOA)' Subject: KRU 2T-07 - Plug&Suspend Update-30-Jun-2015 Victoria &Guy, Here's a quick recap of the past 24hrs on KRU 2T-07—we have some positive news as we were able to get back onto the tubing stub: • We attempted to completely screw into the 2-7/8"tubing stub with a 2-7/8" pup joint with a machined cut-lip guide on the pin. We weren't able to get engaged enough to pick-up on the tubing. • Currently threaded 'hand-tight' into the tubing stub, acting as a wireline entry guide. • Drifted down 2-7/8"tubing to^'1792'with 1-1/2" bailer,currently tripping out to empty bailer. • Plan Forward: o Continue drift operations to production packer at 6076' MD. o Open up deep circulation point(pull OV from GLM at 6016',tubing punch, or split shot depending on drift run success). o Prepare to pump balanced plug from deep circulation point to 1800' MD—may need to perform more milling to get a sealed connection to our tubing stub. Regards, - Danny Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1709 Office: +1907 265-6048 Mobile: +1907 227-6037 danny.kane@conocophillips.com<mailto:danny.kane@conocophillips.com> 4 Loepp, Victoria T (DOA) From: Kane, Danny <Danny.Kane@conocophillips.com> Sent: Tuesday,June 30, 2015 4:33 PM To: Loepp, Victoria T (DOA); Schwartz, Guy L (DOA) Subject: KRU 2T-07 - Plug &Suspend Update - 30-Jun-2015 Follow Up Flag: Follow up Flag Status: Flagged Victoria &Guy, Here's a quick recap of the past 24hrs on KRU 2T-07—we have some positive news as we were able to get back onto the tubing stub: • We attempted to completely screw into the 2-7/8"tubing stub with a 2-7/8" pup joint with a machined cut-lip guide on the pin. We weren't able to get engaged enough to pick-up on the tubing. • Currently threaded 'hand-tight' into the tubing stub, acting as a wireline entry guide. • Drifted down 2-7/8" tubing to 1792'with 1-1/2" bailer, currently tripping out to empty bailer. • Plan Forward: o Continue drift operations to production packer at 6076' MD. o Open up deep circulation point (pull OV from GLM at 6016',tubing punch, or split shot depending on drift run success). o Prepare to pump balanced plug from deep circulation point to "1800' MD—may need to perform more milling to get a sealed connection to our tubing stub. Regards, - Danny Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1709 Office: +1 907 265-6048 Mobile: +1907 227-6037 danny.kane@conocophillips.com 1 Loepp, Victoria T (DOA) From: Kane, Danny <Danny.Kane@conocophillips.com> Sent: Friday,June 26, 2015 9:42 PM To: Loepp, Victoria T (DOA); Schwartz, Guy L (DOA) Subject: KRU 2T-07 - Plug &Suspend Update - 26-Jun-2015 Follow Up Flag: Follow up Flag Status: Flagged Victoria &Guy, Here's a quick recap of the past 24hrs on KRU 2T-07: • Continued milling 7" &9-5/8" production casing buckle to—352' MD. o Camera run early this morning drifted all the way down to the tubing stub at 359' MD—still insufficient drift diameter for an overshot, but significant progress. • Continued milling 7" &9-5/8" production casing buckle to^'353' MD. o Camera run raised questions about where we were milling the casing(inside or outside of buckle), so a multi-finger caliper was run. o Multi-finger caliper drifted down to the tubing stub and actually drifted into the tubing. Drifted tubing with caliper from 359'to 380' MD. ■ This is another key development. • We will continue enlarging the 'drift avenue'that the camera &caliper are passing through so that our slim ("'4- 3/4" OD) 2-7/8" tubing collar overshot can drift down to the tubing stub. o Once we latch onto the tubing stub, we will drift down the tubing to find out how deep we can get with which tools. Plan forward will be adjusted based upon what we see (there are a few different options to get a deep circulation point). Also, as a heads-up, because we have burned through ^'2'of the inside edge the production casing and surface casing, we will likely go back to our original sundried plan to set the surface plugs (in the latest Sundry we requested to set the surface plugs from"'350'to surface) where we will attempt to pull the tubing down to the SSSV, punch holes in the production casing at—1700' MD,set a cement retainer below the milled casing interval,and squeeze cement up the OA to surface. After un-stinging from the retainer, we will then lay in a plug in the IA to surface. Once we have a more defined path forward, I will discuss our cementing plan with you two to confirm we are all still in agreement. Regards, - Danny Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1709 Office: +1907 265-6048 Mobile:+1907 227-6037 danny.kaneecon0Copniilips.com 2 Loepp, Victoria T (DOA) From: Kane, Danny <Danny.Kane@conocophillips.com> Sent: Thursday, June 25, 2015 4:48 PM To: Loepp, Victoria T (DOA); Schwartz, Guy L(DOA) Subject: KRU 2T-07 - Plug &Suspend Update - 25-Jun-2015 Follow Up Flag: Follow up Flag Status: Flagged Victoria &Guy, Here's a quick recap of the past 24hrs on KRU 2T-07: • Performed BOPE test(witnessed waived). • Continued milling 7" &9-5/8" production casing buckle at^'351' MD. Using camera runs to verify milling success&casing orientation (to project what the casing is doing deeper). • We will continue milling ahead with the new string mills to enlarge&straighten the existing-6" hole milled through the 7" production &9-5/8" surface casing damage. Once sufficient clearance for drifting down to the tubing stub has been obtained, we will attempt to drift down to the tubing stub&confirm orientation against the 7" production casing to determine fishing options. Regards, - Danny Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1709 Office: +1907 265-6048 Mobile:+1907 227-6037 danny.kane@conocophillips.com 3 Loepp, Victoria T (DOA) From: Kane, Danny <Danny.Kane@conocophillips.com> Sent: Wednesday, June 24, 2015 5:15 PM To: Loepp,Victoria T (DOA); Schwartz, Guy L (DOA) Subject: KRU 2T-07 - Plug &Suspend Update - 24-Jun-2015 Follow Up Flag: Follow up Flag Status: Flagged Victoria &Guy, Here's a quick recap of the past 48hrs on KRU 2T-07: • Continued milling 7" production casing to straighten out above buckle at' 350' MD. Milled inside of 7" &9-5/8" surface casing in order to regain drift access past damage. We have been able to drift the downhole camera 4' past the 350' MD buckle (huge improvement). • Currently preparing to start our BOPE test(Matt Herrara has waived witness). • We will continue milling ahead with the new string mills to enlarge&straighten the existing"'6" hole milled through the 7" production &9-5/8" surface casing damage. Once sufficient clearance for drifting down to the tubing stub has been obtained,we will attempt to drift down to the tubing stub&confirm orientation against the 7" production casing to determine fishing options. Regards, - Danny Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1709 Office: +1907 265-6048 Mobile:+1907 227-6037 danny.kane@conocophillips.com 4 Loepp, Victoria T (DOA) From: Kane, Danny <Danny.Kane@conocophillips.com> Sent: Monday, June 22, 2015 10:04 AM To: Loepp, Victoria T (DOA); Schwartz, Guy L (DOA) Subject: KRU 2T-07 - Plug &Suspend Update - 22-Jun-2015 Victoria &Guy, Here's a quick recap of the past 24hrs on KRU 2T-07: • Continued milling 7" production casing damage with new 5" string mill. Confirming milled interval with downhole camera—getting good results with new mill on buckle beneath initial area of interest. • We will continue milling ahead with the new string mills to enlarge&straighten the existing -5" hole milled through the 7" production casing damage. Once sufficient clearance for drifting down to the tubing stub has been obtained, we will attempt to drift down to the tubing stub&confirm orientation against the 7" production casing to determine fishing options. Regards, - Danny Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1709 Office: +1907 265-6048 Mobile:+1907 227-6037 danny.kane@conocophillips.com 1 Loepp, Victoria T (DOA) From: Kane, Danny <Danny.Kane@conocophillips.com> Sent: Sunday,June 21, 2015 5:44 PM To: Loepp,Victoria T(DOA); Schwartz, Guy L(DOA) Subject: KRU 2T-07 - Plug &Suspend Update- 21-Jun-2015 Victoria&Guy, Here's a quick recap of the past 24hrs on KRU 2T-07: • Continued milling damaged 7" production casing. Completed 16 milling runs thus far with a cumulative^'18-24" of the damaged interval milled while still staying centered within the 7" production casing o Confirmed milled interval with downhole camera after each milling run in order to adjust milling strategy &mill selection (to prevent accidentally sidetracking). • Finished milling through 7" buckle at -350' MD. Attempt to drift with camera mule shoe—unable to drift past opposite side of buckle(beneath milled interval). • Logged 24-arm caliper of 7" production casing to help determine milling strategy. Sent request for string mills to be made up. • We will continue milling ahead with the new string mills to enlarge&straighten the existing-5" hole milled through the 7" production casing damage. Once sufficient clearance for drifting down to the tubing stub has been obtained, we will attempt to drift down to the tubing stub&confirm orientation against the 7" production casing to determine fishing options. Regards, - Danny Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1709 Office: +1907 265-6048 Mobile:+1907 227-6037 danny.kane@conocophillips.com 1 Loepp, Victoria T (DOA) From: Kane, Danny <Danny.Kane@conocophillips.com> Sent: Saturday,June 20, 2015 3:13 PM To: Loepp,Victoria T (DOA); Schwartz, Guy L(DOA) Subject: KRU 2T-07 - Plug & Suspend Update - 20-Jun-2015 Follow Up Flag: Follow up Flag Status: Flagged Victoria &Guy, Here's a quick recap of the past 24hrs on KRU 2T-07: • Continued milling damaged 7" production casing. Completed 12 milling runs thus far with a cumulative—18" of the damaged interval milled while still staying centered within the 7" production casing o Confirming milled interval with downhole camera prior to continuing in order to adjust milling strategy& mill selection to keep from accidentally sidetracking. • We will continue milling the damaged interval while trying to minimize unnecessary damage to 7" production casing string. Once sufficient damage has been removed,will attempt to drift down to the tubing stub& confirm orientation against the 7" production casing to determine fishing options. Regards, - Danny Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1709 Office: +1907 265-6048 Mobile:+1907 227-6037 danny.kane@conocophillips.com 1 Loepp, Victoria T (DOA) From: Kane, Danny <Danny.Kane@conocophillips.com> Sent: Friday,June 19, 2015 10:23 AM To: Loepp, Victoria T (DOA); Schwartz, Guy L (DOA) Subject: KRU 2T-07 - Plug & Suspend Update - 19-Jun-2015 Follow Up Flag: Follow up Flag Status: Flagged Victoria &Guy, Here's a quick recap of the past 24hrs on 2T-07: • Milled another—3-4" cumulative of 7" production casing damage. Milling—1-1.5" at a time before confirming milling results with downhole camera. o Continuing to get through the folded/buckled section of 7" production casing at"'349' MD. Enough of the fold has been removed to start seeing the casing condition on the other side of the ramp (looks to be a short down-sloping buckle). • We will continue milling the damaged interval while trying to minimize unnecessary damage to 7" production casing string. Once sufficient damage has been removed,will attempt to drift down to the tubing stub& confirm orientation against the 7" production casing to determine fishing options. Regards, - Danny Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1709 Office: +1907 265-6048 Mobile:+1907 227-6037 danny.kane@conocophillips.com 2 Loepp, Victoria T (DOA) From: Kane, Danny <Danny.Kane@conocophillips.com> Sent: Thursday,June 18, 2015 4:45 PM To: Loepp,Victoria T (DOA); Schwartz, Guy L(DOA) Subject: KRU 2T-07 - Plug &Suspend Update - 18-Jun-2015 Follow Up Flag: Follow up Flag Status: Flagged Victoria &Guy, Here's a quick recap of the past 24hrs on 2T-07: • Milled"'4" cumulative of 7" production casing damage. Milling^'1-1.5" at a time before confirming milling results with downhole camera. o The damaged interval appears to be very short—1-2'with noticeable milling results with the small increments milled thus far. • We will continue milling the damaged interval while trying to minimize unnecessary damage to 7" production casing string. Regards, - Danny Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1709 Office: +1907 265-6048 Mobile: +1907 227-6037 aanny.kane@corlu upiudps.com 3 Loepp, Victoria T (DOA) From: Kane, Danny <Danny.Kane@conocophillips.com> Sent: Wednesday,June 17, 2015 1:41 PM To: Loepp, Victoria T (DOA); Schwartz, Guy L (DOA) Subject: KRU 2T-07 - Plug & Suspend Update - 17-Jun-2015 Follow Up Flag: Follow up Flag Status: Flagged Victoria &Guy, Here's a quick recap of the past 24hrs on 2T-07: • Replaced annular(required crane pick to get annular behind well row and into cellar—rig remained on the well). • Tested new annular on 2-7/8" & 3-1/2"test joints—good tests. Sent&discussed annular test charts to Lou Grimaldi. • Currently just started milling damaged 7" production casing with 3-11/16"x 6" packer mill. o After 1" milled,will circulated filtered KW brine around and rig-up downhole camera to verify the mill is milling the damaged interval as planned. o Will continue with milling small increments& inspect milled interval with camera as needed to verify milling success. o Milling parameters&mill selection will be adjusted as needed to ensure we are milling only the targeted damaged interval. Regards, - Danny Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1709 Office: +1907 265-6048 Mobile: +1907 227-6037 danny.kane@conocophillips.com 4 Loepp, Victoria T (DOA) From: Kane, Danny <Danny.Kane@conocophillips.com> Sent: Tuesday, June 16, 2015 1:45 PM To: Loepp, Victoria T (DOA); Schwartz, Guy L(DOA) Subject: KRU 2T-07 - Plug & Suspend Update - 16-Jun-2015 Follow Up Flag: Follow up Flag Status: Flagged Victoria &Guy, Here's a quick recap of the past 24hrs on 2T-07: • Performed state-witnessed BOPE test. The annular failed to test on the 2-7/8"test joint. • Attempted to remove annular element—unable to remove annular lid. • Currently working on plan to swap annular. Regards, - Danny Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1709 Office: +1 907 265-6048 Mobile:+1907 227-6037 danny.kane@conocophiiiips.com 5 Loepp. Victoria T (DOA) From: Loepp,Victoria T(DOA) <victoria.loepp@alaska.gov> Sent: Thursday,June 11, 2015 4:18 PM To: Kane, Danny Cc: Schwartz, Guy L(DOA) Subject [EXTERNAL]Re: 2T-07 - Proposed Plug &Suspend Scope Change(Sundry#315-275) Approval is granted to proceed as outlined. Please submit a 10-403 Change of Approved Program as soon as possible. Thanx, Victoria Sent from my iPhone On Jun 11,2015,at 4:13 PM, Kane, Danny<Danny.Kane@conocophillips.com>wrote: Victoria, As per our phone conversation, I'd like to add this additional information. We would only proceed with this proposed plan forward (to reverse circulate the balanced plug) if we deem that it is technically feasible to reverse circulate cement through the Orifice Valve at 6016' MD (single small-ID restriction) and are confident that we can place the balanced plug as planned. Given that we satisfy those points, would the AOGCC give ConocoPhillips permission to proceed ahead with this new Plug&Suspend plan forward? Regards, - Danny Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1709 Office: +1 907 265-6048 Mobile: +1 907 227-6037 danny.kane@conocophillips.com From: Kane, Danny Sent:Thursday,June 11,2015 2:31 PM To:Victoria Loepp(AOGCC) Subject: 2T-07-Proposed Plug&Suspend Scope Change(Sundry#315-275) Importance: High Victoria, I'll be calling you very shortly to discuss this—I thought I would send this information prior to calling so that we can reference it. We are having difficulties with the 2T-07 Plug&Suspend and the rig is waiting upon our plan forward. 1 ConocoPhillips would like permission to perform the following scope change for the 2T-07 Plug& Suspend because of unforeseen tubing access difficulties. Please see below for a recap of rig activities on 2T-07 to date and the proposed scope change. Please see attached Daily Drilling Reports& proposed Plug&Suspend schematic. • 2T-07 2015 RWO Purpose: o Finish plugging&suspending 2T-07 after being unable to perform the work non-rig because of a severe tubing obstruction at^'350' MD (suspected tubing deformation from shear-induced casing collapse from subsidence). • 21-07 2015 RWO History(Nabors 7ES): o MIRU Nabors 7ES o Pulled BPV,circulated&killed well with 9.4 ppg NaCI brine. o Set BPV, ND tree, NU BOPE, &tested to 250/2,500 psi(good test). o Pulled BPV, screwed in landing joint, BOLDS, & unseated tubing hanger. o Allowed tubing to grow& pulled to neutral weight. • Tubing grew^'18"from compression. Picked up another 5'to bring tubing to neutral weight. o RU E-Line &attempted to drift 2-7/8" 6.5#J-55 EUE-8RD AB Mod IPC tubing–unable to drift past 350' MD. • Attempted 1-11/16" dummy drift, 1-7/16"cross-over, & 1" running gear drifts. All hard tagged at 350' MD. o Cut 2-7/8" tubing at 310' MD, pulled cut tubing to surface. o Set RBP at 256' MD&tested same. Dumped sand on RBP. o ND BOPE. o RU Hydratight system &grew 7" 26#J-55 BTC casing. • Casing grew 23-5/8"from compression w/Hydratight system. o Removed tubing spool, PU spear, &speared casing. Picked-up to 50 klbs over(stretched <1")and re-landed production casing in slips. o Cut excess casing with Wachs cutter, reinstalled pack-offs& pressure-tested same. o Reinstalled BOPE,tested to 250/2,500 psi (good test). o Circulated out sand, retrieved RBP. o Dressed 2-7/8" tubing stub,TIH & latched onto tubing stub at 310' MD with overshot. Pulled to neutral weight. o RU E-Line &attempted to drift tubing. Hard tagged at 350' MD with all drifts. • Same drifts as first attempt–unable to get even 1"drift through obstruction at 350' MD. • Tubing Obstruction Problem o 2T pad has a history of surface casing collapse induced by shear stresses from subsidence acting within a localized gravel layer(the gravel pinches the surface casing as the well subsides)that should be at^350'-400' MD for 2T-07. Note that this subsidence damage is different than what we normally see—severely helically buckled casing/tubing;we believe 2T-07 has this 'traditional'subsidence-induced helical buckling as well beneath the shear collapse damage at"350' MD. • Both 2T-06&2T-08(wells that flank 2T-07) have caliper logs of the surface casing that shows this type of shear collapse damage. Those wells were repaired by replacing the damaged 7" production casing(subsidence repair). o We believe that the shear collapse damage on 2T-07 is the worst that has been observed –severe enough that the tubing is plastically deformed to the point that even after growing/stretching BOTH the tubing& production casing we still cannot get a limber 1" e-line toolstring to drift the tubing. In order for the production tubing to be that 2 plastically deformed,the production casing must have significant shear collapse damage that has been caused by even more severe surface casing shear collapse. o We believe that there are significantly higher-than-normal risks associated with performing a traditional subsidence style repair on 2T-07 to regain tubing access—with the two biggest risks being: • The inability to latch & seal back on the tubing stub beneath the damaged casing after attempting a blind back-off to remove tubing from the damaged interval. • This would remove our circulation path down the well. • That there is a very real risk that in trying to remove the partially-collapsed 7" production casing we would exit the surface casing while milling(very similar to 1A-25). • The most likely back-off point for the tubing will be at a tubing collar at —360' MD. The tubing stub will act like a whipstock when we attempt to mill the remaining tubing(this happened on 1A-25 and we exited the surface casing while milling). • There is little confidence that we can mill the tubing&casing at the same time without exiting the surface casing(if we can't remove the tubing). o Based upon the risks associated with attempting a subsidence repair on 2T-07,we are proposing that we perform the following: • Set a balanced plug from 6016' MD to 1800' MD by reverse circulating. Our 7" production casing still has pressure integrity&we have a circulation path down to the OV valve at 6016' MD,just 60' above the production packer. • Cut holes in production casing above existing tubing stub at 310' MD and set surface plug in IAxOA from 300' MD to surface;the surface casing leak would be squeezed as originally planned. • Proposed Plan Forward o Confirm reverse circulation down the IA,through the OV in the GLM at 6016' MD, & up the tubing. o RU cementers& reverse circulate balanced plug from the OV valve to 1800' MD in both the tubing& IA. RD cementers&WOC. o Notify AOGCC to witness pressure test of cement in tubing& IA. • Unable to tag because of tubing obstruction. o Release from tubing stub, lay down drill pipe. o RU E-Line &shoot perforating torch to cut slots in the 7" production casing at"'275-300' MD. o Displace Arctic Pack from OA with heated freshwater. o Pick-up,TIH, &set K-1 Cement Retainer at^'250' MD. Pressure test to 500psi from above to confirm set. o RU Dowell cementers and pump OA surface plug(Plug#3) down IA beneath retainer&up OA(through production casing torch slots). With good returns to surface, shut-in OA and squeeze surface casing leak. o Unsting from retainer, TOH & LD running tool, and TIH &tag-up on retainer with drill pipe. o RU Dowell cementers &pump final surface plug(Plug#4) above retainer.TOH w/drill pipe. Perform IA top job for pipe steel displacement. Release E-Line. RD Dowell cementers&WOC. o Notify AOGCC& photo document cement to surface in IA, OA, &OOA. • If cement is not within 5'of surface of any annulus, perform top-off job, & document to surface. o ND BOPE& NU dry hole tree. o RDMO RWO Rig 3 Regards, - Danny Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1709 Office: +1907 265-6048 Mobile:+1907 227-6037 danny.kane@conocophillips.com 4 Loepp, Victoria T (DOA) From: Kane, Danny <Danny.Kane@conocophillips.com> Sent: Monday,June 15, 2015 9:20 AM To: Schwartz, Guy L(DOA); Loepp,Victoria T(DOA) Subject: RE: KRU 2T-07 - RWO Update Attachments: 2T-07 RWO Progression - 20150615.pptx Follow Up Flag: Follow up Flag Status: Flagged Guy, You were next on my list to update. Throughout the weekend we continued to gather information on our production casing damage (see attached PowerPoint)—it appears we have an acute bend in our 7" production casing that is preventing us from drifting down and tagging up on the tubing stub. We are having a meeting later this morning to discuss our plan forward—I will update you at that time as that will likely represent the significant scope change (at which time I will let you review our updated plan forward and if you approve,submit a 10-403 Change of Approved Program). Regards, - Danny Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1709 Office: +1907 265-6048 Mobile: +1907 227-6037 danny.kane@conocophillips.com From:Schwartz,Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Monday,June 15,2015 9:10 AM To:Kane, Danny; Loepp,Victoria T(DOA) Subject: [EXTERNAL]RE: KRU 2T-07-RWO Update Danny, Victoria is out today so keep me posted as well on your progress and any significant changes to plan. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 1 recipient of this e-mail,please delete it,wiinout first saving or forwarding it,and,so that the AvGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov), From: Kane, Danny [mailto:Danny.Kane@conocophillips.com] Sent: Friday,June 12, 2015 4:28 PM To: Loepp, Victoria T(DOA) Cc: Schwartz, Guy L(DOA) Subject: RE: KRU 2T-07 - RWO Update Victoria, We are currently gathering information on our parted tubing to determine the best option going forward to latch back onto our tubing stub. We know that we have removed 365' MD of tubing(using the original tally)which means that we have removed the hard-tag obstruction that we could not get our wireline drifts past. We are going to perform a caliper survey of our production casing to the tubing stub and then use an LIB&downhole camera to help determine the orientation & how concentric the tubing collar looking up at us is relative to the production casing. Once we have acquired that information, we will then determine what fishing assembly we will use to get latched back in. Our ultimate intent is to finish plugging& suspending the well as per my proposed plan forward to the AOGCC that I submitted yesterday. Given that there is potential for changes in our proposed cement plugs, I intend to keep you updated on our fishing attempts and once I can confirm our final plan forward (including actual planned plug depths given the latest information) I will confirm with you that the AOGCC will approve going ahead with our proposed plan forward. At that time I will also submit an updated Sundry for Change of Approved Program—I believe that there is too much uncertainty right now to submit the 10-403. Regards, - Danny Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1709 Office: +1907 265-6048 Mobile: +1907 227-6037 danny.kane@conocophillips.com From: Kane, Danny Sent:Friday,June 12, 2015 8:18 AM To:Victoria Loepp(AOGCC) Subject: KRU 21-07-RWO Update Victoria, Quick update. Because of the reservations we had about trying to reverse circulate the balanced plug,we decided to make an honest effort to go ahead&try to pull the seals free from the PBR at 6076' MD,which would allow us to proceed ahead without the difficulties of reverse circulating cement. While attempting to pull the seals free,we parted the tubing(pin jumped the connection)at—360' MD—either right in the middle or at the bottom of the shear-collapse section. The well is secure and we are currently waiting on E-line to evaluate the 7" production casing so we can make decide on the proper plan forward. I will keep you updated. Regards, 2 - Danny Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1709 Office: +1907 265-6048 Mobile:+1907 227-6037 danny.kane@conocophillips.com 3 Loepp, Victoria T (DOA) From: Schwartz,Guy L(DOA) Sent: Thursday,June 11, 2015 4:23 PM To: Loepp,Victoria T(DOA) Subject: RE:2T-07 - Proposed Plug &Suspend Scope Change(Sundry#315-275) Follow Up Flag: Follow up Flag Status: Flagged Good call... hopefully they can get a decent rate circulating. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Loepp,Victoria T(DOA) Sent:Thursday,June 11, 2015 4:18 PM To: Kane, Danny Cc: Schwartz, Guy L(DOA) Subject: Re: 2T-07 - Proposed Plug &Suspend Scope Change (Sundry #315-275) Approval is granted to proceed as outlined. Please submit a 10-403 Change of Approved Program as soon as possible. Thanx, Victoria Sent from my iPhone On Jun 11,2015,at 4:13 PM, Kane, Danny<Danny.Kane@conocophillips.com>wrote: Victoria, As per our phone conversation, I'd like to add this additional information. We would only proceed with this proposed plan forward (to reverse circulate the balanced plug) if we deem that it is technically feasible to reverse circulate cement through the Orifice Valve at 6016' MD (single small-ID restriction) and are confident that we can place the balanced plug as planned. Given that we satisfy those points, would the AOGCC give ConocoPhillips permission to proceed ahead with this new Plug&Suspend plan forward? Regards, - Danny 1 Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1709 Office: +1907 265-6048 Mobile:+1907 227-6037 danny.kane@conocophillips.com From: Kane, Danny Sent:Thursday,June 11, 2015 2:31 PM To:Victoria Loepp (AOGCC) Subject: 2T-07- Proposed Plug&Suspend Scope Change (Sundry#315-275) Importance: High Victoria, I'll be calling you very shortly to discuss this—I thought I would send this information prior to calling so that we can reference it. We are having difficulties with the 2T-07 Plug&Suspend and the rig is waiting upon our plan forward. ConocoPhillips would like permission to perform the following scope change for the 2T-07 Plug& Suspend because of unforeseen tubing access difficulties. Please see below for a recap of rig activities on 2T-07 to date and the proposed scope change. Please see attached Daily Drilling Reports&proposed Plug&Suspend schematic. • 2T-07 2015 RWO Purpose: o Finish plugging &suspending 2T-07 after being unable to perform the work non-rig because of a severe tubing obstruction at-350' MD(suspected tubing deformation from shear-induced casing collapse from subsidence). • 2T-07 2015 RWO History(Nabors 7ES): o MIRU Nabors 7ES o Pulled BPV, circulated & killed well with 9.4 ppg NaCl brine. o Set BPV, ND tree, NU BOPE, &tested to 250/2,500 psi(good test). o Pulled BPV, screwed in landing joint, BOLDS, & unseated tubing hanger. o Allowed tubing to grow& pulled to neutral weight. • Tubing grew^'18" from compression. Picked up another 5'to bring tubing to neutral weight. o RU E-Line &attempted to drift 2-7/8"6.5#J-55 EUE-8RD AB Mod IPC tubing—unable to drift past 350' MD. • Attempted 1-11/16" dummy drift, 1-7/16" cross-over, & 1" running gear drifts. All hard tagged at 350' MD. o Cut 2-7/8" tubing at 310' MD, pulled cut tubing to surface. o Set RBP at 256' MD&tested same. Dumped sand on RBP. o ND BOPE. o RU Hydratight system&grew 7" 26#J-55 BTC casing. • Casing grew 23-5/8"from compression w/ Hydratight system. o Removed tubing spool, PU spear, &speared casing. Picked-up to 50 klbs over(stretched <1") and re-landed production casing in slips. o Cut excess casing with Wachs cutter, reinstalled pack-offs& pressure-tested same. o Reinstalled BOPE,tested to 250/2,500 psi (good test). o Circulated out sand, retrieved RBP. 2 o Dressed 2-7/8" tubing stub,TIH & latched onto tubing stub at 310' MD with overshot. Pulled to neutral weight. o RU E-Line &attempted to drift tubing. Hard tagged at 350' MD with all drifts. ■ Same drifts as first attempt–unable to get even 1" drift through obstruction at 350' MD. • Tubing Obstruction Problem o 2T pad has a history of surface casing collapse induced by shear stresses from subsidence acting within a localized gravel layer(the gravel pinches the surface casing as the well subsides) that should be at^'350'-400' MD for 2T-07. Note that this subsidence damage is different than what we normally see—severely helically buckled casing/tubing;we believe 2T-07 has this 'traditional' subsidence-induced helical buckling as well beneath the shear collapse damage at-350' MD. ■ Both 2T-06&2T-08 (wells that flank 2T-07) have caliper logs of the surface casing that shows this type of shear collapse damage. Those wells were repaired by replacing the damaged 7" production casing(subsidence repair). o We believe that the shear collapse damage on 2T-07 is the worst that has been observed –severe enough that the tubing is plastically deformed to the point that even after growing/stretching BOTH the tubing& production casing we still cannot get a limber 1" e-line toolstring to drift the tubing. In order for the production tubing to be that plastically deformed,the production casing must have significant shear collapse damage that has been caused by even more severe surface casing shear collapse. o We believe that there are significantly higher-than-normal risks associated with performing a traditional subsidence style repair on 2T-07 to regain tubing access–with the two biggest risks being: • The inability to latch &seal back on the tubing stub beneath the damaged casing after attempting a blind back-off to remove tubing from the damaged interval. • This would remove our circulation path down the well. • That there is a very real risk that in trying to remove the partially-collapsed 7" production casing we would exit the surface casing while milling (very similar to 1A-25). • The most likely back-off point for the tubing will be at a tubing collar at "'360' MD. The tubing stub will act like a whipstock when we attempt to mill the remaining tubing (this happened on 1A-25 and we exited the surface casing while milling). • There is little confidence that we can mill the tubing&casing at the same time without exiting the surface casing(if we can't remove the tubing). o Based upon the risks associated with attempting a subsidence repair on 2T-07,we are proposing that we perform the following: • Set a balanced plug from 6016' MD to 1800' MD by reverse circulating. Our 7" production casing still has pressure integrity&we have a circulation path down to the OV valve at 6016' MD,just 60' above the production packer. • Cut holes in production casing above existing tubing stub at 310' MD and set surface plug in IAxOA from ^300' MD to surface;the surface casing leak would be squeezed as originally planned. • Proposed Plan Forward o Confirm reverse circulation down the IA,through the OV in the GLM at 6016' MD, & up the tubing. o RU cementers& reverse circulate balanced plug from the OV valve to 1800' MD in both the tubing& IA. RD cementers&WOC. 3 o Notify AOGCC to witness pressure test of cement in tubing& IA. ■ Unable to tag because of tubing obstruction. o Release from tubing stub, lay down drill pipe. o RU E-Line &shoot perforating torch to cut slots in the 7" production casing at^275-300' MD. o Displace Arctic Pack from OA with heated freshwater. o Pick-up,TIH, &set K-1 Cement Retainer at -250' MD. Pressure test to 500psi from above to confirm set. o RU Dowell cementers and pump OA surface plug(Plug#3) down IA beneath retainer& up OA(through production casing torch slots). With good returns to surface,shut-in OA and squeeze surface casing leak. o Unsting from retainer,TOH & LD running tool, and TIH &tag-up on retainer with drill pipe. o RU Dowell cementers &pump final surface plug(Plug#4) above retainer.TOH w/drill pipe. Perform IA top job for pipe steel displacement. Release E-Line. RD Dowell cementers &WOC. o Notify AOGCC& photo document cement to surface in IA, OA, &OOA. • If cement is not within 5'of surface of any annulus, perform top-off job, & document to surface. o ND BOPE& NU dry hole tree. o RDMO RWO Rig Regards, - Danny Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1709 Office: +1907 265-6048 Mobile: +1907 227-6037 danny.kane@conocophillips.com 4 OF Ty, • w\ � ,v THE STATE Alaska Oil and Gas ofAL /k SKA Conservation Commission %Ottt___ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main 907 279 1433 OFALAS11* - Fax. 907 276 7542 www aogcc.alaska gov 2 ALU'\5 Jill Simek �ED JUL t Staff Well Integrity Engineer j f ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2T-07 Sundry Number: 315-417 Dear Ms. Simek: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 709)Lelt, Cathy P. Foerster Chair DATED thisIT day of July, 2015 Encl. • STATE OF ALASKA A KA OIL AND GAS CONSERVATION COM, ;ION • APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request. Abandon 1 Rug Perforations r Fracture Stimulate r Rill Tubing r Operations Shutdown r Suspend Perforate r Other Stimulate r After Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other:Wellhead removal I7 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. ConocoPhillips Alaska, Inc. Exploratory r Development r- 186-108 3.Address: Stratigraphic r Service r 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-103-20069-00 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No r (/ KRU 2T-07 9.Property Designation(Lease Number): 10.Field/Pool(s). ADL 25569 Kuparuk River Field/Kuparuk River 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). 6975 • 6087 ' 6897' ' 6032' ' cement to surface none Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 110' 110' SURFACE 2740 9.625 2773' 2772' RECEIVED PRODUCTION 6419 7 6449' 5724' LINER 747 5 6975' 6087' JUL 0 9 2015 AOGCC Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size. Tubing Grade. Tubing MD(ft): 6524-6539,6571-6613" 5776-5786,5808-5837 2.375 J-55 6566 Packers and SSSV Type. Packers and SSSV MD(ft)and TVD(ft) PACKER-BROWN HB-1 PACKER MD=6076 TVD=5472 PACKER-BAKER DB PACKER W5'SEAL BORE EXT. MD=6551 TVD=5795 • SAFETY VLV-CAMCO TRDP-1A-SSA MD=1786 TVD=1786 12.Attachments: Description Surrrnary of Proposal r' 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development p- Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: �yL 7/13/2015 OIL r VVINJ r WDSPL r Suspended ,_ 1'J 16.Verbal Approval: Date: GAS r WAG r GSTOR r SPLUG r/ Commission Representative. GINJ r Op Shutdown r Abandoned lV 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact. Jill Simek @ 263-4131 Email. Jill.Simekconocophillips.com Printed Name J. ime. Title. Staff Well Integrity Engineer Signature , II Phone:263-4131 Date I-/1/ I$ IF Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness / 3 IS-_{ lZ Plug Integrity BOP Test r Mechanical Integrity Test r Location Clearance (�7 Other: 2e. do c-c.-. C a 5i Gcc —Ca/ f itieec ee // Spacing Exception Required? Yes ❑ No .[/] Subsequent Form Required: / 0 —4/ Pli;t44711,--- APPROVED BY7-/ /C " Approved by: T COMMISSIONER THE COMMISSION Date: (J Approved a plicatr n is va d or 11 m nth fr.ii the date of approval. Submit Form and OrIGIN �► pc_ �_,3_,�- Form 10-403 Revised 5/2015 f3 RBDIh is in 4jiplicei 2015 .I�7�j�� JUS r 1 ConocoPhillips RECEIVED Alaska P.O. BOX 100360 I U L 0 9 2 015 ANCHORAGE,ALASKA 99510-0360 AOGCC 8 July 2015 Commissioner State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc. hereby applies for an Application for Sundry Approval to abandon KRU 2T-07 (PTD#: 186-108). The well is currently undergoing suspend operations with the Nabors 7ES rig. After rig operations, the well will be suspended with cement to surface and a dry hole tree installed. Per the attached procedure, abandonment operations will be performed on 2T-07 to remove the tree, ,- excavate, and cut and remove casing strings and wellhead. Operations will commence after Nabors 7ES c.c has finished suspend activities. If you have any questions or require any further information,please contact me at 263-4131. Sincerely, I Ev.uk J `'mek -ItIntegrity Engineer It CPAI Drilling and Wells ConocoPhillips KRU 2T-07 Permit to Drill #: 186-108 The objective of the proposed 2T-07 abandonment is to remove the tree, excavate, and cut and remove casing strings and wellhead. Wellhead Excavation / Final Abandonment: 1. Receive Rig Handover Form from Nabors 7ES. Confirm well status. 2. Ensure all pressure is bled off the system. 3. Remove the tree, in preparation for the excavation and casing cut. 4. If shallow thaw conditions are found, have shoring box installed during the excavation activity to prevent loose ground from falling into the excavation. 5. Cut off the wellhead and all casing strings at 4 feet below original ground level. 6. Verify that cement is at surface in all strings; perform top job, if necessary. AOGCC witness and photo document required.' 7. Send the casing head w/ stub to materials shop. Photo document. 8. Weld "1/4" thick cover plate (16" O.D.) over all casing strings with the following information bead welded into the top. Photo document. AOGCC Witness Required. / ConocoPhillips 4 2T-07 , PTD #: 186-108 API #: 50-103-20069-00-00 +� 9. Remove Cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 10. Obtain site clearance approval from AOGCC. RDMO. 11. Report the Final P&A has been completed to the AC/C2C.C, and any other agencies required. Photo document final location condition after all work is completed. L� ��• ( � ecit SFS clues- - ,IS Dry Hole Tree KRU 2T-07 ConocoPhillips I Suspended Producer _.. ' 5 Plug&Suspend—07-Jul-2015 16"62.5#H-40 W LD,110'MD "' ' Compromised 9-5/8"Surface Casing. & 4 1-Cut 2-7/8"Tubing-1700'MD,PU 5'MD Partially Milled Through-348'to 355'MD2-Pump Balanced Plug 1700'to 400'MD )ccurred while milling to regain access to tubing stub) ':, 3-WOC,Tag/PT,Cut 2-7/8"Tubing Above 4-Cut&Pull 7"Casing(-340-350'to Surf) iii iii: 2 5-Set 9-5/8"Cement Retainer at-250'MD iiiii: ii: 6-Squeeze OOA/Surface Casing Holes Primary Surface Casing 7-Lay In Cement Above Retainer Cement 18bb1 Top Job `; :: 8-Document Cement to Surface 1: :: 9-Install Dry-Hole Tree 1785'MD,Camco TRDP-1A SSA Top Arctic Set/-1784'MD I • (Locked Out 1991,Flapper Locked 1993) I 2582'MD,Camco KBMG GLV-BK 9-5/8"36#J-55 BTC,2772'MD :;ii iiiiii 15.8ppg Class G Balanced Plug 6026'MD to-1800'MD i--1104i iii Pumped 07-Jul-2015 ` 4090'MD,Camco KBMG GLV-BK Planned Tag 08-Jul-2015 2-7/8"6.5#,J-55 Tubing Deepest Possible 7"Casing TOC-4400'MD--►,. (NOTE:Lost returns during job.document lost circulation zone 3800'to 4400'MD while dolling) 4956'MD,Camco KBMG DMY-BK Drilling Mud(Existing) Cement(Existing) Arctic Pack(Existing) Brine w/Wellbore Fluids (Existing) i 5318'MD,Camco KBMG GLV-BK KW Brine(9.4ppg) PropoSed �lt. Cetite ::::.; 5697'MD,Camco KBMG DMY-BK Pulled Seals Free 06-Jul-2015 • / 6016'MD,MMH HTC OV-RK Spaced Tubing Tail to 6026'MD NOTE:All upper completion depths should----1� be adjusted-45'MD shallower. ' '—6056'MD,Brown PBR F -� +1—6076'MD,Brown HB-1 Packer 6113'MD,Camco KBMG DMY-BK f_6136'MD,OTIS XA Sliding Sleeve (Closed 1995) l 4. 6155'MD,2.250"Camco D Nipple 2-7/8"x 2-3/8"Crossover 1► ��---6228'MD,Baker Mod'A'Liner Hanger 7"26#J-55 BTC,6448'MD ► 2-%"4.7#N-80 Tubing 6524'-6539'MD,C Perforations Ir ...4 6551'MD,Baker DB Packer w/5'SBE Oa 4 6563'MD,1.812"Camco D Nipple I 1 6565'MD,Camco Shear-Out Sub 6571'-6613'MD,A Perforations (Cement Plugged in 2010) 5"18#S-140,6975'MD 1111 I Date: 07-Jul-2015 I Drawn By: Danny Kane Zi-c7 Pr-b taw) Regg, James B (DOA) From: Regg,James B (DOA) i`' (� 1(1//15- Sent: fZ/ISSent: Thursday, July 02, 2015 11:03 AM To: 'Kane, Danny'; Loepp, Victoria T (DOA); Schwartz, Guy L (DOA); 'AOGCC.Inspectors@alaska.gov' Cc: Nabors 7ES Company Man; Rauchenstein, Rock D; Kanady, Randall B Subject: RE: KRU 21-07 - Plug & Suspend Update & Potential BOPE Test Waiver Request - 01- Jul-2015 KRU 2T-07 PTD 1861080 SCANNED l.!(� .1 410 I4 Danny- I appreciate the summaries and phone discussion this morning updating your progress. Request to delay t ekly BOPE test is approved through Sunday, 7/5. BOPE test results for Nabors 7ES have been good (last witnessed 6/17/15). If you have not met your objective (open up a circulation point above the production packer to set a balanced plug) by Sunday we can consider a further delay. Also, if you lose connection with the 2-7/8" tubing and have to trip the work string to surface you are expected to test before reentry. Please continue to update us throughout the weekend by email; I am also available by phone. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jim Regg at 907-793-1236 or jim.regg@alaska.gov. Original Message From: Kane, Danny [mailto:Danny.Kane@conocophillips.com] Sent: Wednesday,July 01, 2015 6:43 PM To: Loepp,Victoria T(DOA); Schwartz, Guy L(DOA); Regg,James B (DOA) Cc: Nabors 7ES Company Man; Rauchenstein, Rock D; Kanady, Randall B Subject: Re: KRU 21-07 - Plug&Suspend Update& Potential BOPE Test Waiver Request-01-Jul-2015 All, We have continued bailing milled debris and formation down to 1794'SLM and believe we are working down a bridge that formed above the bore upsets within the SSSV. Given our slow progress and unknown timeline until we break 1 through, ConocoPhillips will be formally requesting a variance to extend the start of our BOPE test past the one week cycle Nabors 7ES is currently on. I will call first thing in the morning to discuss this. The purpose of this email is to prevent any confusion, as our company men have submitted the 24-hour notice and have cited that we will be asking for a variance. Please feel free to call me at 227-6037 if you would like to discuss this matter this evening. Regards, - Danny Danny Kane Drilling Engineer-WNS ConocoPhillips Alaska, Inc. +1 (907) 265-6048-Office +1 (907) 227-6037- Mobile danny.kane@conocophillips.com<mailto:danny.kane@conocophillips.com> On Jul 1, 2015, at 11:46, Kane, Danny<Danny.Kane@conocophillips.com<mailto:Danny.Kane@conocophillips.com>> wrote: All, Nabors 7ES is currently performing slickline drift operations in an attempt to get back down our 2-7/8" tubing to open up a circulation point above our production packer(needed to set our balanced plug above the packer). We have been bailing mill debris at–1792' MD for the past 12 hours and making very slow—but continued—progress. I wanted to send this email to provide forewarning that we may request a BOPE test waiver to delay the start of the test so that we can complete drift operations, create a circulation point, & possibly pump our balanced plug (within reason). The next weekly BOPE test due for Nabors 7ES is due to start tomorrow. While our hope is that we can finish these operations before the BOPE test, there is as of right now the possibility that we may not have completed the work. Please see below for what would be our reasoning for delaying the start of the test: Background: • We started milling the damaged 7" production casing on 17-Jun-2015 at–348' MD. The casing was severely buckled and over the course of 49 mill runs (& subsequent camera runs to confirm milling success), we were able to mill through the buckled casing to–355.5' MD where we started to mill outside the 7" production & 9-5/8" surface casing on 28-Jun-2015. With the tubing stub only 3.5' beneath where milling stopped and our uncertainty on which direction the casing was turning, we stopped milling ahead &were having trouble getting our mills to walk back inside the casing. Fearing an accidental sidetrack, we ran in with a 2-7/8" muleshoe and were surprised when it drifted down to the tubing stub (this was the first time we had been able to do this). • We then decided to see if we could screw into the tubing stub (box is looking up at us) and after a few tries, we were able to get a 2-7/8" tubing joint with a cut-lip machined into the pin end to walk into the casing—and more importantly—got it screwed in 'hand-tight' into the 2-7/8" tubing box looking up. • Starting yesterday morning (30-Jun-2015), we got 24hr slickline crews on location to start drift operations w/ E-line on standby to create a deep circulation point. Reason for Potential Waiver Request 2 • Right now we have drift access to the tubing stub and are working on drifting past 350' MD—the furthest we have been in the past couple years. There is a risk that we could lose access to the tubing stub if we come off of it right now (whether that be we're unable to guide the pup joint back down, that residual stresses start to deform the 7" &9-5/8" casing strings that we've partially milled through, etc.). Barrier Discussion: • We initially killed the well with 9.4ppg NaCI brine and we have been experiencing losses of 1/2 to 1-1/2 bph since; we have kept the well full and there has been no indication of gas migration. Again,this email is more of a forewarning and not a formal request yet. At the time that we do make such a request, I can come down to discuss in further detail what we have done on 21-07 to date, explain our current situation in better detail, and provide additional details on the plan forward. Regards, Danny Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1709 Office: +1907 265-6048 Mobile: +1907 227-6037 danny.kane@conocophillips.com<mailto:danny.kane@conocophillips.com> From: Kane, Danny Sent: Tuesday,June 30, 2015 4:33 PM To:Victoria Loepp (AOGCC); 'Schwartz, Guy L (DOA)' Subject: KRU 2T-07 - Plug&Suspend Update -30-Jun-2015 Victoria & Guy, Here's a quick recap of the past 24hrs on KRU 21-07—we have some positive news as we were able to get back onto the tubing stub: • We attempted to completely screw into the 2-7/8" tubing stub with a 2-7/8" pup joint with a machined cut-lip guide on the pin. We weren't able to get engaged enough to pick-up on the tubing. • Currently threaded 'hand-tight' into the tubing stub, acting as a wireline entry guide. • Drifted down 2-7/8" tubing to^'1792' with 1-1/2" bailer, currently tripping out to empty bailer. • Plan Forward: o Continue drift operations to production packer at 6076' MD. o Open up deep circulation point (pull OV from GLM at 6016', tubing punch, or split shot depending on drift run success). o Prepare to pump balanced plug from deep circulation point to 1800' MD—may need to perform more milling to get a sealed connection to our tubing stub. 3 r Regards, - Danny Danny Kane Senior Wells Engineer ConocoPhillips-ATO 1709 Office: +1907 265-6048 Mobile: +1907 227-6037 danny.kane@conocophillips.com<mailto:danny.kane@conocophillips.com> 4 VISCP-k 0416 bclat WELL LOG TRANSMITTAL DATA LOGGED -7/.BE14/20NDER15 K To: Alaska Oil and Gas Conservation Comm. '• June 22, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 JUN 26 2U1:; Anchorage, Alaska 99501 RE: Multi Finger Caliper(MFC) x2 &Jet Cut Record: 2T-07 Run Date: 6/9/15, 6/12/15, 6/21/15 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 2T-07 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-103-20069-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: 1' 2 o_e.itedt (-Co-r s, THE STATE Alaska Oil and Gas 0A Li ..SIK \. Conservation Commission ifit =� 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 -"•� Main. 907.279 1433 OFALASIJFax' 907 276 7542 NME� ` L Q B 201q www aogcc alaska.gov Danny Kane 5`a Sr. Wells Engineer V ConocoPhillips Alaska, Inc. V P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2T-07 Sundry Number: 315-374 Dear Mr. Kane: 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, 441"-47 ; Daniel T. Seamount, Jr. Commissioner DATED this !t day of June, 2015 Encl. STATE OF ALASKA RECEIVED . AL....)KA OIL AND GAS CONSERVATION COMi_ 3ION JUN 1 7 2015 C (,\\,A6 APPLICATION FOR SUNDRY APPROVALS • ,-Pi- 20 AAC 25.280 AOGCC 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations Shutdown r Suspend 17 Perforate r Other Stimulate r Alter Casing r7 Change Approved Program P Rug for Redrill E perforate New Pool rRepair Well iv Re-enter Susp Well r Other: r 2.Operator Name. 4.Current Well Class. 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. • Exploratory r Development F„-,. 186-108 3.Address: Stratigraphic r Service r_ 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-103-20069-00' 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No P. KRU 2T-07 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25569 • Kuparuk River Field/Kuparuk River 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): 6975• 6087 - 6897' . 6032' • 6555' none Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 110' 110' SURFACE 2740 9.625 2773' 2772' PRODUCTION 6419 7 6449' 5724' LINER 747 5 6975' 6087' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade. Tubing MD(ft). 6524-6539,6571-6613' . 5776-5786,5808-5837 2.375 J-55 6566 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BROWN HB-1 PACKER MD=6076 TVD=5472 • PACKER-BAKER DB PACKER W5'SEAL BORE EXT. MD=6551 TVD=5795 SAFETY VLV-CAMCO TRDP-1A-SSA MD=1786 TVD=1786 • 12.Attachments Description Summary of Proposal r 13. Well Class after proposed work Detailed Operations Program E BOP Sketch r Exploratory r Stratigraphic r Development r,% • Service r 14.Estimated Date for Commencing Operations: 15 Well Status after proposed work 0 6/15/2015 OIL i VVINJ r WDSPL r Suspended v 16.Verbal Approval: Victoria Loepp Date: 6/15/2015 GAS r WAG r GSTOR r SPLUG r Commission Representative. GINJ n Op Shutdown r Abandoned r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Danny Kane @ 265-6048 Email: Daniel.Kaneconocophillips corn Printed Name Danny Kane Title Sr. Wells Engineer Signature Phone:265-6048 Date(6-3 ON-atAc. Commission Use Only Sundry Number: Conditions of approval. Notify Commission so that a representative may witness 3‘ .-3---7 Plug Integrity rkVBOP Test iv Mechanical Integrity Test r Location Clearance r Other: A/otl-Pc) ftUC7CG" ?1 h r 5 /-i czC/vai,c. to 1A-,/-7Lfrir53 p /uj PT .e 14; . Pkzcfo c11OCv{-v,Critel. f/`a v) of c'C/-v, c� f f-afj oF-7, „ c4 ,,,-,u/J• El f 6/��z9 . .56/2 /e--57” to 75- 0 /751 (M n5P 15 0/ Z6 p5, Spacing Exception Required? Yes ❑ No Z Subsequent Form Required: /a — 4 0 APPROVED BY / / // !�� Approved by: o COMMISSIONER THE COMMISSION Date (p /` �/ /✓ VT L. 6//8//5- Approved application is valid tor 12 moonnl rfi thr date Qt approval. Submit Form and Form 10-403 Revised 5/2015 ? �l ft s. RR II GG NAL Attachments in Duplicate RBDMS JUN 2 4 2015 ConocoPhillips Alaska P.O. BOX 100360 RECEIVED ANCHORAGE,ALASKA 99510-0360 June 16,2015 JUN 1 7 2015 Cathy Forester AOG Cc State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to continue working over Kuparuk Producer KRU 2T-07(PTD# 186-108,Sundry#315-275). Well KRU 2T-07 was drilled and completed as Kuparuk A- &C-sand selective producer in 1986. The A-sand was fracture stimulated in 1988 with primary production since being from the A-sand along with intermittent C-sand production from 1988-1995. In March 1995 IA x OA communication was observed and the inner casing pack-offs were plastic-packed to mitigate. In 2000 an OA leak was observed and LLR logging determined the leak to be at 350' MD—subsequent repair attempts have been unsuccessful. In 2002 the inner casing pack-offs failed to test and because of the plastic packing,remedial work has been unsuccessful. Subsidence was first observed starting in the early 2000s. In 2010, the A-sand perforations were plugged back with cement in order to prepare the well for a slot recovery program. After the cement was pumped, slickline was unable to drift (1.15")the tubing to tag-up on the estimated TOC at 6555'MD;however,a MIT-T did pass. In 2013,subsequent MIT-Ts failed and the subsidence had worsened to the point that the slickline is unable to drift the tubing past—350' MD with a 1"custom split shot. Nabors 7ES moved onto the well 06-Jun-2015 and was unable to regain tubing wireline drift access despite bringing the tubing to neutral weight and growing&stretching the production casing. After attempting to pull the tubing seals free,the tubing parted(pin jumped connection)at—350' MD. Subsequent wireline diagnostic work and tubing drift attempts showed the production casing was too badly damaged to continue with the original plan forward. The proposed continuation of this work-over will be to complete plug & suspension operations to surface. After milling the damaged 7"production casing interval (minimum required to regain tubing drift), latch onto the tubing stub at—360' MD, drift the production tubing, and shoot tubing punch or split shot to create deep circulation point above the production packer. Spot a balanced cement plug from circulation point to—1800' MD. After confirming top of the balanced plug cement in the tubing,release from the tubing stub and cut slots in the 7"production casing at —340' MD. A cement retainer will be set at—250' MD and cement will be squeezed down the 7"production casing, through the slots, and up the OA to surface. Once good cement is observed at surface,the IA will be choked-in and the surface casing leak will be squeezed. Cement will then be laid in on top of the retainer to surface. After confirming cement to surface in all annuli,the top of cement will be photo-documented and a dry hole tree will be rigged up. This Sundry is intended to document the proposed work on KRU 2T-07 because of the intent to Change Approved Program while continuing plug&suspension operations on this well. If you have any questions or require any further information,please call me at 265-6048 or email danny.kane@conocophillips.com. Sincerely, 1 Danny Kane Wells Engineer CPAI Drilling and Wells KRU 2T-07 Rig Workover Plug & Suspend (PTD #:186-108 / Existing Sundry #:315-275) Current Status: Nabors 7ES moved onto KRU 2T-07 under Sundry#315-275 and is currently attempting to plug&suspend the well as per that Sundry procedure. After pulling the 2-7/8"tubing to neutral weight and growing&stretching the 7" production casing,wireline drift access had not been restored experiencing the same hard tag during pre-rig work at —350' MD. In an attempt to pull the 2-7/8"seals free from the Brown PBR at 6,056' MD,the tubing parted(pin jumped)at 350' MD when the tubing connection was being pulled across a section of damaged 7"production casing and(high side-loading forces). E-Line was then rigged up on the well and acquired caliper data,downhole camera images,&tubing drift information across the 7"production casing damage at 350' MD. Scope of Work: Mill 7" production casing damage at— 350' MD to regain access to the 2-7/8" tubing stub at—360' MD. Create a deep circulation point(hole punch/split shot or pulling seals free) above the Brown HB-1 packer at 6,076' MD and confirm sufficient circulation rates for cement job. Spot balanced Class G cement plug in tubing&IA to 1,800' MD. Wait on cement, pressure test, & tag TOC within the tubing. Release from 2-7/8" tubing stub and lay-down work string. Cut slots in the 7" production casing at—340' MD (adjusted as per casing damage), and displace the Arctic Pack in the OA at that depth to surface. Set cement retainer at 250' MD on tubing and cement 7"production casing x OA to surface via slots with Arctic Set I(w/CemNET LCM); once good cement is returning at surface, choke the OA&squeeze cement through 9-5/8"surface casing leak at—350'MD. Un-sting from retainer&lay-in cement above retainer to surface. Confirm TOC&install dry-hole tree. General Well Info: Well Type: Producer MPSP: 2,120 psi using MASP=(PP-(0.1*TVD)),assuming dry gas gradient to surface. ✓ Reservoir Pressure/TVD: Kuparuk C—2,500 psi/5,776' TVD(8.4 ppg EMW) Kuparuk A—2,700 psi/5,808' TVD(9.0 ppg EMW) Wellhead Type/Pressure Rating: CIW Gen IV(5M Tubing Head/3M Casing Head) BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT results: MJT-T Failed 02-May-2013 Last Passed 19-Dec-2010 MIT-OA Failed 01-Nov-2003 Leak Identified at—350'RKB NOTE: IA x OA communication identified after growing&stretching 7" production casing during this work-over. Earliest Estimated Start Date: Nabors 7ES MIRU 06-Jun-2015 Production Engineer: Tommy Nenahlo Workover Engineer: Danny Kane (907)265-6048 danny.kane@conocophillips.com Work-over Summary to Date: 1) MIRURWO Rig 2) Kill Well w/9.4ppg Brine, Flow Check(Static), ND Tree,NU& Test BOPE 3) Pull 2-7/8" Tubing to Neutral Weight(5'Stretch), RU E-Line,Attempt to Drift(Unsuccessful) 4) Cut Tubing Above Obstruction, L/D Same, Set RBP 5) ND BOPE 6) Grow&Stretch(50klbs over) 7"Production Casing(23-5/8"Growth, <1"Stretch) 7) Re-Land Production Casing,NU&Shell Test ROPE, Retrieve RBP 8) TIH w/Overshot, Latch On to Tubing Stub, RU E-Line,Attempt to Drift(Unsuccessful) 9) Establish Reverse Circulation Parameters(For Potential Reverse Circulation of Balanced Plug) a) Decide to hold off on Reverse Circulation because of current Gas-Lift Design complications KRU 2T-07 Rig Workover Plug & Suspend (PTD #:186-108 / Existing Sundry #:315-275) 10) Attempt to Pull Seals Free at 80% Tubing Tensile Limit(8'Stretch— Tubing Movement), Attempt to Pull Seals Free at 90% Tubing Tensile Limit a) 2"d Pull at 90%, Pin Jumps as Connection Crosses Production Casing Damage(High sideforces) 11) Attempt to Drift Overshot&Muleshoe to Tubing Stub(Unsuccessful) 12) RU E-Line&Acquire Data on Production Casing Condition& Tubing Stub Orientation a) Perform Caliper & Video Runs —Determine Production Casing is Severely Buckled/Bent (Acute Angle) Preventing 3-1/2"Mule Shoe Drifting b) The pin jumped at this obstruction from excessive side-loading. 13) Drift Past Obstruction w/2-7/8"Mule Shoe, Deformed Once Pulled to Surface(Mule Shoe) 14) Perform MIT-IA, Find IA is in Communication w/OA a) NOTE: During initial well kill,IA &OA were not in communication. 15) Perform BOPE Test. Annular failed 2-7/8"test; unable to swap annular element, work on swapping annular. Summary Procedure: Rig Workover 1. Mill through the production casing damage. Use time milling procedures&E-line camera crews to ensure the damage is being milled as per plan. a. Adjust milling strategy&mill selection based upon real-time results. 2. Once the damaged interval has been milled,use E-line camera crew to determine depth and orientation of tubing collar looking up. 3. Get back onto the tubing stub&regain wireline drift access (RU E-Line & attempt to drift small tubing punch or 1"split shot to the first joint above the Brown HB-1 production packer). a. Attempt to screw a 2-7/8"L-80 tubing joint into the collar looking up. b. CONTINGENCY#1: If unable to screw into the tubing stub,attempt to latch onto the tubing collar with an overshot. This may require extra milling to enlarge the milled hole through the obstruction. c. CONTINGENCY#2: If unable to regain tubing drift access, attempt to spear into the tubing stub and pull the seals free up to 80%tubing tensile yield. d. CONTINGENCY#3: Some offset 2T wells have had a second significant subsidence interval at 1000' MD—this interval may necessitate a full subsidence workover. 4. Establish circulation through deep circulation point. a. CONTINGENCY #4: If unable to get pressure-tight seal screwed into existing collar, RU E-Line, cut the tubing mid joint beneath the uppermost collar,and latch onto cut tubing stub with sealing overshot. b. CONTINGENCY#5:If unable to establish a deep circulation point,discuss reverse circulating 15.3ppg (micronized, low rheology cement)balanced plug with Anchorage Engineering team. 5. Spot balanced plug of 15.8ppg Class G cement(Plug#1)from the deep circulation point to 1800' MD. Notify AOGCC to witness tag&pressure test of plug after necessary compressive strength has been built. Z� G,-S 6. Release from tubing stub at—360' MD. , I, c 7. TOH work string&lay-down same. 8. Shoot MCR PTC-2937(perforating torch)at—350' MD,above 7"production casing damage. 9. Displace Arctic Pack from OA with heated freshwater(displace well from KW brine to freshwater). 10. Pick-up,TIH,&set K-1 Cement Retainer at—250' MD. Pressure test to 500 psi from above to confirm set. 11. RU Dowell cementers and pump OA surface plug of Arctic SET I(Plug #2) down IA & up OA (through production casing torch slots). With good returns to surface, choke in OA and squeeze surface casing leak. 12. Unsting from retainer,TOH&LD running tool,and TIH&tag-up on retainer with drill pipe. 13. RU Dowell cementers &pump final surface plug of 15.7ppg Arctic SET I (Plug#3) above retainer. TOH w/ drill pipe. Perform IA top job for pipe steel displacement. Release E-Line. RD Dowell cementers&WOC. KRU 2T-07 Rig Workover Plug & Suspend (PTD #:186-108 / Existing Sundry #:315-275) 14. Notify AOGCC&document cement to surface in IA,OA,&OOA. a. If cement is not within 5' of surface of any annulus,perform top-off job,&photo document to surface. 15. ND BOPE&NU dry hole tree. 16. RDMO RWO Rig Post-Rig Work 1. Turn suspended well over to Well Integrity. s KUP 2T-07 ConocoPhillips /a Well Attributes lMax Angle&MD TD Inc Wellbore APIAIWI Field Berne Well States Inci(°) MD(ftKB) Act Bim(ftKB) Alaska. alps 501032006900 KUPARUK RIVER UNIT PROD 49.68 5,400.00 6,975.0 CaeocoPh " Comment H2S(ppm) Date Annotation End Date KBGrd(ft) Rig Release Date • -•• Well Confq:-2T-07,1131201210073/AM SSSV:LOCKED OUT 40 1/112009 Last WO: 40.00 8/28/1986 Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: 6,573.0 2/7/2004 Rev Reason:WELL REVIEW osborl 1/31/2012 p . / Casing Strings HANGER,28 :t; Casing Description String 0... String ID...Top(ftKB) Set Depth(1...Set Depth(TVD)...String Wt...Slang... String Top Thrd CONDUCTOR 16 15.062 33.0 110.0 110.0 62.50 P1-40 WELDED Casing Description String 0... String ID„.Top(ftKB) Set Depth(f.„Set Depth(TVD)...String WL..String...String Top Thrd SURFACE 9 5/8 8.765 33.0 2,772.5 2,772.4 36.00 J-55 BUTT NI Casing Description String 0... String ID„.Top(ftKB) Set Depth(f...Set Depth(TVD)...String WL..String...String Top Thrd PRODUCTION 7 6.276 30.1 6,448.6 5,724.2 26.00 J-55 BTC Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String WL..String...String Top Thrd LINER 5 4.151 6,228.5 6,975.0 6,087.1 18.00 S-140 LTC Liner Details CONDUCTOR,- Top Depth 33-110 (TVD) Top Incl Need... Top(ftKB) (0K6) ("I Item Description Comment ID(In) SAFETY VLV. 0 6,228.5 5,574.5 47.49 HANGER BAKER LINER HANGER 5.000 1,786 Tubing Strings GAS LIFT, Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd 2.5x2 TUBING 27/8 2.441 28.3 6,565.9 5,804.9 6.50 .1-55 EUE8rdABMOD 2.875"x2.375" Completion Details Top Depth (TVD) Top Incl Nomi... t Top(ftKB) (0KB) (°) Item Description Comment ID(in) SURFACE, / l 28.3 28.3 0.11 HANGER CIW TUBING HANGER 2.441 33-2,772 1,785.6 1,785.5 0.25 SAFETY VLV CAMCO TROP-1A-SSA(LOCKED OUT 9/3/1993) 2.312 GAS UF't 6,056.8 5,459.4 48.16 PBR BROWN PBR _-- 2.500 4,090 6,076.0 5,472.3 48.11 PACKER BROWN HB-1 PACKER 2.750 GAS uEr,_ 6,135.6 5,512.1 47.96 SLEEVE-C OTIS XA SLIDING SLEEVE(CLOSED 4/2/1995) 2.310 4.957 6,154.5 5,524.8 47.91 NIPPLE CAMCO D NIPPLE 2250 GAS LIFT, j 6,156.4 5,526.0' 47.91 XO reducing XO reducing 2.875x2.375,4.704,N-80,1.995 2.375 5.319 1 - 6,512.0 5,767.8 46.53 BLAST RING CARBIDE BLAST RING 1.995 .._ 6,550.0 5,793.9 46.54 LOCATOR BAKER LOCATOR 1.995 6AS 5897 _ 6,551.0 5,794.6 46.54 PACKER BAKER DB PACKER w5'SEAL BORE EXT. 3.250 6,563.0 5,802.9 46.54 NIPPLE CAMCO D NIPPLE NO GO 1.812 GAS LIFT, 6,565.3 5,804.5 46.54 SOS CAMCO SHEAR OUT 1.995 8,018 Other In Hole ireline retrievable plugs,valves,pumps,fish,etc.) PBR.6.057 - - -_- Top Depth (TVD) Top Incl Des PACKER,6.m6 - --iiirli. Top(ftKB) (ORB) (°) Description Comment Run Date ID(in) 6,555.0 5,797.4 46.54 CMT PLUG Pumped 15 bbls of 15.8 ppg Class G cement slurry 12/162010 0.000 GAS LIFT. t -0 perforations&Slots 6.11 I Shot Top(TVD) Btm(TVD) Dens - Top(ORB)Btm(ftKB) (SKB) (ftKB) Zoo. Date (FB- Type Comment SLEEVE 36 � 6,524.0 6,539.0 5,776.1 5,786.4 C-4,Unit B, 10/30/1986 12.0 IPERF 33/8"HyperJet II;60 deg.Ph ate2T-07 NIPPLE,6,155 II- 6,571.0 6,613.0 5,808.4 5,837.2 A-3,2T-07 10/30/1986 12.0 IPERF 3 3/8""HyperJet II;60 deg.Ph Notes:General&Safety End Date Annotation -, 2/7/2004 NOTE:HEAVY, ERRATIC PICKUP WEIGHTS SUGGEST CORKSCREW TBG FROM TTL-500' 1 1 11/30/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 PRODUCTION, A 4 306,449 II a 6,524PERF,6.539 I fill i LOCATOR, III �`; PACKER.6.551 I NIPPLE,6,563 II I Mandrel Details Top Depth Top Port SOS,6,565 , "- (TVD) Incl OD Valve Latch Size TRO Run CMT PLUG, Ste Top(ftKB) (ftKB) CI Make Model On) Sere Type Type (in) (pal) Run Date Com... • 6.Sss� 1 2,582.2 2,582.1 0.30 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,336.0 10/302004 IPERF, 8,571-6,813 2 4,090.0 4,015.0 31.48 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,334.0 10/30/2004 Cement Plug 3 4,956.9 4,718.6 37.88 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 10/31/1986 6.555 4 5,318.6 4,977.0 49.92 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,327.0 10/30/2004 5 5,6972 5,223.0 49.53 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 10/31/1986 6 6,016.0 5,432.3 48.26 MMH HTC 1 12 GAS LIFT OV RK 0.250 0.0 3/42006 7 6,113.6 5,497.4 48.02 CAMCO KBMG 1 PROD DMY BK 0.000 0.0 10/31/1986 Closed LINER, 6.2213-6,975N i ID. TD,6,975 Dry Hole Tree KRU 2T-07 ConocoPhiIIu s Suspended Producer • Casing Damage Mitigation P&S 16"62.5#H-40WLD,110'MD ►'' .. :;:;: ' t ■ Cement Retainer-250'MD 9-5/8"Casing Leak,350'MD Cut Holes Production Casing-345'MD 7"Casing Leak 7"Production Casing Damage 350'MD Assumed 350'MD (Will Attempt to Mill Through Obstruction) Primary Surface Casing (Assumed Damage Caused by Surface Casing) Cement, 18bbI Top Job ' 2-7/8"Tubing Stub-360'MD Top Balanced Plug-1800'MD 1785'MD,Camco TRDP-1A SSA Top Arctic Set I-1784'MD (Locked Out 1991,Flapper Locked 1993) 2582'MD,Camco KBMG GLV-BK 9-5/8"36#J-55 BTC,2772'MD ► Eoni f 4090'MD,Camco KBMG GLV-BK 2-7/8"6.5#,J-55 Tubing i::111UO2.:: -4--4956'MD,Camco KBMG DMY-BK Drilling Mud(Existing) Cement(Existing) Arctic Pack(Existing) Brine w/Wellbore Fluids (Existing) 4 5318'MD,Camco KBMG GLV-BK KW Brine(9.4ppg) :•Prbp;oSed:CehiBnl::_:::: :;:�D::: 4 5697'MD,Camco KBMG DMY-BK Tubing Punch or Split Shot :: 6016'MD,MMH HTC OV-RK (Assumes Tubing Drifts) ; {► a' Pull Seals Free if No Drift I 6056'MD,Brown PBR 6076'MD,Brown HB-1 Packer • 6113'MD,Camco KBMG DMY-BK 6136'MD,OTIS XA Sliding Sleeve (Closed 1995) 6155'MD,2.250"Camco D Nipple 2-7/8"x 2-3/8"Crossover ► 6228'MD,Baker Mod'A' Liner Hanger 7"26#J-55 BTC,6448'MD ► 2-%"4.7#N-80 Tubing ► 6524'-6539'MD,C Perforations 6551'MD,Baker DB Packer w1 5'SBE ai - 6563'MD,1.812"Camco D Nipple 6565'MD,Camco Shear-Out Sub 6571'-6613'MD,A Perforations (Cement Plugged in 2010) 5"18#S-140,6975'MD ► Date: 15-Jun-2Oi5 Drawn By o:,5„,Kane rel(t)r :OF Ty �j sT THE STATE Alaska Oil and Gas 7� vfALAS :A Conservation Commission •#2 333 West Seventh Avenue '1/1GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 , ���� Main. 907.279.1433 OF ALAS* :step ��A� S Fax. 907.276.7542 SCO" www aogcc alaska gov Danny Kane b° Sr. Wells Engineer ConocoPhillips Alaska, Inc. _ P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2T-07 Sundry Number: 315-275 Dear Mr. Kane: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P Foerster Chair DATED this Aay of May, 2015 Encl. • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMI,_ SIGN • APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair w ell Change Approved Program r Suspend .1-7. • Rug Perforations r• Perforate r Pull Tubing r • Time Extension r" Operational Shutdow n r Re-enter Susp.Well F , Stimulate E Alter casing "Other: r- 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc.• Exploratory r Development r F . 186-108• 3.Address: Stratigraphic r Service I- P.O. Box 100360,Anchorage,Alaska 99510 50-103-20069-00- 7.If perforating, 8 Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception', Yes r No r / KRU 2T-07 . 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25569 . Kuparuk River Field/Kuparuk River 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): 6975 6087 6897' 6032' 6555' none Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 110' 110' SURFACE 2740 9.625 2773' 2772' RECEIVED PRODUCTION 6419 7 6449' 5724' LINER 747 5 6975' 6087' MAY 0 6 2015 OGCC` l5 Perforation Depth MD(ft). Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6524-6539',6571'-6613' . 5776'-5786',5808'-5837' 2.375 J-55 6566 Packers and SSSV Type• Packers and SSSV MD(ft)and TVD(ft) PACKER-BROWN HB-1 PACKER MD=6076 TVD=5472 • PACKER-BAKER DB PACKER W5'SEAL BORE EXT. MD=6551 TVD=5795 • SSSV-CAMCO TRDP-1A-SSA MD=1786 TVD=1786 • 12.Attachments: Description Summary of Proposal rtii 13 Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r�r• Service r 14.Estimated Date for Commencing Operations. 15. Well Status after proposed work. 5/20/2015 Oil r Gas r WDSPL r Suspended g7. 16.Verbal Approval. Date• WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Danny Kane @ 265-6048 Email: Daniel.Kane@conocophillips corn Printed Name Danny K Title: Sr. Wells Engineer Signature L._ Phone:265-6048 Date dYS-t-AA1/4j 2¢PIC Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness "315- 2:7G Plug Integrity V BOP Test fr Mechanical Integrity Test r Location Clearance r Other: L3c7P tl5 t to 25 ' p25' ( /v p 5 P 15 2/ Z C' /J5+ ,--)-`-,r-)r. 1civ �rtvlv; ttr tlSt fo 2 .---co .75 . / b.. -ey _ �✓h o � p C 0 G �r„� fs'11- ee)p.v fh t rap ro if of" Qv�n✓ r J Spacing Exception Required? Yes 0 No [r/� Subsequent Form Required: /G - 4 �7 [/n APPROVED BY Q Approved by:12g COMMISSIONER THE COMMISSION Date:s'8/S-' Vrt._ 519/15-Approved application is valid tor 12 monthstrm the date of approval. Form 10-403(Revised 10/2012) oRIGINAL so IfSubmit Form and ttachments in Duplicate 57C,5RBDMSaMAY 1 1 2015 • ✓ RECEIVED ConocoPhiIIups MAY 0 6 2015 Alaska P.O.BOX 100360 A V G V V ANCHORAGE,ALASKA 99510-0360 �+ V V May 5,2015 Cathy Forester State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby submits an Application for Sundry Approval to workover Kuparuk Producer KRU 2T-07(PTD# 186-108). Well KRU 2T-07 was drilled and completed as Kuparuk A-& C-sand selective producer in 1986. The A-sand was fracture stimulated in 1988 with primary production since being from the A-sand along with intermittent C-sand production from 1988-1995. In March 1995 IA x OA communication was observed and the inner casing pack-offs were plastic-packed to mitigate. In 2000 an OA leak was observed and LLR logging determined the leak to be at 350'MD—subsequent repair attempts have been unsuccessful. In 2002 the inner casing pack-offs failed to test and because of the plastic packing,remedial work has been unsuccessful. Significant subsidence was first observed starting in the early 2000s. In 2010, the A- sand perforations were plugged back with cement in order to prepare the well for a slot recovery program. After the cement was pumped, slickline was unable to drift(1.15")the tubing to tag-up on the estimated TOC at 6555' MD; however,a MIT-T did pass. In 2013,subsequent MIT-Ts failed and the subsidence had worsened to the point that the slickline is unable to drift the tubing past—350'MD with a 1"custom split shot. The proposed workover will complete plug&suspension operations to surface. After rigging up on the well,the 2- 7/8"tubing will be pulled to neutral weight to regain wireline access. After tagging the top of the A-sand cement plug within the tubing,holes will be punched in the tubing below the production packer, and the C-sand perforations will be plugged via a cement squeeze. After pressure testing&confirming the top of the C-sand cement plug,holes will be punched in the tubing above the production packer and a balanced cement plug will be set to 1800' MD. After confirming top of cement of the balanced plug in the tubing, the 2-7/8" tubing will be cut at 1750' MD and holes will be punched in the 7"production casing at—1700'MD. After setting a cement retainer at—250'MD,cement will be squeezed beneath the retainer,through the 7"production casing holes and up the OA to surface. Once good cement is observed at surface,the IA will be shut-in and the surface casing leak will be squeezed. Cement will then be laid in on top of the retainer to surface. After confirming cement to surface in all annuli,a dry hole tree will be rigged up. This Sundry is intended to document the proposed work on KRU 2T-07 because of the intent to re-enter a suspended well,to plug perforations,cut tubing,alter casing,suspend the well,as well as to request approval to continue plug& suspension operations on this well. If you have any questions or require any further information, please call me at 265-6048 or email danny.kane@conocophillips.com. Sincerely, Danny Kane Wells Engineer CPAI Drilling and Wells • KRU 2T-07 Rig Workover Plug & Suspend (PTD #:186-108) Current Status: KRU 2T-07 is currently shut-in&considered suspended by the AOGCC. The A-sand perforations were plugged on 16-Dec-2010 with an estimated top of cement at 6555'MD inside the tubing. While unable to drift the 2-7/8" tubing with a 1.15"swage and tag-up on the top of the plug,a successful MIT-T was performed on 19-Dec-2010 to 2000psi/30min;subsequent MIT-T tests taken in 2013 have failed. The tubing restriction has continued to worsen and wireline is unable to drift the tubing past—356'MD even with a custom 1.00"split shot. Scope of Work: Complete plug& suspension work to surface. After gaining access to the tubing,tag TOC for A-sand perforations plug(estimated 6555'MD),and punch tubing in the first full joint below the Brown HB-1 production packer at 6076' MD. Establish injectivity into the C-sand perforations and plug C-sand perforations by squeezing with Class G cement. Wait on cement,pressure test,&tag TOC within the tubing. Punch holes in tubing above tagged TOC and spot balanced Class G cement plug in tubing&IA to 1800' MD. Wait on cement,pressure test,&tag TOC within the tubing. Cut 2-7/8"tubing at—1750'MD and pull&lay down same. Perform CBL to confirm top of OA cement (estimated 1784'MD),punch holes in production casing at—1700'MD(or shallower if determined by CBL analysis), and displace the Arctic Pack in OA to surface. Set cement retainer at 250' MD on tubing and cement 7"production casing x OA to surface via perforations with Arctic Set I; once good cement is returning at surface, shut in OA & squeeze cement through 9-5/8" surface casing leak at —350' MD. Un-sting from retainer & lay-in cement above retainer to surface. Confirm TOC&install dry-hole tree. General Well Info: Well Type: Producer MPSP: 2,120 psi using MASP=(PP-(0.1*TVD)),assuming dry gas gradient to surface. Reservoir Pressure/TVD: Kuparuk C—2,500 psi/5,776' TVD(8.4 ppg EMW) Kuparuk A—2,700 psi/5,808' TVD(9.0 ppg EMW) Wellhead Type/Pressure Rating: CIW Gen IV(5M Tubing Head/3M Casing Head) BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT results: MIT-T Failed 02-May-2013 Last Passed 19-Dec-2010 MIT-OA Failed 01-Nov-2003 Leak Identified at—350'RKB Earliest Estimated Start Date: 20-May-2015 Production Engineer: Tommy Nenahlo Workover Engineer: Danny Kane (907)265-6048 danny.kane@conocophillips.com Summary Procedure: Pre-Rig Work 1. Measure T,IA,&OA fluid levels. 2. Set BPV. Rig Workover 1. MIRU RWO Rig 2. Pull BPV. Reverse circulate KWF. Obtain SITP&SICP;if pressure is observed at surface,calculate new KWF and displace as necessary. Verify well is dead prior to proceeding. 3. Set BPV&blanking plug,ND tree,NU BOPE&test to 250/2500psi low/high. 4. Pull blanking plug&BPV,screw in landing joint,BOLDS,unseat tubing hanger. 5. PU on tubing to neutral weight(remove compression). NOTE:Do not pull tubing from PBR seals. KRU 2T-07 Rig Workover Plug & Suspend (PTD #:186-108) 6. RU wireline to drift tubing,tag A-sand TOC,and to punch holes in the tubing below the Brown HB-1 packer. a. Drift tubing&tag TOC of A-sand cement plug. (Estimated at—6,555 MD) b. Punch holes in first full joint of tubing beneath Brown HB-1 packer(6076'MD)to provide a circulation path to straddled C-sand. c. RD wireline. 7. RU cementers to plug C-sand perforations.(Estimated Class G Volume—4O.7bbls) a. Perform injectivity test into straddled C-sands beneath HB-1 packer. b. Squeeze cement down tubing&into C-sand perforations,plan job to place TOC at HB-1 packer. c. RD cementers. 8. WOC as per planned slurry&surface sample. 9. Pressure-test cement in tubing to 1500psi/lOmin. , 4-. fQ p r 10. RU wireline to tag TOC&cut tubing. _ /✓a�i 1 C fv w i a. Tag up on C-sand cement plug in the tubing. b. Punch holes in first full joint of tubing above the Brown HB-1 packer(6076'MD)to provide a circulation path above the production packer from the tubing to the IA. i. If TOC is tagged above the packer,punch holes in first full joint of tubing above tagged TOC. c. RD wireline. 11. Establish T x IA circulation&displace to KWF. 12. RU cementers to set balanced plug in T x IA. (Estimated Class G Volume—154bbls) a. Plan top of balanced plug to be at 1800'MD in the T&IA. b. RD cementers. 13. WOC as per planned slurry&surface sample. 14. Pressure-test cement in T&IA to 1500psi/lOmin. -- 15. RU wireline to tag TOC&cut tubing. a. Tag up on balanced plug in the tubing. b. Cut tubing in first full joint of tubing at—1750' MD above the SSSV(1786'MD). i. If TOC is above the SSSV,punch holes in the first full joint of tubing above tagged TOC. c. RD wireline. 16. Pull 2-7/8"tubing,laying down at surface. 17. RU wireline to confirm OA TOC and to punch holes in 7"production casing. a. Run CBL to confirm TOC in the OA. (Estimated OA TOC 1784'MD) b. Punch holes in 7"production casing at—1700'MD,adjusting as needed by measured TOC. c. RD wireline. 18. Displace Arctic Pack with KWF by taking returns up the OA. 19. RIH w/cement retainer on tubing,set at 250'MD,&pressure test running string x 7"production casing annulus to 500psi/lOmin. 20. RU cementers to cement IA & OA to 7" production casing perforations and to squeeze surface casing leak. (Estimated Arctic Set I volume—155bbls) a. Pump cement beneath retainer,through 7"production casing perforations at—1700'MD,&back-up OA. b. Once good cement returns are at surface, shut-in OA& squeeze—39bbls of cement through the 9-5/8" surface casing leak at—350'MD. c. Un-sting running tool from retainer&LD same. d. Lay in cement on top of cement retainer to surface. e. RD cementers. 21. WOC as per planned slurry&surface sample. KRU 2T-07 Rig Workover Plug & Suspend (PTD #:186-108) 22. Confirm that cement is to surface in the IA&OA. / ti A-O Cz n l5 5 . a. If cement is not within 5' MD of surface,measure void depth to determine volume,&perform surface cement job. b. Document cement to surface with pictures. 23. ND BOPE. 24. NU dry-hole tree. 25. RDMO RWO Rig. Post-Rig Work 1. Turn suspended well over to Well Integrity. ' • ' KUP 2T-07 ConocoPhillips fill Well Attributes Max Angle&MD TD IncWellbore APlnUWI Field Name Well Status Incl(') MD(RKB) Act Btm(RKB) Alaska, 501032006900 KUPARUK RIVER UNIT PROD 49.68 5,400.00 6,975.0 '- Comment H2S(ppm) Date Annotation End Date KBGrd(R) Rig Release Date "' SSSV:LOCKED OUT 40 1/11/2009 Last WO: 40.00 8/28/1986 Well Contin:•2T-07,1/31/201210:07:31 AM Schematic-Actual Annotation 1 1 Depth(MB) End Date Annotation Last Mod...End Date P Last Tag: 6,573.0 2/7/2004 Rev Reason:WELL REVIEW osborl 1/31/2012 Casing Strings HANGER,26 ` II ' Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd " CONDUCTOR 16 15.062 33.0 110.0 110.0 62.50 H-40 WELDED ' Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd V SURFACE 95/8 8.765 33.0 2,772.5 2,772.4 36.00 J-55 BUTT 491 / Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd PRODUCTION 7 6.276 30.1 6,448.6 5,724.2 26.00 J-55 BTC Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd LINER 5 4.151 6,228.5 6,975.0 6,087.1 18.00 S-140 LTC Liner Details CONDUCTOR, Top Depth 33-110 (TVD) Top Incl Remi... I.o 1 Top IRKS) (RKB) (°) hem Description Comment ID(in) SAFETY VLV, 1,778686 6,228.5 5,574.5 47.49 HANGER BAKER LINER HANGER 5.000 III Tubing Strings GAS LIFT, Tubing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd Z5t2 ._ TUBING 27/8 2.441 28.3 6,565.9 5,804.9 6.50 J-55 EUE8rdABMOD ---- 2.875"x2.375" Completion Details Top Depth (ND) Top Incl Nonni... SURl Top(RKB) (RKB) F) Item Description Comment ID(In) FACE,_ 28.3 28.3 0.11 HANGER CIW TUBING HANGER 2.441 2' 1,785.6 1,785.5 0.25 SAFETY VLV CAMCO TRDP-1A-SSA(LOCKED OUT 9/3/1993) 2.312 GAS LIFT, - IWe 6,056.8 5,459.4 48.16 PBR BROWN PBR 2.500 4,090 -- 6,076.0 5,472.31 48.111 PACKER 1BROWN HE-1 PACKER 2.750 GAS LIFT. f 6,135.6 5,512.1 47.96 SLEEVE-C OTIS XA SLIDING SLEEVE(CLOSED 4/2/1995) 2.310 4,95716,154.5 5,524.8 47.91 NIPPLE CAMCO D NIPPLE 2.250 GA6LIFT,__. - 6,156.4 5,526.0 47.91 XO redudng XO redudng 2.875x2.375,4.708,N-80,1.995 2.375 5,379 6,512.0 5,767.8 46.53 BLAST RING CARBIDE BLAST RING 1.995 ___ 6,550.0 5,793.9 46.54 LOCATOR BAKER LOCATOR 1.995 GAS 5,697 LIFT - 6,551.0 5,794.6 46.54 PACKER BAKER DB PACKER w5'SEAL BORE EXT. 3.250 6,563.0 5,802.9 46.54 NIPPLE CAMCO D NIPPLE NO GO 1.812 GAS LIFT, 6,565.3 5,804.51 46.541SOS CAMCO SHEAR OUT 1 1.995 6,016 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) --1 Top Depth PBR.6,057 ( (ND) Top Incl PACKER,6,076 Milift Top OMB) (RKB) C) Description Comment Run Date ID(In) .. in. 6,555.0 5,797.4 46.54 CMT PLUG Pumped 15 bbls of 15.8 ppg Class G cement slurry 12/16/2010 0.000 GAS UFT. Perforations&Slots 6,114 - Shot Top(ND) Btm(TVD) Dens } �I Top(RKB)Btm(RKB) (RKB) (RKB) Zone Date (oh... Type Comment SLEEVE-C, - }1.11 6,524.0 6,539.0 5,776.1 5,786.4 C-4,Unit B, 10/30/1986 12.0 IPERF 3 3/8"HyperJet II;60 deg.Ph 6,136 - 2T-07 6,571.0 6,613.0 5,808.4 5,837.2 A-3,2T-07 10/30/1986 12.0 IPERF 3 3/8"HyperJet II;60 deg.Ph NIPPLE,6,155 �Q IF Notes:General&Safety End Date Annotation 2/72004 NOTE:HEAVY,ERRATIC PICKUP WEIGHTS SUGGEST CORKSCREW TBG FROM TTL-500' 31 IL 11/30/2010 NOTE VIEW SCHEMATIC w/Alaska Schematic9.0 PRODUCTION, * p A 30-6,449 6.524.6,539 IPERF, LOCATO 6,5R, 50 1- 1 PACKER,6,551 f 1 I NIPPLE,6,563 II Mandrel Details Top Depth Top Port SOS,5,565 is. (ND) Incl OD Valve Latch Sloe TRO Run Stn Top(MB) (RKB) F) Make Model (in) Sery Type Type (in) (psi) Run Date Corn... CMT PLUG, - 6555 1 2,582.2 2,582.1 0.30 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,336.0 10/30/2004 IPERF, ,6,5714613 2 4,090.0 4,015.0.31.48 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,334.0 10502004 Plug. 3 4,956.9 4,718.6 37.88 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 10/31/1986- Cement 6.555 4 5,318.6 4,977.0 49.92 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,327.0 10/302004 5 5,697.2 5,223.049.53 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 10/31/1986 6 6,016.0 5,432.3 48.26 MMH HTC 1 12 GAS LIFT OV RK 0250 0.0 3/4/2006 J 7 6,113.6 5,497.4 48.02 CAMCO KBMG 1 PROD DMY BK 0.000 0.0 10/31/1986,Closed LINER, 6,228-6,975 TD,6,975 �-' KRU 2T-07 ConocoPhillips Suspended Producer Proposed Schematic 110'MD,16"62.5#,H-40 ►' 350'MD,9-5/8"Casing Leak Primary Surface Casing : is iCement Retainer-250'MD Cement, 18bbl Top Job —PI'i:i: • :. •.! Punch Holes 7"Casing-1700'MD Cut 2-7/8"Tubing-1750'MD `—►RI . :::! • -1785'MD,Camco TRDP-1A SSA Top Arctic Set l-1784'MD ►:;i; :. ;.�-1-2582'MD,Camco KBMG GLV-BK 2772'MD,9-5/8"36#,J-55 — . __:i 4090'MD,Camco KBMG GLV-BK 2-7/8"6.5#,J-55 Tubing -i f-4956'MD,Camco KBMG DMY-BK Drilling Mud(Existing) ::cement(Existing)::::::: Arctic Pack(Existing) Completion Brine(Existing) is 5318'MD,Camco KBMG GLV-BK Proposed Brine KWF iiiiiiiiiii,iiiiiiiii6?iiIiii;:;:;'i iii lig, :i,t :: 5697'MD,Camco KBMG DMY-BK ,ar --6016'MD,MMH HTC OV-RK Punch Holes 2-7/8"Tubing H►;,,: f-6056'MD,Brown PBR 7r •• . ' 6076'MD,Brown HB-1 Packer t. Punch Holes 2-7/8"Tubing ;'-Il• 101.11i•i 6113'MD,Camco KBMG DMY-BK _;j,1 6136'MD,OTIS XA Sliding Sleeve }: id ,i 6155'MD,2.250"Camco D Nipple 2-7/8"x 2-3/8"Crossover ► :11 6228'MD,Baker Mod'A'Liner Hanger 6448'MD,7"26#,J-55 - 4 . 2-%"4.7#J-55 Tubing M 6524'-6539'MD,C Perforations L - 6551'MD,Baker DB Packer w/5'SBE ira 6563'MD,1.812"Camco D Nipple • I 1 *I 6565'MD,Camco Shear-Out Sub 6571'-6613'MD,A Perforations (Cement Plugged in 2010) 6975'MD,5"18#,S-140 Ixa' Data: e5-May-2015 1 Drawn By: Danny Kane Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct ins pection of the file. _-/l~ll- _/_..O_~ Well History File Identifier Organization (done) ~Two-Sided RESCAN DIGITAL DATA [] Color items: [] Diskettes, No. [] Grayscale items: [] Other, No/Type [] Poor Quality Originals: ~ Other: ~::)..~~ TOTAL PAGES: ~[/~ NOTES: ORGANIZED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: OVERSIZED (Scannable) D Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) Logs of various kinds [] Other lei Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ PAGES:/'~/~f (at the time of scanning) SCANNED BY; BEVERLY BRE~HERYL MARIA LOWELL DATE: RESCANNED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl General Notes or Comments about this file: PAGES :/y'~ Quality Checked [done) • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 09/10/11 Inspector: - Bob Noble Operator: CPA Well Name: KRU 2T -07 Oper. Rep: Martin Walters PTD No.: 186 -108 Oper. Phone: 659 -7043 Location Verified? Yes Oper. Email: If Verified, How? Other (specify in comments) Onshore / Offshore: Onshore Suspension Date: 12/19/10 Date AOGCC Notified: 09/09/11 Sundry No.: 310 -413 Type of Inspection: Initial Wellbore Diagram Avail.? Yes Well Pressures (psi): Tubing 460 Photos Taken? Yes IA 300 " OA 120 Condition of Wellhead: Wellhead looked to be in good working condition, The flow line and A/L lines were still attached. There was a blind in the A/L line with 1300 psi upstream. The flowline was not blinded. Condition of Surrounding Surface The pad looked to be good clean gravel. The cellar box was dry. The wellhead was protected with a well house. — Location: The location was verified with the use of a plot plan. Follow Up Actions None Needed: ' r I t Attachments: Photos (2) REVIEWED BY: Well Schematic - Insp. Supry J � )0 1 7 (1/ KRU 2T Pad Layout - Comm PLB 08/2010 2011- 0910_Suspend_KRU_2T- 07_bn.xls Suspended Well Inspection - KRU 2T -07 PTD 1861080 Photos by AOGCC Inspector B. Noble 9/10/2011 111111 111! ■ ja .; _ � et r t ii ' x .. , , ...,,. ,,,,, ' lr.. : � `. �, s III ■ ■ _mss— — ,4.4t.. • • KUP 2T -07 C nocoPhillips� ' !.' 4 e11 4ttr96at s ,I�!J G ''lud" : 1 °.,pillp . , I �.o T . c �° .,, Virg " i;,,4 o'& 0 I1r »a iI 16 iVaska Inc. Weltbnn OirWe lad Naee Wen Status' Incl (') 110 6 B) Act 10 KB) �� r_ 501032006900 KUPARUK RIVER UNIT PROD 49.68 5,40000 6,975.0 ■ "' ea ., t t _ - SSSV:LOCKE000T ) 1Nts (40) Da 1/1 1/ 2069 ! Le st=: IEnd Date ..._ KB- D 40n00 RigRelea e n . . . s Mnotaeon Depth (l1K8 End Date Annotation Last Mod... End Daft { Last T.. .y 6,573.0 2/7)2004 Re.: Reason.' CEMENT PLUG !masher 12125/20)0 -.. , Y .° ,M tasin1) strtMCTSlSrWr�11 P i ':31 � . � �, - ., y .. , .._. ., i ; NAUOER,3a w1/ 1p: caning Description String a_ String iD _. rop DVS) ac[ wpm (r.. sei Depth (rv0)_, String v1/. strtrg.- String Top Thad CONDUCTOR 16 15.062 33. 110.0 110.0 62 H-40 WELDED � " Casing °est/lotion String O_ String ICI _. Top MRS) Set Depth (f_ Set Depth(TVO) ... String Wt. . String l... String Top Thrd SURFACE 95/8 8.765 330 2,772.5 2,772.4 36.00 }55 BUTT Casing Description String O.. String 10 ... Top (Mg) Set Depth (!.-. Se/ Depth (IVO) .. String Wt_. Stang ... String Top Thrd 7.. ..a, . Ct , � s .. .i PRODUCTION 7 6.151 30.1 6,448.6 5,724.2 26.00 .655 BTC • Casing Description String 0... Sirfag 10... Top MKS) Sat Depth (1- Set Depth 4WD) .. String Wt, String., String Top Thrd LINER 5 4151 62285 6,975.0 6,087.1 1800 S -140 _ LTC Liner Dotatis . 411; ^ "` I COhtlt7CTOR -_ Top Depth lbtf0 r (TVD( Top Incl Nand... _ � 1hKgl_ (8708) 1') Item Description Cammxnt ID (in) SAFE WVLV, 6228.5 5,5745 4749I1ANGER OAKER LINER I-ANGER 5 000 TLtbin Strings 048 LIFT. - Tutting Description Siring 4a. String iD Top (BKB) Sot DCplh )t Sx1 gin (7V0)_. tit g V,t_. St l g. S Tap 4hrd 2. `°` '°' TUBING 2 7/8 2.441 283 6,5659 5801.9 6.50 355 �EUE&IAB..00 2.875"x2.375' I I Completion Details Top Depth ( Top Inc! Hoed- Top IttHS) Pike) el itemDescxipl)an Camment 10 On) *101151/15, 263 283 0.11 HANGER CIW TUBING HANGER - TAT 11 -2.rz2 . 1,185.6 1,7855 0.25 SAFETY VLV CAMCO TROP -)A -SSA, ......._ ..... -- -- ...__ 2.312 DAs L*FT, 'r 6,056.8 5,459.4 48.16 PBR - BROWN PBR 2500 NO 5+041 6,076.0 5.472.3 48.11 PACKER BROWN HB-1 PACKER 2.750 OAS OFT, I 6,135.6 5,512.1 47.96 SLEEVE -C OT1S XA SLIDING SLEEVE (CLOSED 4/2/1995) 2310 4S<77 -�-- 6,154.5 5,524.8 47.97 NIPPLE CAMCDDNIPPLE 2250 in LIPr, 6,156.4 5,526.0 47.91XOreducing XOrerhrtilTy13 .875x2.375.4.701),N$O.i.995 2.37E OAS sllg 1 -r 6,51 5,767.8 46.53 BLAST RING CARBIDE BLAST RING 1.995 6,550.01 5,793.9 46.54 LOCATOR • BAKER LOCATOR 1.995 ws LifT, _.__ -- 5.N7 6,551.0 5,794.6 46. PACKER BAKER D8 PACKER w5' SEAL BORE EXT. 3.250 IN 6,563.0 5,802.9 46.54 NIPPLE CAMCO 0 NIPPLE NO GO -..- 1,812 OAS 101, . , 6,565.3 5,804.5 4554 SOS CAMCO SHEAR OUT 1.095 6.018 . Perforations & Slots 5811, 8.057 Shot Top(TVO) Btm(TVD) Dena PACKER 8.078 T• • 0/(13 BDn IIKB (MRS) MD) Zone Date (sh• -- Comment - 6.52 •.0 6,539.0 5,706.1 illi C-4, rut B. 1000/1986 �® t HyperJel (1: 60 deg Ph IL 21-07 base 4 .371.0 6,613. 5,808. 5837.2 -3, 27-07 10130/1 12.0 IPERF 3 318" H ype Jet ii; 60 deg Ph Notes: General & Safety . E1EEVE -C. � End Date Annolanon 6,13* 2172004 INOTE: HEAVY, ERRATIC PICKUP WEIGHTS SUGGEST CORKSCREW TBG FROM TTL -500' all 1150/2010 NOTE: VIEW SCHEMATIC Yr/AlaskaSchernatic9.0 10PP1.E,8.155 I r. PRODUCTION, Aa - A 3}6440 • 1 1p 6.5245.SJ8 -_ - . ■ L n LOLAOTDA, 3 l PAcelle 15557 , + -1 li PPLE 6543 Iiire to ti v Top Depth Top Port 805.5,565 ` 1 (TVD) 1nel OD Yarn Latch Size TRO Ron Stn IopMKS) il 1') Make Model 1k4 Sent Type Type 0 (pall Run Date Corn... 1 2,5822 2,582.1 530 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,336.0 10/302001 8,571 4.8 7PER f. 2 4,090.0 4.015.0 31.48 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,334.0 100302004 t9 ce n a wag. 3 4,956.9 4,718.8 37.88 CAMCO KBMG 1 OAS LIFT DAY BK 0.000 0.0 10/31/1986 *1•856 4 5,318.6. 4,977.0 49.92 CAMCO 813M0 1 GAS UFT GLV BK 07 : • 1,327.0 1030/2004 5 5697.2 5,223.0 49.53 CAMCO KBMG 1 GAS LIPT DMY BK 0.000 0.0 10/31/1986 6 6,016:0 5,432.3 48.26 MMH HTC 1 1/2 GAS LIFT OV RK 0.250 0.0 3/412036 7 6,113-6 5,497.4 48.02 CAMCO KBMG 1 PROD DMY BK 0.000 0.0 1031/1986 Closed LINER, 6.2284.87 TD, 6,676 5 f7 * ` .1.1ffillitt." ....... li.. —", ... , t t NOTE l . NO SNOW IS TO BE PLACED IN I ANY RESERVE PIT OR LINED PIT, t t GUARD RADS \ t' 7. PAM 2A MA ,; RESERVE PIT .. I 11 Plc i TAW PIPELINES PIT — 0 . I Paw I I I lIT or r .,......, a 4,.., I mut ‘ I = 1 PLIF ' 4 *zrs i 4$ V A fa r . . I MOPIO r • I I L6 __,.......— . . I A70 al . , 5. I iSt =I ■••••• ...• ht 21 191' Ill . tit', 9 8 7 6 5 4 3 2 23g 26 28 30 32eg „ , „ 131 1 .'.:1 - , . [! .... (,,, T o .., „......, zi G it, AS a /7_ laza 0,,*: e ..ii:n lattaarawaraanDma 74 co 20 18 a 9 22 27 29 31 RI? TO os2A 4--25.-125125 , as-1.32si-sts-adzsAns I " - A 2 SPACES j 12 SPACES 12 SPACES 4 L 1 SPACES 6 015' 1 SPACES i '6 ,:- 0 12.5 0 1.2S 0125 015' 0 WS [ 2 1 1 ■= WP 1.**; 5 SPACES- p, AK it Me egeregell I EMM .4 I 6 Me el eleArm eft I drarelerl arA I re FEATURE LOCATION LEGEND CAUTION 0 EXISTING PRODUCER I I LEGEND AP. EXISTING INJECTOR THIS DRILL SITE IS a CONVERTED PROM - CLEAN SNOW DUMP AREA. AU. EQUIPMENT. 1Z RESCUE EQUIPMENT PRODUCER TO INJECTOR 1 e CONSIDERED TO BE ... ..... . . . - ENVIRONMENTAL AREA-NO SNOW DUMPING. * SCBA LOCATIONS AN H AREA r ABANDONED CONDUCTOR i • DESIGNATED SAFE AREA (PRImARY) X EXISTING CONDUCTOR , % I5 - POWERLINE-WATCH CLEARANCED. KODIAK ■: BLOWERS MAY HIT LINES WITH DISCHARGE. ,...Q.,..: DESIGNATED SAFE AREA (SECONDARY) E PARTIAL TREE - KODIAK BLOWERS MAY DISCHARGE OVER EVACUATION ROUTES DEPENDING ON WIND PIPELINES. i l' .7.'1 - NO SNOW DUMPING AREA. r ' WINDSOCK BARRICADE/ESCAPE ROUTE .... 1 AREA: 2T MODULE: XXXX UNIT: D2 .; A LOUNSBURY, INC ...,..- FIRE EXTINGUISHER APPROVAL'. , . . 5 5/01/02 Add NI 39, Rev Per K02013ACS ?ART SCT iDAZ 11/26/99 CAM 11/26/99 4 15/30/01 Add Wells, Update Title 81k, Rev Per KOIONACS ROL WIRT I DRAWING NO. SHEET: REV: t . - GATE REVISIONS BT ... ., .. ...„ _ ..... ... . , „ • • y J/y • • ConocoPh l l i ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 September 10, 2011 SEP 1 4 21th Alaska ®ii & Gas Pont n i'�►'•�d Commissioner Dan Seamount star. Alaska Oil and Gas Conservation Commission I. 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Re: Suspended Well Inspection 10 -404 Sundry Kuparuk River Unit 2T -07 (PTD 186 -108) Dear Commissioner Seamount: Enclosed please find the quinquennial suspended well inspection documentation as required by 20 AAC 25.110 for ConocoPhillips Alaska, Inc. Kuparuk River Unit well 2T- 07 (PTD 186 -108). The following documents are attached: - 10 -404 Sundry - Suspended Well Check List - Wellbore Schematic - Location Plot Plan .. g q $ - Photographs Please call MJ Loveland or me at 659 -7043 if you have any questions. Sincerely, / 4 / A:Mid Martin Walters ConocoPhillips Well Integrity Projects Supervisor Enclosures . . • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair Rug Perforations St Othe Suspended Well p g r Inspection Alter Casing r Rill Tubing r Perforate New Pool r Waiver r Time Extension r Change Approved Program r Operat. Shutdown r Perforate r Re -enter Suspended Well r- 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development /7 Exploratory r _ ° 186 - 108 3. Address: 6. API Number: Stratigraphic r Service r P. 0. Box 100360, Anchorage, Alaska 99510 50 103 - 20069 - 00 i 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025569 4. 2T -07 9. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 6975 feet Plugs (measured) None true vertical 6087 feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 6076, 6551 true vertical 0 feet (true vertucal) 5472, 5795 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 110 110 SURFACE 2739 9 -5/8 2772 2772 PRODUCTION 6419 7 6449 5724 C s'44`) See Perforation depth: Measured depth: 6524 -6539, 6571 -661 �., j P RECEIVED True Vertical Depth: 5776-5786, 5808-5837 K 9 1. -2- " 1 t SEP 1 4 2011 Tubing (size, grade, MD, and TVD) 2.875, N -80, 6156 MD, 5526 TVD / 8 Oil & t3 3 Cons. Commission 2.375, N -80, 6565 MD, 5804 TVD Anchorage Packers & SSSV (type, MD, and TVD) PACKER - BROWN HB -1 PACKER @ 6076 MD and 5472 TVD PACKER - BAKER DB PACKER W5' SEAL BORE EXT. @ 6551 MD and 5795 TVD SSSV - CAMCO TRDP -IA -SSA @ 1786 MD and 1786 ND 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r : Service r Stratigraphic r 15. Well Status after work: Oil r Gas r VVDSPL r Daily Report of Well Operations X GSTOR r VVINJ r® WAG r GINJ r SUSP r+i, SPLUG r 16. 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: N/A Contact MJ Loveland /Martin Walters Printed Name Martin Walters Title: Well Integrity Project Supervisor Signature Phone: 907 - 659 -7043 Date: 09 -10 -11 RBDMS SEP 14 201A,, l -,. ,c/ r / Form 10-404 Revised 10/2010 Subm i Original Only Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: Kuparuk River Unit 2T -07 Field /Pool: Kuparuk River /Kuparuk River Pool Permit # (PTD): 186 -108 Sundry 310 -413 API Number: 50103200690000 Operator: ConocoPhillips Date Suspended: 12/16/2010 Surface Location: Section: 277' FSL, 556' FWL, Sec 1 Twsp: T11 N Range: R8E UM Nearest active pad or road: KRU DS2T Take to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Good Pad or location surface: Good. Gravel Pad Location cleanup needed: No Pits condition: N/A Surrounding area condition: Good Water /fluids on pad: Rain water on pad Discoloration, Sheens on pad, pits or water: No sheen Samples taken: None Access road condition: Good Photographs taken (# and description): None Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition • Wellhead /tree /valve description, condition: Good. Cycled SSV, SV, MV, IA valve, and OA valve. SSV was open. Closed SSV Cellar description, condition, fluids: 6X6 wooden cellar box. Dry Rat Hole: No Wellhouse or protective barriers: Wellhouse with fiberglass floor Well identification sign: Stenciled on wellhead and wellhouse Tubing Pressure (or casing if no tubing): 460 psi. Flowlline not blinded Annulus pressures: IA = 30 psi, OA = 120 psi. AL line has spec blind with 1300 psi Wellhead Photos taken (# and description): 2 of wellhead and cellar Work Required: None Operator Rep (name and signature): Martin Walters _Ea /= AOGCC Inspector: Bob Noble Other Observers: Mouser /Bybee /Greenwood Inspection Date: 9/10/2011 AOGCC Notice Date: 9/1/2011 Time of arrival: Time of Departure: Site access method: Highway Vehicle �, • KUP • 2T -07 ConocoPhillips pi. Well Attributes Max Angle & MD TD • Alaslea, hl:; Wellbore API /UWI Field Name Well Status Intl (') MD (HKB) Act Btm (51K13) Cmoml'tVlkq 501032006900 KUPARUK RIVER UNIT PROD 49.68 5,400.00 6,975.0 Comment H2S (ppm) Date Annotation End Date KB-Ord (ft) Rig Release Date ••• SSSV: LOCKED OUT 40 1/11/2009 Last WO: 40.00 8/28/1986 Well Conan' - 2T -07 1/212011 9:51 05 AM Schematic - Actual Annotation Depth (MB) End Date Annotation Last Mod ... End Date Last Tag- 6,573.0 2x7/2004 Rev Reason: CEMENT PLUG Imosbor 12/25/2010 Casing Strings HANGER. 28 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 33.0 110.0 110.0 62.50 H-40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.765 33.0 2,772.5 2,772.4 36.00 J-55 BUTT Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd , / - PRODUCTION 7 6. 151 3 6,448.6 5,724.2 26.00 J -55 BTC Casing Descriptl String 0... Strin ID ... To (15)68) Set Dep th (6... set Depth (TVD) ... String Wt... String ... String Top Thrd LINER 5 4.151 6,228.5 6,975.0 6,087 18.00 S -140 LTC Liner Details CONDUCTOR, Top Depth 33 -110 (TVD) Top Inc! Nomi... Top (HKB) (ftKB) ( °) Item Description Comment ID (in) SAFETY VLV. 6,228.5 5,574.5 47.49 HANGER BAKER LINER HANGER 5.000 1,786 II Tubing Strings GAS LIFT, Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd 2.582 TUBING 27/8 2.441 28.3 6,565.9 5,804.9 6.50 J -55 EUE8rdABMOD s 2.875"x2.375" Completion Details Top Depth (TVD) Top Inc! Nemi... Top (ftKB) (ftKB) ( °) Item Description Comment ID (In) SURFACE, 28.3 28.3 0.11 HANGER CIW TUBING HANGER 2.441 33 -2,772 ....; 1,785.6 1,785.5 0.25 SAFETY VLV CAMCO TRDP -1ASSA 2.312 GAS LIFT, 6,056.8 5,459.4 48.16 PBR BROWN PBR 2.500 4,090 6.076.0 5,472.3 48.11 PACKER BROWN HB-1 PACKER 2.750 GAS LIFT,. 6,135.6 5,512.1 47.96 SLEEVE -C OTIS XA SLIDING SLEEVE (CLOSED 4/2/1995) 2.310 E=4 4.957 6,154.5 5,524.8 47.91 NIPPLE CAMCODNIPPLE 2.250 GAS LIFT, 6,156.4 5,526.0 47.91 XO reducing XO reducing 2.875x2.375, 4.70#, N- 80,1.995 2.375 5.319 _ 6,512.0 5,767,8 46.53 BLAST RING CARBIDE BLAST RING 1.995 6,550.0 5,793.9 46.54 LOCATOR BAKER LOCATOR 1.995 GAS 5,897 6,551.0 5,794.6 46.54 PACKER BAKER DB PACKER w5' SEAL BORE EXT. 3.250 6,563.0 5,802.9 46.54 NIPPLE CAMCO D NIPPLE NO GO 1.812 GAS 6,565.3 5,804.5 46.54 SOS CAMCO SHEAR OUT 1.995 8.018 .016 Perforations & Slots Shot PER 8,057 Top (TVD) Btm (TVD) Dens PACKER, 8.078 1111111111. Top (MB) Btm (ftKB) (1t108) (MB) Zone Date (sh ... Type Comment III 6,524.0 6,539.0 5,776.1 5,786.4 C - 4, Unit B, 2T - 07 10/30/1986 12.0 IPERF 33/8" HyperJet II; 60 deg. Ph GAS e1 4 6,571.0 6,613.0 5,808.4 5,837.2 A -3, 2T -07 10/30/1986 12.0 IPERF 3 3/8" HyperJet II; 60 deg. Ph W Notes: General & Safety EEVE -C, End Date Annotation 613s 7/7/2004 NOTE: HEAVY, ERRATIC PICKUP WEIGHTS SUGGEST CORKSCREW TBG FROM TTL 500' GI 11/30/2010 NOTE: VIEW SCHEMATIC w /Alaska Schema)ic9.0 IPPLE, 6.155 I, I IL PRODUCTION. • • 30 -0,449 IPERF, 1 6,5246,539 LOCATOR, 4 6.550 I 1 PACKER, 6,551 NIPPLE, 6,563 Mandrel Details Top Depth Top Port 505, 6,565 (TVD) Inc! OD Valve Latch 5(06 TRO Run 5m Top(ttKB) (ftKB) (°) Make Model (in) Sery Type Type (In) (poi) Run Date Com... 1 2,582.2 2,582.1 0.30 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,336.0 10/302004 PERF. - 1 6.571 6613 2 4,090.0 4,015.0 31.48 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,334.0 10/302004 Cement Plug, 3 4,956.9 4,718.6 37.88 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 10/31/1986 8.555 4 5,318.6 4,977.0 49.92 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,327.0 10/30/2004 5 5,697.2 5,223.0 49.53 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 10/31/1986 6 6,016.0 5,432.3 48.26 MMH HTC 1 12 GAS LIFT OV RK 0.250 0.0 3/4/2006 7 6,113.6 5,497.4 48.02 CAMCO KBMG 1 PROD DMY BK 0.000 0.0 10/31/1986 Closed LINER. 6.226 -6,975 TD. 6975 • irII�IIIII ICVPJ�r�r�IIl•tl�fl•�iMS"III fr�rri \MI•C II:�II�I•IEMII•��IIIII� !l!: /�IrMr��tl�C UMw - le. }- POWERLINES jier ,A AMIE NOTE A° NO SNOW IS TO BE PLACED IN / ANY RESERVE PIT OR LINED PIT. GUARD RAILS PH0 ' 26 1112 RESERVE PIT PIG 1Ea1E or PIPELINES IT 11. 1 O PROD NM gi UM CCUFLO k E55 Kw A7K !, e Ylp _ r! • mm 1 5• • 21 191' 151511.131 1 15 i ° ' 9 8 7 5 4 3 22326 N N N N N N / rj E7 GRADEBEkus 1 m oo - oa ��A wick) A L OliMUDilliMIIIX Y m 37 20 18 3 38 ® 22 27 29 31 N N N i C71 I TO DS2A 1 - 75 7s 1 213 1 - 48 —d2V 15'0'— �.5 90'�62.5�3 6 2. 5 -- X 37 . 5 ' 1251 r 1 �1 55PACE � 2 9 J I2I1 5 h..' ; S L3 56 ,5' SPACES L3 : 12 1 2 1 • 151' r 55555. ��iiiifiiiiiiiiiiiii��� .�.�ii//iii�iiii/ i FEATURE LOCATION LEGEND CAUTION EXISTING PRODUCER LEGEND — EXISTING INJECTOR i / 4 ,4 - CLEAN SNOW DUMP AREA, ALL EQUIPMENT. ® RESCUE EQUIPMENT THIS DRILL SITE I S CONVERTED ER TO INJECTOR CONSIDERED TO BE 1:•X�� - ENVIRONMENTAL AREA -NO SNOW DUMPING. ° SCBA LOCATIONS AN H AREA 1 ABANDONED CONDUCTOR �iuiil - BLOWERS MAY HIT LINES WITH DISCHARGE. POWERLINE-WATCH CLEARANCE!!, KODIAK 12 I DESIGNATED SAFE AREA (PRIMARY) )&( EXISTING CONDUCTOR BLOWERS I DESIGNATED SAFE AREA (SECONDARY) I ® PARTIAL TREE 1 ` 1j - KODIAK BLOWERS MAY DISCHARGE OVER ROUTES DEPENDING ON WIND PIPELINES. f:: :: •_� - NO SNOW DUMPING AREA. WINDSOCK I= BARRICADE /ESCAPE ROUTE Fii AREA: 2T MODULE:XXXX UNIT: D2 A LOUNSBURY, INC Ark, FIRE EXTINGUISHER APPROVAL: DS2T FACILITY EXPANSION /ft 5 5/01/02 Add Well 39, Rev Per K02013ACS MRT SCT DATE: 11/26/99 CADD FILE: LK622011 FEATURE LOCATION 4 5/30/01 Add Wells, Update Title Blk, Rev Per K01039ACS ROL MRT DRAWING NO. SHEET: REV: REV. COST DATE REVISIONS BY CHK J08 PROD CEA —D2TX -3323 001 5 N0.__App ,� ENGR ENGR • • °- 2T -07 (PTD# 186 -108) . 3 . ?? - r;z. j; s © ConocoPhillips Alaska, Inc. I `; This photo is copyrighted by ConocoPhillips Alaska Inc. and cannot be released or k `' published without express b written consent of �z � r . ConocoPhillips Alaska 7 4' i - - - dig LION r' it . i � � ti t I i , .. ., . _ , , • • • 2T °07 (PTD# 186 °1O8) 44 © ConocoPhillips Alaska, Inc. This photo is copyrighted by ConocoPhillips Alaska, Inc. and cannot be released or �k published without express = written consent of , t o , ConocoPhillips Alaska s i r T a x .� 7 ? 0 n b , ' .. 1 de / ' 4 ...... . 4 ii* / ' ;„ - ,* . * -'''#* , . _, 41 , ..,- , , 4 44 ' .. :,f-.-4.,..,.. r ow , ,,,, :..,,-, N> , „r 0 0 F „ _400 t STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended gi 1 b. Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: December 16, 2010 186 - 108 / 310 - 413 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 July 22, 1986 - 50 103 - 20069 - 00 ©0 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 277' FSL, 556' FWL, Sec 1, T11 N, R8E, UM August 25, 1986 - 2T - 07 Top of Productive Horizon: 8. KB (ft above MSL): 117' RKB 15. Field /Pool(s): 1286' FSL, 1172' FEL, Sec. 2, T11 N, R8E, UM GL (ft above MSL): 41' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 1409' FSL, 1477' FEL, Sec. 2, T11 N, R8E, UM 6555' MD / 5797' TVD Kuparuk River Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 498945 y 5970258 Zone 4 6975' MD / 6087' TVD ADL 25569 TPI: x - 497216 y - 5971266 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 496911 y 5971390 Zone 4 1786' MD / 1786' TVD 2667 18. Directional Survey: Yes ❑ No Q 19. Water Depth, if Offshore: 20. Thickness of Permafrost MDITVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1550' MD / 1550' 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 MDITVD none not applicable 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H -40 Surf. 110' Surf. 110' 24" 245 sx CS II 9.625" 36# J -55 Surf. 2772' Surf. 2772' 12.25" 750 sx AS III, 285 sx Class G 7" 26# J -55 Surf. 6449' Surf. 5724' 8.5" 410 sx Class G, 200 sx AS I 5" 18# S- 140/N -80 6228' 6975' 5574' 6086' 6.125" 125 sx Class G 24. 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) 2.875" / 2.375" 6566' 6076' MD / 5472' TVD perfs squeeze off 6551' MD / 5795' TVD - passe"p ' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. •1/ DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED � -6 �� �"'� 15 bbls of 15.8 ppg Class G - I 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) suspended 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. psi 24 -Hour Rate -> 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No Q Sidewall Cores Acquired? Yes ❑ No 0 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 VOW JAN 3 1 L1311 A , c .4 6 /01 Form 10 -407 Revised 12/2009 RBDMS JAN 2 6 2011 CONTINUED ON REVERSE rg ittgeginal only C /2" 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes 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 1550' 1550' needed, and submit detailed test information per 20 AAC 25.071. Kuparuk C 6521' 5773' Base Kuparuk C 6540' 5786' Top Kuparuk A 6540' 5786' Base Kuparuk A 6738' 5923' N/A Formation at total depth: not applicable 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Dan Herrmann @ 263 - 4619 5�. Printed Na a e Title: Alaska Wells Manager ��� / Signature Phone 265 -6306 Date 1 Sharon Allsup -Drake 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 la: 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 12/2009 2T -07 Well Work Summary DATE JOBTYP SUMMARY 12/16/10 Ann- Pumped fullbore cement plug with 15 -bbl of 15.8 -ppg class G cement slurry followed Comm by 6" foam wiper ball. Displaced cement and wiper with 25 -bbl freshwater and 12- bbl diesel freeze protect. (Ready for PT and SL tag after 13:00 12/17/10). 12/19/10 slickiine ATTEMPT TO TAG CEMENT PLUG. DRIFT TO 1093' SLM: UNABLE TO FALL misc. DEEPER. HOT OIL TO RETURN FOR MIT. COMPLETE. Note: Hot Oil performed drift, tag, 2000 psi MIT -T (Passed) entry in WSR for pressures. etc At KUP 2T -07 C� Well Attributes � Max Angle & MD � TD frlaS1L13. yu ,, x"-2 - Wellborn APUUWI 'Field Name Well Status Incl (°) MD (kKB) Act Bhn (ftKB) _..._. _... txXOfT6xN" 501032006900 KUPARUK RIVER UNI I PROD 1 49.68 5 400.00 6,9 /5 0 Comment H25 (ppm) Dale Annotation End Date KB (ft) Rig Release Date "' SSSV LOCKED OUT i.. 40 1/11/2009 Last WO: 40. 8/28/1986 k n63; 2,1;,.nti �Q11;G5 AM I t _ - -- 1. well . -.. l - _. Stlremetic - AbNal 951 ' Annotation Depth (ftKB) End Date Annotation Last MOd ... I End Last I ag: 6,573 0 2/7/2004 Rev Reason: CEMENT PLUG Imosbor 12/ 010 c - Sp Casing Strings HANGER, 28- 7 ., Casing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (ND) ... I String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 310 110.0 110 0 62.50 H WELDED Casing Description String 0... String ID . Top (336) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd SURFACE 9 5/8 8.765 310 Z772.5 2 772.4 36.00 J -55 BUTT -_ ,� r casing Description String 0... String ID . Top (ftKB) S Depth (f... Set Depth (ND) ... String Wt... String .. String Top Thrd PRODUCTION 7 6.151 30.1 6,4486 5724.2 7 26.00 55 BTC -__ . -_.._ >' Casing Description n String 0... ,String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String String Top Thrd ILINER 5 j 4.151 6,228.5 6,975.0 6,087.1 18.00 S -140 LTC Liner Details CONDUCTOR, Top Depth 33 -110 (TVD) Top Inc! Nomi... Top MKS) (ftKB) P) Item Des tion ... comment ID (in) , � 6 22 - H SAFETYVtv,_ _ f 4 HANGER BAKER LINER HANGER 5.000 1,786 Tubing Strings GAS LIFE Tubin g Description IStrin 0._ . String ID... Top (1138) Set Depth (1... Set Depth (ND) ... String Wt... String 'String Top Thrd 2,582 TUBING 27/8 2.441 28.3 6,565.9 5,804.9 6.50 J-55 EUE8rdABMOD 2.875 "x2.375" r f) Completion Details - Top Depth Nomi... T MKS) Top Item Desolption Comment ID (in) SURFACE,_____ 28.3 28.3 0.11 HANGER CIW TUBING HANGER 2.441 33 - 2,772 1,785.6 1,785.5 0.25� SAFETY VLV CAMCOTRDP - 1A - SSA 2 GAS _ LIFT, - � _. 6,056.8 5,459.4 48. 16 PBR BROWN PBR 2.500 4,090 6,076.0 5,472.3 48.11 PACKER BROWN HB -1 PACKER 2.750 GAS LIFr, _ 6,135.6 5,512 47.96 SLEEVE -C OTIS XA SLIDING SLEEVE (CLOSED 4/2/1995) 2.310 4,957 0 - - - 6,154.5 5,524.8 47.91 NIPPLE CAMCO D NIPPLE 2.250 GAS LIFT, __- u - 6,156.4 5,526.0 47.91 X0 reducing XO reduc ng 2.875x2.375, 4.7011, N- 80,1.995 2.375 5,319 _ 6,512.0 5,767.8 46.53 BLAST RING CARBIDE BLAST RING 1.995 l _ _.... ...� - -- 6,550.0 5,793.9 46.54 LOCATOR BAKER LOCATOR 1.995 GAS LIFT, -- 5,697 6,551.0 5,794.6 46.54 PACKER BAKER DB PACKER w5' SEAL BORE EXT. 3.250 6,563.0 5,802.9 46.54 NIPPLE CAMCO D NIPPLE NO GO 1.812 GAS LIFT, - _ - 6,016 6,565.3 5,804.5 46.54 SOS CAMCO SHEAR OUT 1.995 Perforations & Slots PBR,6,057 t shot _ Top (TVD) Btm (TVD) Dens PACKER, 6,076- Top MKS) Bhn (ftKB) (kKB) (ftKB) Zone Date (sh °- 'type _ Comment 6,524.0 6,539.0 5,776.1 5,786.4 C-4, Unit B, 10/30/1986 12.0 IPERF 3 3/8" HyperJet II; 60 deg. Ph 2T -07 GAS LIFT,_ - 6,114 6,571.0 6,613.0 5,808 4 5,837.21A-3, 2T -07 10130/1986 12.0 IPERF 3 3/8" HyperJet II; 60 deg. Ph ` Nom Gen eral & Safety SLEEVE -C, End Date Annotation 6,136 2/7/2004 NOTE: HEAVY, ERRATIC PICKUP WEIGHTS SUGGEST CORKSCREW TBG FROM TTL- 500' 11/30/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 NIPPLE,6,155 _ __._. _ _. ..... _ - -- -_ 1 PRODUCTION, 30 -6,449 it IPERF, ___ q° 6,524 -6,539 oey it LOCATOR, 6,550 . I1 PACKER, 6,551 - IN. , '': -/ NIPPLE, 6,563 - - - Top Depth Top Port . 50S, 6,565 (TVD) Intl OD Valve Latch Size TRO Run Stn To ,(kKB) r) Make Model (in) Serb TYpe TIM. (in) (psi) Run Date Com... P_( ftKB ) 1 2,582.2 2,582.1 0.30 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,336.0 10/30/2004 IPERF t 6,5715,813 - 2 4,090 0 40 31.48 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,334.0 10/30/2004 , `tom" ,015. 3 4,956.9 4,718.6 37.88 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 10/31/1986 Cement Plug, 6,555 4 5,318.0 4,977.0 CAMCO KBMG GAS LIFT GLV BK 0.188 1,327.0 10/30/2004 5 5,697.2 5,223.0 49.53 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 10/31/1986 6 6,016.0 5,432.3 48.26 MMH HTC 1 1/2 GAS LIFT OV RK 0.250 0.0 3/4/2006 7 6,113.6 5,497.4 48.02 CAMCO KBMG 1 PROD DMY BK 0.000 0.0 10/31/1986 Closed j LINER, L 6,2285,05 \ TD, 6,975 • FE 0 T ALASKA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION C01101ISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Dan Herrmann Wells Engineer ConocoPhillips Alaska, Inc. P.O. P.O. Box 100360 o 0 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2T -07 Sundry Number: 310 -413 Dear Mr. Herrmann: 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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, Daniel T. Seamount, Jr. Chair DATED this i s day of December, 2010. Encl. STATE OF ALASKA ALASOIL AND GAS CONSERVATION COMMISSI* APPLICATION FOR SUNDRY APPROVALSti 1 20 AAC 25.280 1. Type of Request: Abandon Rug for Redrill Perforate New Pool r Repair well r Change Approved Program Suspend Plug Perforations fv j Perforate r Pull Tubing Time Extension Operational Shutdown Re -enter Susp. Well Stimulate After casing Other. I 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development rv Exploratory 186 -108 3. Address: Stratigraphic ] Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20069 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes No `- 2T - 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25569 Kuparuk River Field / Kuparuk River 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): 6975 6087 6897' 6032' Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 110' 110' SURFACE 2739 9 -5/8" 2772' 2772' PRODUCTION 6419 7 6449' 5724' LINER 747 5" 6975' 6086' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6524'- 6539', 6571' -6613' 5776'- 5786', 5808' -5837' 2.875, 2.375 J -55, N -80 6157', 6566' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PKR - BROWN 'HB -1' MD= 6076 TVD= 5472 PKR - BAKER'DB' W/ 5' SEAL BORE EXT. MD= 6551 TVD= 5795 TRDP -IA -SSA MD= 1786 TVD= 1786 12. Attachments: Description Summary of Proposal r', 13. Well Class after proposed work: Detailed Operatio s Program BOP Sketch J` Exploratory > ` Development Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 12/27/2010 Oil r Gas WDSPL i Suspended ry ' 16. Verbal Approval: Date: WINJ r GINJ WAG Abandoned Commission Representative: GSTOR SPLUG 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Dan Herrmann @ 263 -4619 Printed Name He Title: Wells Engineer Signature � f � � . Phone: 263 -4619 Date Q // �Jr Commission nl Sundry Number�l�..U' Conditions of approval: Notify Commission so that a representative may witness 11 PI la�q ntegrit ;��OP Test Mechanical Integrity Test Location Clearance A l f.�. - �- Ply- �.,..�� �{ �o ��,P z� A�4� .s- Other: - ICEIVED Subsequent Form Required: /(). DEC 1 3 2010 , 'Basks Oil & Gas Cons. Commis ion APPROVED BY An orag Approved by COMMISSIONER THE COMMISSION Date: 12 C Form 10 -403 Revised C R `Z /S /o Submit in Dupli ate � 10 i KRU 2T -07 ConocoPh llips Alaska, Inc. 2T -07 _ APL 501032006900 Well T e: PROD Angle TS: 47 deg @ 6521 -- - SSSV SSSV Type: LOCKED OUT Orig Completion. 8/28/1986__ Angle TD: 46 deg 6975 (1786.1787, Annular Fluid: Last W /O: Rev Reason: Comment Note OD:2.875) chan ed for W V 8.1 Reference L Ref Log_Date: _ Last Update: 1/25/2007 Last Tag: 6573 TD:_ 6975 ftKB Gas Lit Last Tag Date: 2 /7/2004 Max Hole Angle: 50 deg @ 5400 MandrellValve Casing String -ALL STRINGS 1 (2582. 2583, OD:4.750) Description Size Top Bottom TVD Wt Grade Thread - _ CONDUCTOR 16.000 0 110 110 6 H-40 Gas Lift PROD CASING_ 9 625_ 0 2772 2772 36.0 J -55 G MandrG Lve PROD- CA SING 7.000 0 6448 _ 5724 26.00 J -55_ 2 (4090 - 4091 LINER 5.000 6228 6975 _ 6975 18.00 S -140 0DA.750) Tubing String -TUBING Size Top _Botto _ TVD _ Wt Grade _Thread _ 2.875 0 ! 6157 5526 6.50 J -55 _ EUE 8RD AB -MOD 2 -375 6157 6566 5805 4.70 N -80 EUE 8RD AB -MOD Perforations Summary Interval TVD Zone Status Ft SPF Date Type Comment Gas Lift - 6524-6539 5776-5786 C- 4,UNIT 15 12 10/30/1986 IPERF 3 318" HyperJet II; 60 deg. MandreVValve �_ -- Ph - -_ 4 (5319.5320, 6571 -6613 5808 - 5837 A -3 42 12 10/30/1986 IPEF 3 3/8" HyperJet II; 60 deg. ODA750) Ph Gas Lift Mandrels /Valves St k 4957 TVD Man Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Mfr Cmnt 1 2 5_82 Cameo KBMG GI 1.0 BK 0.188 1336 10/30/20 2 4015 Cameo KB GLV 1.0 BK 0.188 1334 10/30/20 Gas L tt - - - 3 4719 Cameo KBMG DMY 1.0 BK 0.000 0 10/31/198 Mand/VaKe F ` 4 4977 Camco KBMG GLV 1.0 BK 0.188 1327 10/30/20 6 (60166017, 5 _5223 Cameo KBMG .. DMY 1_0 _BK _ 0.000 _ 0 10/31!198 OD:5.500) 6 6016 5432, MMH HTC OV 1.5 RK 0.250 0 3146006 7cv.1v P Mandrels/Valves PBR — St MD TVD Man Man Type V Mfr V Type V OD Latch Port i TRO Date Run 60576058, Mfr OD:2.875) 7 6114 5498 Camco KBMG DMY 1.0 BK 0.000 0 110/31/1986 Closed Other (plugs, equip., etc. JEWELRY Depth — _ 2 3D PKR TVD Type P 1 12 _' ) Descn tion I - - - - -- (6076-6077 1786 1 786 - SSSV TRDA SSA Locked Out 9/3/9 R DP Pulled_ 3/30/95) OD:6.151) 6057 5460 PBR Brown _ - - 2.500 6076 5472 _PKR Brown HB -1'__ _ 2.750 6136 5512 SLEEVE,C O tis; XA ' SLIDING SLEEVE CLOSED (4/2/95 2.310 6155 5525_ NIP Camco D' Nipple NO GO _ 2 250 6551 5795 PKR Baker 'DB' w/ 5' seal bore ex 3.250 __ 6563 _ 5803 NIP Camco'D' Nipple N GO _ 1.812 6565 5804 _ SOS Camco 1.995 646T&80 TTL 1.995 SLEEVE -C e nerall =rte _ (6136.6137, Date Note_ OD:2.875) -- - -- 2/7/2004 NOTE: HEAVY, ERRATIC PIC WEIGHTS SUGGEST CORKSCREW TBG F ROM T TL_500' NIP - -- - (6155.6156, OD:2.875) Pert _ (6524 -6539) PKR - - (6551 -6552, ODA151) NIP — (6563-6564, OD:2.375) TUBING (6157 -6566, OD:2.375, 0:1.995) _ Perf (6571 -6613) Well 2T -07 Proposed Well Suspension 2T -07 is being evaluated for slot recovery. Currently it has subsidence related ✓ buckling and the last drift was unable to get past -340'. The well needs to be secured by pumping cement across the formation to isolate the productive zones. The C Sand Selective is currently closed with the Sliding sleeve closed and a DV in the production mandrel. The A sand needs to be isolated with cement to help secure the well while the 2T -07 is being evaluated. The cement job being pumped will leave the cement top @ -6555 RKB which will allow the C -Sand to be isolated with cement at a future date. cv� Proposed Well Suspension Procedure: Cementing Unit 1. Mix 15 bbls of 15.8 ppg Class G cement slurry. 2. Pump 15 bbls of 15.8 Class G cement slurry, followed by a nerf ball and displace w/ 25 bbls freshwater & 12 bbls diesel freeze protect Slickline 3. After at least 24 hours pressure test cement plug to 2000 psi then bleed tubing o 0 psi. Record pressures --v /Vof -, � �� �„ ss g p p s c�air 4. D &T to TOC at 6555 RKB with Dummy 1 tubing punch for to determine if the circulation holes can be shot in the C -Sand selective. �s Bts� � 3r ZS oos' ?� r' G 3`l0 12- 37 L F s Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, December 15, 2010 1:12 PM To: 'Herrmann, Daniel D' Subject: RE: 2T -07 Suspend (RTD 186 -?08) Dan, Your explanation below is sufficient... Thanks, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Herrmann, Daniel D [ mailto: ]D.Herrmann @conocophillips.com] Sent: Wednesday, December 15, 2010 1:11 PM To: Schwartz, Guy L (DOA) Subject: RE: 2T -07 Suspend (PTD 186 -108) Guy, Yes the short turnaround is needed because we have a good time in our schedule between other pumping jobs to get this one pumped. The well also has buckled tubing where we are unable to drift past 1500'. The well is a safety concern at this time but, it was determined that the job should be pumped as soon as possible by the end of 2010. There was also some miscommunication and it was thought that a sundry had already been approved when the job was scheduled. When I figured out there was not an approved sundry, I sent one as soon as possible. Please let me know if this will suffice for a justification or if you would like any more information. Thanks for the help on the quick turn around, Merry Christmasll Dan Herrmann Wells Engineer office: 263 -4619 cell: (713)703 -5282 jd.herrmann@conocophillips.com From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Wednesday, December 15, 2010 11:43 AM To: Herrmann, Daniel D Subject: 2T -07 Suspend (PTD 186 -108) Dan, Can you send me an email explaining why the short turnaround is needed for the sundry to Suspend 2T -07. I need to put something in our records to justify that. You mentioned the cementing equipment was available in a short time window and this was opportunity work. 12/15/2010 Page 2 of 2 • Anything else ?? Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) 12/15/2010 ConocoPhillips ~~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 1, 2010 Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 M1. ~,, ,~ ~ ~~ Anchorage, AK 99501 _ . , Commissioner Dan Seamount: ,~~~'~~ _ -u~ 2p~t ~~ ~t< ~~~~,~g~~_ ~~ ui~$~`~~~ ~ ~.`aiCCs'#`~~~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped July 21St. The corrosion inhibitor/sealant was pumped July 30tH, 31St 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, MJ Loveland ,g ~, i o~ ~~.o~ ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off 1..~~"° Report of Sundry Operations (10-404) Kuparuk Field Date 8/01/10 ~Ge sir rr oen Well Name API # PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 26-13 50029211380000 1841040 64" 0.4 11" 7/21/2010 1.7 7/31/2010 2K-16 50103201150000 1890940 SF n/a 19" n/a 2.8 7/31/2010 2K-20 50103201200000 1891180 10" n/a 10" n/a 2 7/31/2010 2K-23 50103201250000 1900140 SF n/a 18" n/a 2.6 7/31/2010 2K-24 50103201220000 1891300 SF n/a 18" n/a 2.6 7/31/2010 2T-07 50103200690000 1861080 17" n/a 17" n/a 5.1 7/30/2010 2T-19 50103202140000 1950260 18" n/a 8" n/a 2 7/30!2010 2T-20 50103202150000 1950290 SF n/a 23" n/a 2.6 7/30/2010 2T-21 50103202120000 1950130 SF n/a 21" n/a 3.4 7/30/2010 2T-26 50103202230000 1950820 SF n/a 27" n/a 4.3 7/30/2010 2T-29A 50103202220100 2091360 SF n/a 29" n/a 7.7 7/30/2010 2T-30 50103202190000 1950570 SF n/a 30" n/a 6 7/30/2010 2T-31 50103202260000 1950990 30" n/a 30" n/a 6 7/30/2010 2T-36 50103202280000 1951020 SF 0.40 12" 7/21/2010 2.6 7/30/2010 2T-39 50103203920000 2011830 30" 0.54 14" 7/21/2010 4.3 7/30/2010 2T-201 50103202300000 1951220 60" 1.57 32" 7/21/2010 7.7 7/30/2010 2T-204 50103203270000 2000160 SF n/a 24" n/a 5.1 7/31/2010 2T-209 50103202810000 1982430 40" 1.20 19" 7/21/2010 4.8 7/31/2010 2T-218 50103204490000 2030170 31" 0.73 9" 7/21/2010 2.6 7/31/2010 2T-220 50103202830000 1982530 38" 0.49 19" 7/21/2010 5.1 7/31/2010 • ConocoPhillips ~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 3, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 • .~ :i~~~~ cif a= ~flGP1C1d'rr~ ~~~5l,'it7 Dear Mr. Maunder: Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. we112T-07 PTD 186-108 Brinker Platelet job. Please call MJ Loveland or myself with any questions. Sincerely, Perry Kl ' Well Integrity Projects • • ~~1~~ ail ~Q~l~ STATE OF ALASKA ;fit k~ ~~' , ~6S ~O~~u g~mISS1011 ALASKA OIL AND GAS CONSERVATION COMMISS (~ REPORT OF SUNDRY WELL OPERATIONS~"c~tor~ 1. Operations Performed: Abandon ^ Repair Well^ Plug Perforations ^ Stimulate ^ Other Q Platelet SC repair Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: COnOCOPhillips Alaska, InC. Development^ Exploratory ^ 186-108 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20069-00 ' 7. KB Elevation (tt): 9. Well Name and Number: RKB 117' ~ 2T-07 ' 8. Property Designation: 10. Field/Pool(s): ADL0025569 ' Kuparuk River Field /Kuparuk Oil Pool ' 11. Present Well Condition Summary: Total Depth measured 6975' ~ feet true vertical 6087' feet Plugs (measured) Effective Depth measured 6897' feet Junk (measured) true vertical 6032' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 110' 16" 110' SURFACE 2655' 9-5/8" 2772' 2772' 3580 2090 PRODUCTION 6331' 7" 6448' 5714' 4980 4320 LINER 747' S" 6975' 6975' Perforation depth: Measured depth: 6524-6539 6571-6613 true vertical depth: 5776-5786 5808-5837 Tubing (size, grade, and measured depth) 4.5",L-80,7031 - 3.5",L-80,7179' - 2.875",L-80,7649 - 2.375",L-80,7784' and Packers &SSSV (type & measured depth) pkr= BROWN 'HB-1' ; BAKER'DB' W/ 5' SEAL BORE EXT. pkr= 6076' ; 6551' SSSV= SSSV SSSV= 1786' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 189 291 465 950 240 Subsequent to operation 189 291 465 950 240 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development 0 ~ Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: Oil Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA conta MJ Lo land er Klein P ame Title WI Project Supervisor Signature Phone 659-7043 -Date ~ ~ O 4 ,'. ~ ~ _~ ~~., ti~Er, ey ~ ~~~"~ Submit O iginal Only Form 10-404 Revised 04/2004 - 2 . a ~ E„„„ 2T-07 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 01/31/09 Brinker Platelets SC Repair -Unsuccessful, Initial T/I/0=240/950/115. Rigged up pump to the platelet skid and started pumping diesel down the OA and established a LLR of 1.5 bpm @ 120 psi., 2.5 bpm @ 360 psi., 3.5 bpm @ 540 psi. Loaded batch #1, 100 - 8 mm light platelets and pumped at a rate of 2.5 bpm @ 340 psi. Loaded batch #2, 100 - 15 mm heavy no core platelets and pumped at a rate of 3.5 bpm @ 500 psi. Loaded batch #3, 100 -15 mm .5" heavy core platelets and pumped at a rate of 2.5 bpm @ 440 psi. Loaded batch #4, 200 - 10 mm heavy cubed platelets and pumped at a rate of 3.5 bpm @ 550 psi. Loaded batch #5, 210 - 5 mm heavy cubed platelets and pumped at a rate of 3.8 bpm @ 550 psi. Loaded batch #6, 50 - 25 mm disc platelets and pumped at a rate of 3.5 bpm @ 550 psi. Unsuccessful on the well, rigged down pump and platelet skid. Final T/I/0=240/950/0. Brinker Platelets SC Repair -Unsuccessful • ConocoPhillips Alaska, Inc. KRU 2T-07 SSSV (1786-1787, OD:2.875) Gas Lift MandnlWaMe 1 (2582-2583, OD:4.750) Gas Lift MandreWaNe 2 (4090-4091, OD:4.750) Gas Lift MandreWaNe 4 (5319-5320, OD:4.750) Gas Lift MandreWalue 6 (6016-6017, OD:5.500) PBR (6057-6058, OD:2.875) PKR (6076-6077, OD:6.151) SLEEVE-C (6136-6137, OD:2.875) NIP (6155-6156, OD:2.875) Pert (6524-6539) PKR (6551-6552, OD:4.151) NIP (6563-6564, OD:2.375) TUBING (6157-6566, OD:2.375, ID:1.995) Perf (6571-6613) 2T-o~ API: 501032006 900 Well T e: PROD _ Angle TS: 47 deg @ 6521_ _ SSSV T e: _ LOCKED OUT Ori Com letion: _ 8/28/1986 An le TD: 46 deg a[7 6975 _ Annular Fluid: _ _ Last W/O: Rev Reason: Comment Note than ed for WV 8.1 _ Reference Log: _ _ __ _ Ref L Date: Last U date: 1/25/2007 . Last Tag: 6573 TD: _ 6975 ftKB Last Ta Date: 2/7/2004 Max Hole An le: 50 d 5400 Casing Strin -ALL S Tl GS _ Description Slze Tom Bottom ~ TVD Wt Grade Thread _ _ _ CONDUCTOR 16.000 0 110 110 62.50 H-40 __ SUR. CASING 9.625 0 2772 2772 36.00 J-55 PROD. CASING 7.000 0 6448 -_ 5724 26.00 - J-55 LINER 5.000 _ 6228 6975 6975 18.00 S-140 Tubing_String -TUBI - Size Top_ 2.875 0 2.375 6157 NG _ -- - Bottom TVD Wt Grade Thread _ 6157 5526 6.50 J-55 EUE 8RD AB-MOD 6566 5805 4.70 N-80 EUE 8RD AB-MOD rations ~wnm Interval TVD Zone Status Ft SPF Date T e Comment 6524 - 6539 5776 - 5786 C-4,UNIT 8 15 12 _ 10/30/1986 IPERF 3 3!8" HyperJet II; 60 deg. Ph 6571 - 6613 5808 - 5837 A-3 42 _ 12 10/30/1986 IPEF 3 3/8" HyperJet II; 60 deg. Ph Gas Lift MandrelsNal ves St MD TVD 1 Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 2582 2582 Camco _ KBMG GLV 1.0 BK 0.188 1336 10/30/200 2 4090 4015 Camco ~ KBMG GLV 1.0 BK 0.188 1334 10/30/200 3 4957 4719 Camco KBMG DMY 1.0 BK 0.000 0 10/31/19 4 5319 4977 - Camco_ KBMG _ GLV 1.0 BK 0.188 1327 10/30/200 5 5697 5223 Camco KBMG DMY 1.0 BK 0.000 0 10/31/198 6 6016 5432 MMH HTC OV 1.5 RK 0.250 0 3/4/2006 Pro ducti on Mandrels Naives _ - St MD _ TVD Man !~ Mfr Man Type V Mfr _ V Type V OD Latch Port TRO Date Run V-v Cmnt 7 _ 6114 5498 Camco KBMG OMY 1.0 BK 0.000 0 10/31/19 Closed Other lu s, a ui ., etc. -JEWELRY De th TVD T e Description ID 1786 1786 SSSV TRDP-IA-SSA'Locked Out 9/3/93' (WRDP Pu Iled 3/30/95 2.312 6057 5460 PBR _ BroHrn 2.500 6076 5472 PKR Brown'HB-1' 2.750 6136 5512 SLEEVE-C Otis; 'XA' SLIDING SLEEVE CLOSED 4/2/95 2.310 6155 5525 NIP Camco'D' Ni le NO GO 2.250 6551 5795 PKR Baker'DB' w/ 5' seal bore ext. 3.250 6563 5803 NIP Camco'D' Ni le NO GO 1.812 _6_565 5804 S OS__ am C co 1.995 6566 _ _ 5805 TTL _ _ 1.995 General Notes Date Note ?J7/2004 NOTE: HEAVY, ERRATIC PICKUP W EIGHTS SUGGEST CORKSCREW TBG FROM TTL- 500' MICROFILMED 9/1 ~/00 DO NO'/- PLACE ANY' NEW MATERIAL UNDER THIS PAGE DEPT. OF NATURAL RESOURCES DIVISION OF OIL AND GAS ~ April 12, 1991 D. W. Johnston, AOGCC Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Subject: Release of ARCO Kuparuk River Unit 2T Well Data WALTER d. HICKEL, GOVERNOR RO. BOX 107034 ANCHORAGE. ALASKA 99510-7034 PHONE: (907) 762-2553 ._ -- ':'; ;'.,. ~ ,. ;'.. -.;- ' ~,'s '. 3' r ' __ ' _.~--- - o'T - -.'-:;'i- ?~O.-) * .- ----~, ~.~'X' .... -. ~ ~", ~..2," Dear Commissioner Johnston: On August 5, 1988 1 granted extended confidentiality for the Kuparuk River Unit 2T wells. The Kuparuk River Unit 2T-2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 12A, 13, 14, 15, 16, and 17 wells were granted extended confidentiality until 90 days after the unleased land in T11N R7E Umiat Meridian could be offered for lease. The unleased land in this township was offered for lease in Sale 70A which was held on January 29, 1990. Therefore, the wells no longer qualify for extended confidentiality and the well data should be released on April 30, 1991. By copy of this letter I am notifying ARCO Alaska Inc. of the upcoming release of the above listed wells. Sincerely, (J~.mes E. Eason 2)n'ector cc: J. L. Dees, ARCO Alaska Inc. RECEIVED APR 1 6 199t Alaska Oil .& Gas Cons. Commission gnchorage ~'r-, /STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Operation: Operation Shutdown Pull tubing Alter casing Stimulate X Plugging Perforate _ Repair well Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 277' FSL, 556' FWL, Sec. 1, T11N, R8E, UM At top of productive interval 1286' FSL, 1172' FEL, Sec. 2, T11N, R8E, UM At effective depth 1388' FSL, 1424' FEL, Sec. 2, T11N, R8E, UM At total depth 1409' FSL, 1477' FEL, Sec. 2, T11N, RSE, UM 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 80' 2739' 6. Datum elevation (DF or KB) RKB 117 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2T-07 9. Permit number/approval number 86-108 / 8-75cJ 10. APl number 5o-103-20068 11. Field/Pool Kuparuk River Field/ Kuparuk River Oil Pool 6975' feet Plugs (measured) 60 8 6' feet Cement: 6975'-6897' 689 7' feet Junk (measured) 6 0 3 2' feet None Size Cemented Measured depth 1 6" 245 Sx CS I 1 10' 9 5/8" 750 Sx AS III & 2772' 285 Sx Class G 7" 410 Sx Class G &200 Sx AS I 644 9' 5" 125 Sx Class G 6 9 7 5' 6 SPF 60 degree phasing 6419' 747' measured 6524'-6539', 6571 '-6613' True vertical depth 110' 2772' 5724' 6086' true vertical 5775'-5786', 5807'-5836' TVD Tubing (size, grade, and measured depth 2 7/8" J-55 set at 6155', 2 3/8" N-80 set from 6155'-6567' Packers and SSSV (type and measured depth) HB-1 @ 6076', DB pkr @ 6551', Camco TRDP-1A-SSA @ 1786' 13. Stimulation or cement squeeze summary Fracture A Sand with gelled water data frac.and sand frac. Intervals treated (measured) 6571 '-6613' Treatment description including volumes used and final pressure 14. 749 bbls gelled water, 240 bbl diesel, 89,000 lbs 16/20 Carbolite, final pressure 5448 psi. Reoresentative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 383 680 0 1000 228 Subsequent to operation 1364 2271 0 1050 299 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Water Injector Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~ned ~)~'-~ · ~ Title Senior Operations Engineer Form 10-404 Rev 09/12/90 Date SUBMIT IN DUPLICATE ARCO Alaska, Subsidiary of Atlantic Richfield Compan~ WELL SERVICE REPORT WELL CONTRACTOR AEMARKS //o. TI ) OPERATION AT'REPORT TIME / o~oo -- oSc)o ._~/oo ~; / ~, I /:~,"m /9:0 .&",n 2 o,/ [] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ARCO Alaska, Inc. Date: May 12, 1989 RETURN TO: ARCO Alaska, lnc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal Ct: 7470 ~".lazka 0;! & ~;a~ Cons. Anchorage Transmitted herewith are the following items. one signed copy of this transmittal. 30-18 .'~3A-03 ~'3A-08 ~"'3 O- 11 ~"30-13 '~'"'3 O- 17 B-14 DO8 ~3A-08 '~ 30-12 '~30-18 2B-14 ~1 R-02 ~,3F-16 ~ 3F-16 ~1 R-02 ~1Y-06 '~' 2'[-07 ~1 E-25 Sub-Surface Pressure Survey Ku3aruk Fluid Level Re3ort Ku3aruk Ku3aruk Ku3aruk Ku 3aruk Ku:3aruk Ku3aruk Ku 3aruk Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Ku 3aruk Ku3aruk Ku3aruk Ku 3aruk Ku3aruk Ku 3aruk Ku3aruk Fluid Level Re Fluid Level Re Fluid Level Re Fluid Level Re Fluid Level Re Fluid Level Re Fluid Level Re Fluid Level Re Fluid Level Re Fluid Level Re Fluid Level Re Fluid Level Re Fluid Level Re Fluid Level Re Fluid Fluid Fluid Fluid Well 3ort 3ort 3ort 3ort 3ort 3ort 3ort 3ort 3orr 3ort 3ort 3ort 3orr 3ort Level Report Level Report Level Report Level Report Presure Report Please acknowledge receipt and return 2-15-89 4-23-89 4-23-89 4-22-89 4-22-89 4-22-89 4-24-89 4-24-89 4-24-89 4-24-89 4-29-89 4-29-89 4-29-89 4-30-89 4-29-89 5-03-89 5-04-89 5-03-89 5-08-89 5-07-89 11-07-88 #64613 Casing Casing Casing Casing Casing Casing Casing Casing Casing Casing Casing Casing Casing Casing Tubing Tubing Casing Casing Casing Amerada Receipt Acknowledged: ........................... Date' - ........... 01,~TRIBUTION: D&M ~ SAPC Chevron Mobil Unocal AL,, .A OILAND GAS CONSERVATION COMMi. ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program_ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface Operation Shutdown _ Re-enter suspended well_ _ Plugging _ Time extension _ Stimulate .X . Pull tubing _ Variance _ Perforate _ Other 5. Type of Well: Development ~X Exploratory _ Stratigraphic _ Service _ 277' FSL, 556' FWL, Sec. 1, T11N, R8E, UM At top of productive interval 1286' FSL, 1172' FEL, Sec. 2, T11N, R8E, UM At effective depth 1388' FSL, 1424' FEL, Sec.2, T11N, R8F_., UM At total depth 1409' FSL, 1477' FEL, Sec. 2, T11N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 6975' feet Plugs (measured) 6 08 6' feet None 6. Datum elevation (DF or KB) RKB 117' feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2T-7 9. Permit number 86-108 10. APl number 50-1 03-20069 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured true vertical 6897' feet Junk (measured) 603 2' feet None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 80' 2739' Size Cemented Measured depth 1 6" 9 5/8" 6419' 7" 747' 5" measured 6524'-6539', 245 Sx CS I 1 10' 750 Sx AS III & 2772' 285 Sx Class G 410 Sx Class G & 200 Sx ASI 6449' 125 Sx Class G 6228'-6975' 6571'-6613' MD True vertical depth 110' 2772' 5724' 5573'-6086' ~ true vertical 5775'-5786', 5807'-5836' TVD Tubing (size, grade, and measured depth 2 7/8", J-55, surf. to 6155', 2 3/8", N-80 6155' to tbg tail @ 6567'. Packers and SSSV (type and measured depth) HB-1 pkr @ 6076', DB p[kr @ 6551', TRDP-1A-SSA SSSV @ 1786' 13. Attachments Description summary of proposal X Detailed operation program _ Perform A Sand gelled water data frac and sand fracture treatment. BOP sketch 14. Estimated date for commencing operation 10/2/88 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ~ Gas __ Service Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. FOR coMMIsSION USE ONLY Conditions of approval' Plug integrity_ BOP Test_ Location clearance Mechanical Integrity Test _ Subsequent form ORIGINAL SIGNED BY Approved by the order of the Commission 1,0NNIE C. SMITH Form 10-403 Rev 06/15/88 Notify Commission so representative may witness require 10- .-~pprove(~ L;opy Returne~d~ //~ /// ~,,r~rnm.!_~sioner IApprovaLNo. SUBMIT IN TRIPLICATE KUPARUK WELL 2T-07 Data Frac & Fracture Procedure 9/23/88 Charge Code: 230DS28TL Pre-Job 1. MIRU Slickline. 2. RIH with Gauge Ring and Tag Bottom.(note fill location) POOH. If Fill is Above 6660 FT-MD this procedure may need to be modified or the Well Cleaned out. 3. RIH and Close Otis Sliding Sleeve. POOH. 4. RIH with standing valve and set in "D" nipple. 5. PT tubing to 3000 psi to ensure tubing isolation. 6. RIH. Pull Standing Valve. 7. RDMO slickline 8. MIRU pump truck. 9. Pump musol/diesel spear. Let soak overnight. 10. RDMO pump truck. Data Frac 11. MIRU fracture equipment. Install "tree saver". 12. MIRU E-Line unit. 13. RIH with CCL, Temp, and Terra Tek TQ10 Pressure Gauge. Tie In. Set Top of Tool String no higher than 6620 FT-MD, Preferably at 6640 FT-MD if Rat Hole is Sufficient. 14. Operations Engineering will Set Up all Necessary Surface Equipment to Monitor the Data Frac. 15. Carry Out All Quality Control Procedures (Onsite Operations Engineering). The specific procedures will depend on the vendor selected. * * The pressure on the annulus should be maintained as close as possible to 3500 psi during the data fracture treatment. 16, Perform formation breakdown and shut-in test to determine closure pressure. Pump 150 bbl of 2% KCL at 20 BPM. Be prepared to pump an extra 50 bbl of 2% KCL if "breakover" does not occur before 140 bbls of 2% KCL has been pumped. Shutdown for approximately 15 minutes to determine closure pressure. 17. Perform pump-in/shut-in test. Pump 50 bbls of 2% KCL at 20 BPM. Shut down for 10 minutes and monitor. Pump another 50 bbls of 2% KCL at 20 BPM and shut down for 10 minutes to monitor. 18. Perform data frac test. Pump the first 37 bbls at a reduced rate (5 BPM) and then shut down for 3 minutes. This will displace the 2% KCL Water out of the tubing and allow it to leak off into the formation. Pump the remaining 263 bbls of Gelled Water with 5% Diesel at 20 BPM. Shut Down and monitor pressure for 30 Minutes. 19. Pull E-Line out of hole and Rig Down. Fracture Treatment 20. Rig Up Equipment to Pump the Fracture Treatment. Obtain reoresentative fluid samoles from the _Dad. slurry, and flush staoes durino the fracture treatment. This data will be used to determine the fl~)w b~,ck, schedule. 21. Pump fracture treatment per the attached schedule. Expected Wellhead Treating Pressure: WHTPE = 4660 psi Fracture Gradient = 0.66 psi/ft (5803' TVD) Tubing Friction (2-7/8") = 480 psi/1000 ft (6106' MD) Tubing Friction (2-3/8") = 1000 psi/1000 ft (410' MD) Recommended Max Treating Pressure = 6,200 psi ** IF treating pressure during the pad is in excess of 5,200 psi, shut down job and confer with Operations Engineering. Ensure capability to drop ball sealers if necessary. 22. SI well and rig down 'frac equipment Sundry Notice - Well 2T-7 A Sand Fracture Treatment No BOP's are used during the fracture. The frac will be pumped through a manifold on the surface, ASand pressure (6200' SS) = 3243 psi 7/18/87 SWHP/FL No workover fluid will be used during this process. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 4, 1988 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in triplicate are multiple Applications for Sundry Approvals on the following Kuparuk wells. Well Action Anticipated Start Date 1 F- 0 1 Acidize October, 1988 I F- 0 3 Acidize October, 1988 I F- 0 9 Acidize October, 1988 2 X- 01 Fracture October, 1988 2T-07 Fracture October, 1988 1 G- 1 0 Acidize September, 1988 If you have any questions, please call me at 265-6840. Sincerely, Senior Operations Engineer GBS:kjr Attachments cc: J. Gruber ', ATO 1478 M. L. Hagood ATO 1120 S. P. Twiggs ATO 1130 KOE1.4-9 ARCO Alaska, Inc. is a Subsidiary of AllanlicRichfieldCompany' ARCO Alaska, Inc. Post Office E).._ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: April 28, 1987 Transmittal #: 5961 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~3N-9 ~3N-8A ~2T-7 ~2T-4 ~T-15 ~2T-11 CEL 4-7-86 7500-9272 CEL .4-7-86 5100-9272 'CET/CEL 10-29-86 6200-6712 CET/CEL 10-4-86 7350-8160 CET/CEL 10-7-86 6900-7465 CET/CEL 10-11-86 5965-6620 '"'/3 -- Receipt ~cknowledged: DISTRIBUTION: NSK Drilling Mobil SAPC Unocal Vault (film) ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompamy BPAE Chevron " STATE OF ALASKA ~ ALASKA ._,_ AND GAS CONSERVATION C~, MISSION /~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG nSkk vvmrkk · IVI1 Vfl flkVVlll~kk · IVll ~krV-- · ~qlqU mvM 1. Status of Well Classification of Service Well OIL~ GAS [] SUSPENDED [] ABANDONED [] SERVICE 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 86-!08 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 103-20069 4. Location of well at surface 9. Unit or Lease Name 277' FSL, 556' FWL, Sec. 1, T11N, R8E, UM Kup .......... .... ,, D~ .... Unit At Top Producing Interval 10. Well Number 1286' FSL, 1172' FEL, Sec. 2, T11N, R8E, UM o~I_.~6. , At Total Depth 11. Field and Pool 1409' FSL. lb, 77' FFI -~;~ ? T!!N P.~¢ IJM Kuparuk River Field 5. Elevation in ~eet (indicate t~B, DF, etc~.) ; "'~:Lease Designation andSerial No. RKB 117' ADL 25569, ALK 2667 Kuparuk River 0il Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 07/22/86 08/25/86 01/17/87* N/A feet MS LI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. D'~re. ctionalSurvey 20. Depth where SSSV set 21. Thickness of Permafrost 6975'MD 6086'TVD 6897'MD 6032'TVD YESES' NO[] 1786' feetMD 1550' (Approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, Cal, CET, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSIZE~WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 110' 24" 245 sx CS II 9-5/8" 36.0# J-55 Surf 2772' 12-1/4" 750 sx AS III & 285 sx ;lass G 7" 26.0# J-55 Surf 6449' 8-1/2" 410 sx Class G & 200 sx AS I Squeezed liner lap w/101) sx Class G 5" 18.0# S 140/N-80 6228' 6975' 6-1/8" 125 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) I 6524'-6539'MD 5775'-5786'TVD 2-7/8" 6566' 6076' & 6551 6571 ' -6613 'HD 5807 '-5836 'TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Perforated w/6 spf, 60~ phasing DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED See attached AddenJum, dated 01/29/87) for Fracture data.. 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED~L OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. CONJ:i AL WNote= Drilled RR 08/28/86. Well perforated & 'cubing run 10/31/86, Form 10-407 Rev. 7-1-80 WC2:029:DAN I CONTINUED ON REVERSE SIDE Submit in duplicat/ ' ~ - - .' ....... "GEOLOGIC MARKERS ~-'' -' """ '~'" ::"?: ~' ; ;" '"FORMATi'ON TESTS ' NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEI~TH GOR, and time of each phase. . ' . . Top Kuparuk C 6521' 5773' Base Kuparuk C 6540' 5786' Top Kuparuk A 6540' 5786' Base Kuparuk A -: 6738' 5923' : 31. LIST OF ATTACHMENTS Addendum, dated 01/29/87. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Associate Engineer INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ~ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplement.aj~ ~ecords~for this, well sh°ul'd show the details of any multiple stage cement- ing and the location of the ceme..qting~ tool. ' .... Item 27' Method of Operation' [F[~_wj~ng,i~-'~ [if't, Ro.~l' ~mp, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. ' Item 28' If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 7/31/86 1/17/87 2T-7 Arctic Pak w/200 sx AS I, followed by 53 bbls Arctic Pak. Stimulate Kuparuk "A" sand perfs 6571'-6613' per procedure dated 12/11/86 as follows: Stage #1: Stage #2a: Stage #2b: Stage #3: 37 bbls 150° diesel @ 1, 2200-1600 psi 35 bbls 50/50 IPA & diesel @ 2-1/4 BPM, 1600-2000 psi 90 bbls 50/50 IPA & diesel @ 1/2 BPM, 2000 - 1900 psi 35 bbls 100° diesel @ 1/2 BPM, 1900 psi Date SUB-SURFACE DIRECTIONAL SURVEY F~UIDANCE ~]ONTI'NUOUS [-~OOL Company ~co ALASKA, INC. Well Name 2T-7 (277'FSL, 556'FWL, Field/Location KUPARUK, NORTH SLOPE, SEC. 1, TllN, R8E, UM) ALASKA Job Reference No. 72070 Logaed Ely: SARBER Date 10/28/86 Computed By: KRUWELL GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ~RCO ALASKA, INC. 2T-7 ~UPARUK NORTH SLOPE,ALASKA METHODS OF COMPUTATION TOOL LOCATION: TANGENTZ4L- INTmRP~LATI3N: LINEAR VERTICAL SECTION: HGRIZ. DIST. SURVEY DATE: 28-0CT-86 ENGINEER: G. SAR~ER AVERAGED DEVIATION AND PROJECTED ONTO A TARGET AZIMUTH AZIMUTH OF NORTH 60 DEG 56 MIN WEST GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. 2T-7 KUPARUK NORTH SLCPE,ALASKA SURVEY OATE: 28-0CT-85 ENGINEER: G. SARBER METHODS O~ CCMPUTATZON TOOL LOC.&TION: TANGENTIAL- ~VER~GED DEVIATION AND AZIMUTH INTERPOLATION: LINE&R VERTICAL SECTION: HGRIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 6O MIN WEST COMPUTATION DATE: 19-NOV-86 FAG6 1 ARCO ALASKA, INC. 27-7 KUPARUK NORTH SLOPE,ALASKA INTERPOLATED VALUES FOR TRUE SU~-SEA RED VERTICAL VERTICAL DEVIATION OEG MIN 0 0 0 13 0 22 0 33 0 42 0 42 0 48 0 58 0 48 0 51 0 18 0 21 0 37 0 32 0 34 0 19 0 18 0 015 0 15 0 16 0 11 0 13 0 13 0 19 0 17 0 18 0 16 0 11 0 36 EVEN 100 FEET OF MEASU DEPTH DEPTH DEPTH . 0.00 0.00 -117.00 100.00 100.00 -17.00 200.00 200.00 83.00 300.00 299.99 182.99 400.00 399.99 282.99 500.00 499.98 382.98 600.00 - 599.97 482.97 700.00 699.96 582.96 800.00 799.95 682.95 900.00 899.93 782.93 1000.00 999.93 832.93 1100.00 10'99.93 982.93 1200.00 1199.92 1082.92 1300.00 1299.92 11J2.92 1400.00 1399.91 1282.91 1500.00 1499.91 1382.91 1600.00 1599.91 1482.91 1700.00 1699.91 1582.91 1800.00 1799.90 1682.90 1900.00 1899.90 1782.90 2000.00 1999.90 1882.90 2100.00 2099.90 1982.90 2200.00 2199.90 2082.90 2300.00 2299.90 2182.90 2400.00 2399.90 2282.90 2500.00 2499.90 2352.90 2600.00 2599.90 2482.90 2700.00 2699.~9 2582.89 2800.00 2799.~9 2682.59 2900.00 2899.89 2782.89 3000.00 2999.87 28S2.37 3100.00 3099.67 2982.67 3200.00 3198.97 3081.97 3300.0'3 3297.07 3160.07 3400.00 3393.34 3276.34 3500.00 3487.87 3370.37 3600.00 3580.69 3463.69 3700.00 3671.72 3554.72 3800.00 3761.49 3644.49 3900.00 3850.04 3733.04 OATE OF SURVEY: 28-0CT-$6 KELLY BUSHING ELEVATION: ENGINEER: G. SAREER MEASURE COURSE VERTICAL gOGLEG RECTAN AZIMUTH SECTION SEVERITY NORTH/ DEG MIN FEET O~G/lO0 FEE N 0 0 E S 42 10 E S 79 11 E S 87 55 E N 84 49 E N 59 55 E N 58 53 E N 72 39 E N 59 26 E N 59 27 E N 26 5~+ E S 72 56 5 N 74 31E S 63 16 E S 50 30 E S 45 39 E N :35 46 E N 80 11~ N 89 5 E N 38 18 W 0.00 0.00 -0.37 0.28 -0.91 0.30 -1.72 0.05 -2.68 0.09 -3.48 0.11 -4.15 0.08 -5.04 0.06 -6.09 0.9~ -6.60 1.11 -7.11 0.60 -7.46 0.30 -7.97 0 · 74 -9.00 0.43 -9.97 0 · 67 -10.74 1.00 -11.18 0.23 -11.32 0.8,5 -11.40 ~.93 -11.47 1.10 -11.50 0.55' -11.49 0.14 -11.10 0.06 -1!.16 0.69 -11.37 0.38 -11.46 0.18 -11.08 0.36 -10.71 0.45 -10.90 0.45 -11.46 0.19 N 75 5 E N 56 33 W N 44 55 W S 25 47 E S 0 2 W S 74 !0 W S 72 54 W S 60 4 N S 69 8 E N ,59 58 E 1 51 N 21 33 W 4 50 N 38 28 W ~ 48 N 46 19 W 13 19 N 50 8 W 17 35 N 51 5 W 20 17 N 55 41 W 23 19 N 58 39 W 25 19 N 59 14 W 26 53 N 59 19 W 28 24 N 59 20 W 00 GULAR COOrDINaTES HORIZ. SOUTH EAST/WEST DIST. T FEET FEET 0.00 N 0.00 E 0.00 0.11 S 0.37 E 0.38 0.32 S 0.8'7 E 0.92 0.32 S 1.78 E 1.81 0.28 S 2.91 E 2.93 0.08 N 4.02 E 4.02 0.77 N 5.18 E 5.23 1.47 N 6.58 E 6.75 2.00 N 8.07 E ',3.32 2.97 N 9.20 E 9.67 3.42 N 10.03 E 10.60 3.63 N 10.57 E 11.15 3.90 N 11.28 E 11.94 3.72 N 12.36 E 12.91 3.43 N 13.32 E 13.75 2.78 N 13.83 E 14.11 2.70 N 14.29 E 14.55 2.53 N 1~.36 E 14.58 2.75 N 14.57 E 14.83 2.62 N 14.58 E 14.81 3.04 N 14.84 E 15.15 3.12 N 14.87 E 15.19 3.3.5 N 14.56 E 14.94 3.48 N 14.70 E 15.11 2.91 N 14.62 E 14.91 2.50 N 14.50 E 14.71 2.41 N 14.01 E 14.22 2.18 N 13.47 E 13.64 1.74 N 13.44 E 13.55 1.84 N 14.15 E 14.27 -11.19 3.93 3. -5.67 2.13 8. 5.49 5.17 16. 24.31 4.94 29. 50.78 2.94 46. 83.11 3.06 65. 120.20 2.79 85. 161.53 1.87 107. 205.59 1.63 129. 252.04 1.16 153. 08 N 14.51 E 14.84 15 N 11.01 E 13.70 41 N 2.83 E 16.55 14 N 11.62 W 31.37 33 N 32.35 W 56.51 7~ N 58.55 W 88.03 85 N 89.~0 W 124.24 04 N 125.31 W 164.51 56 N ' 163.21 W 203.38 27 N 203.17 ~ 254.50 DEPARTURE AZIMUTH DEG MIN N 0 0 E S 73 27 E S 70 4 E S 79 51 E S 84 31 E N 88 53 i~ N 81 31 N 77 22 E N 76 5 E N '72 6 E N 71 9 E N 70 56 E N 70 55 E N 73 14 E N 75 32 E N 78 37 E N 79 17 E N 80 0 E N 79 lB E N 79 48 E N 78 25 E N 78 9 E N 77 2 E N 75 41 E N 78 43 E N 80 12 E N 50 13: N ,~0 48 i N 32 36 E N 82 35 E N 75 0 E N 53 29 E N 9 47 E N 21 43 W N 3~ 55 W N 41 41 W N 46 17 W N 49 29 W N 51 33 ,~ N 52 58 W FT COHPUTATION DATE: 19-NOV-85 PAGE 2 ARCO ALASKA, INC. 27-7 KUPARUK NORTH SLOPE,ALASKA T mEASURED VER DEPTH D 4000.00 39 4100.00 40 4200.00 41 4300. O0 41 4400.00 42 ~500.00 43 4600.00 44 4700.00 45 4800.00 45 4900.00 46 5000.00 5100.00 5200.00 5300.00 5400.00 5500.00 5500.00 5700.00 5800.00 5900.00 600 610 620 630 640 650 660 670 680 690 INTERPOLATED VALUES FOR RUE SUB-SEA COURSE TICAL VERTICAL DEVIATION AZIMUTH EPTH DEPTH DEG MIN DEG MiN 37.32 3820.32 23.16 3906.16 07.56 3990.66 90.87 4073.87 72.71 4155.71 52.97 4235.97 32.56 4315.56 12.45 4395.45 92.61 4475.61 73.07 4556.07 4752.48 4635.48 4827.91 4710.91 4898.14 4781.14 4963.87 4846.87 5028.58 '4911.58 5093.51 4976.51 5158.73 5041.73 5224.06 5107.06 5289.05 5172.05 5354.67 5237.67 0.00 5420.80 5303.90 0.00 5487.51 5370.51 0.00 5554.42 5437.42 0.00 5621.84 5504.84 0.00 5689.92 5572.92 0.00 5758.39 5641.89 0.00 5827.48 5710.48 0.00 5896.39 5779.39 0.00 5965.43 584~.43 0.00 6034.47 5917.47 30 5 N 59 38 W 31 37 N 59 48 W 33 1 N 59 49 W 34 20 N 59 29 W 35 50 N 59 19 W 37 11 N 59 6 W 37 6 N 58 59 W 36 53 N 58 5i ~ 36 28 N 58 31 W 36 35 N 58 22 W 38 52 N 56 39 W 43 14 N 55 13 W 47 28 N 54 16 W 49 33 N 56 5 W 49 41 N 57 1 W 49 23 N 57 48 W 49 5 N 59 0 W ~9 31 N 60 59 W 49 11 N 62 56 W 48 50 N 63 44 W 48 24 N 64 55 W 48 3 N 65 54 w 47 48 N 66 35 W 47 14 N 67 27 W 46 52 N 68 10 W 46 32 N 68 42 w 46 33 N 68 16 W 46 20 N 67 47 W 46 20 N 67 47 W 4~ 20 N 67 47 W OATE OF SURVEY: 28-0CT-86 KELLY ~USHING ELEVATION: 117.00 MT ENGINEER: G. SAREER EVEN 100 FEET OF MEASURED DEPTH VERTICAL OOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET OEG MIN 300.81 1.64 178.03 N 245.20 W 303.02 N 54 1 N 352.10 1.55 203.86 N 289.53 W 354.10 N 54 51 W 405.55 1.39 230.72 N 335.76 W 407.39 N 55 30 W 4,51.00 1.18 258.74 N '383.61 W 462.71 N 56 0 W 518.43 1.54 287.99 N 433.06 W 520.08 N 56 22 W 578.05 0.66 318.53 N 484.29 W 579.66 N 56 39 538.55 1.04 349.67 N 536.21 W 640.15 N 56 53 698.66 0.46 380.73 N 587.72 W 700.26 N 57 3 W 758.41 0.45 411.77 N 638.32 W 760.03 N 57 11 W ~17.74 0.57 442.85 N 689.43 W 819.,1 N 57 17 W 878.40 ~.63 475.11 N 740.90 W ~80.15 N 57 19 W 943.73 4.54 512.08 N 795.09 W 945.73 N 57 12 W 1014.43 3.65 553.47 'N 852.97 W 1016.80 N 57 1 W 108'9.37 1.64 596.72 N 914.68 W 1092.11 N 56 52 W 1165.40 0.60 638.63 ,N 978.36 W 1168.35 N 56 51 W 1241.30 0.76 ,679.61 N 1042.43 W 1244.40 N 56 53 W 1317.03 1.04 719.37 N 1106.97 W 1320.18 Iq 56 58 W 1392.72 2.27 757.43 N 1172.40 W 1395.79 N 57 8 g 1468.70 0.76 792.89 N 1239.63 W 1471.51 N 57 23 W 1544.09 0.62 826.77 N 1307.05 W 1546.58 N 57 41 W 1618.9~ 1.11 859.37 N 1374.61 W 1621.13 N 57 59 W 1693.23 0.67 890.24 N 1442.40 W 1695.00 N 58 19 W 1767.22 0.85 920.15 N 1510.43 W 1768.64 N 5,~ 39 ~ 1840.66 1.16 948.94 N 1578.44 N 1841.73 N 5~ 59 W 1913.39 2.87 976.61 N 1646.27 W 1914.15 N 59 19 ~ 1985.19 3.46 1003.36 N 1713.55 W 1985.70 N 59 38 i,' 2057.31 0.13 1029.99 N 1781.26 W 2057.61 N 59 57 21~9~ .25 0.00 1057.24 N 1848.41 W 2129.41 N 60 13 w 2201.07 0.00 1084.58 N 1915.39 W 2201.14 N 60 28 N 2272.90 0.00 1111.92 N 1962.37 W 2272.92 N 60 42 W 6975.00 5086.25 5969.25 46 20 N &7 47 W 2326.77 0.00 1132.42 N 2032.60 W 2325.77 N 60 52 N COMPUTATION DATE: 19-NOV-86 PAGE 3 ARCO ALASKA, INC. 2T-7 KUPARUK NORTH SLOPE,ALASKA INTERPOLATED VALUES FOR EVEN 1000 FEET MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEG MIN OEG MiN VERTICAL DOGLEG SECTION SEVERITY FEET DEG/iO0 100 2OO 3O0 40O 5O0 60O 697 0.00 0.00 0.00 O.OO 0.00 O.OO 0.00 5.00 0,00 -117,00 O 0 N 0 0 999,93 882.93 0 18 N 26 54 1999.90 1882,90 0 16 N 75 5 2999,87 2882.87 1 51 N 21 33 3937,32 3820,32 30 5 N 59 38 4752,48 4635.48 38 52 N 56 39 54Z0,80 5303,80 48 24 N 64 55 6086,25 5969.25 46 20 N 67 47 0.00 0.00 -7.11 0.60 -11.50 0.55 -11.19 3.93 300.81 1.64 878,40 4,63 1518,98 1,11 2326.77 0,00 ME&SU RECTA NORTH FE 0 3 3 3 178 475 859 1132 DATE OF SURVEY: 25-0CT-86 KELLY 5US~tING ELEV.~TION: 117.00 FT ENGINEER: G. SARBER RED DEPT NGULAR COORDINATES HORIZ. DEPARTURE /SOUTH EAST/WEST DIST. AZIMUTH ET FEET FEET DEG MIN .00 N 0.00 ~ 0.00 N 0 0 E .42 N 10.03 E 10.60 N 71 9 E .04 N 14.84 E 15.15 N 78 25 E .08 N 14.51 E 14.84 N 78 0 E · 03 N 245.20 W 303.02 N 54 1 W ,11 N 740,90 W 880.15 N 57 19 ~.' ,37 N 1374,61 W 1621,13 N 57 59 ,42 N 2032,60 W 2326.77 N 60 52 w ARCO ALASKA, lNG. 2T-7 KUPARUK NORTH SLOPE,ALASKA COMPUTATION DATE: INTERPOLATEO VALUES FOR EVEN 100 TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 0,00 0,00 -117,00 17,00 17,00 -100,00 117,00 117,00 0,00 217,00 217,00 100,00 317.01 317.00 200.00 417.02 417.00 300.00 517,02 517,00 400,00 617,03 617,00 500,00 717,04 717,00 600.00 817,06 817,00 700,00 917.07 917.00 800.00 '1017.07 1017.00 900.00 1117.07 1117.00 1000.00 1217.08 1217.00 1100.00 1317.08 1317.00 1200.00 1417.09 1417.00 1300.00 1517.09 1517.00 1400.00 1617.09 1617.00 '1500.00 1717.09 1717.00 1600.00 1817.10 1817.00 1700.00 1917.10 1917.00 1800.00 2017.10 2017.00 1900.00 2117.10 2117.00 2000.00 2217.10 2217.00 2100.00 2317.10 2317.00 2200.00 2417.10 2417.00 2300.00 2517.10 2517.00 2400.00 2617.10 2617.00 2500.00 2717.11 2717.00 2600.00 2817.11 2817.00 2700.00 2917.11 2917.00 2800.00 3017.14 3017.00 2900.00 3117,40 3117,00 3000,00 3218,27 3217,00 3100,00 3320,53 3317,00 3200.00 3424,87 3417,00 3300.00 3531,16 3517,00 3400,00 3639,71 3617,00 3500,00 3750,27 3717,00 3600,00 3862,53 3817,00 3700,00 19-NDV-~6 FEET OF COURSE VERTICAL DOGLEG DEVIATION AZIMUTH SECTION SEVERITY DEG MIN DEG MIN ~EET DEG/IO0 0 0 N 0 0 ':'" 0 0 0 0 38 N 72 38 ,,-- 0.00 0 15 S 52 55 E -0,44 0 26 S 85 34 E -1.02 0 34 S 88 36 =. -1.86 0 41 N 83 25 E -2,85 0 42 N 59 0 E -3.58 0 50 N 59 lB E -4.27 0 58 N 71 58 E -5,24 0 49 N 50 32 E -6,19 0 '%6 N 67 11 E -6,75 0 21 N 27 34 E -7,10 0 17 S 84 33 E -7,56 0 40 N 85 21 E -8,12 0 30 S 69 10 E -9,15 0 33 S 42 55 E -10,14 0 17 S 67 37 C -10,83 0 17 S 75 50 E -11,26 0 8 N 7 47 W -11 , 31 0 15 S 53 20 E -11,48 0 18 N 0 7 W -11.42 0 12 S 8B 25 5 -11.56 0 12 N 63 £2 N -11.42 0 13 N 8 32 W -11.04 0 17 S 2 31 W -11.21 0 18 S 8 46 E -11.42 0 17 S 79 19 W -11.3'9 0 20 S 69 9 W -11.01 0 16 S 35 15 W -10.68 0 15 S 76 1~ E -10.96 0 2 5 14 18 21 24 26 27 37 N 64 52 5 -11.59 29 N 28 3 W -10.66 19 N 39 56 W -4.25 42 N 46 45 W 8.33 18 N 50 11 W 29.14 23 N 51 55 W 58.35 15 N 56 39 W 94,11 14 N 59 9 W 136,26 10 N 59 17 W 183.38 53 N 59 18 W 234.36 0.00 0.00 0.40 0.65 0.15 0.21 0.13 0.22 0.19 0.59 0.81 0.39 0.88 0.80 0.94 0.34 0.61 0.95 0.97 1.03 0.70 0.63 0.17 1.69 0.91 0.26 0.16 0.19 1.38 0.AD 0.50 3.90 3.60 5.02 4.62 3.49 3.47 2.02 1.31 1.51 PAGE 4 DATE OF SURVEY: 28-0CT-86 KELLY BUSHING ELEVATION: 117,00 FT ENGINEER: G, SARBER SUB-SEA DEPTH RECTANGULAR COORDINATES HORIZ, DEPARTURE NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET FEET FEET ,DEG MIN 0,00 N 0,00 E 0,00 N 0 0 E 0,00 N 0,00 E 0,00 N 90 0 Z 0,16 S 0,42 E 0,45 S 69 20 E 0,33 S 0,99 E 1,04 S 71 25 E 0,33 S 1,95 E 1,98 S 80 30 E 0,26 S 3,12 E 3,13 S 85 16 F 0.18 N 4.20 E 4,20 N 87 29 ,,_. 0.90 N 5.39 E 5.46 N 80 32 ~ 1.56 N 6.86 E 7,04 N 77 9 E 2.14 N 8.27 E 8,54 N 75 29 E 3.08, N 9.43 E 9'.92 N 71 55 E 3.51 N 10.07 E 10.67 N 70 46 E 3.62 N 10,66 E 11.26 N 71 13 E 3.93 N 11.47 E 12.13 N 71 4 E 3,65 N 12,50 E 13,02 N 73 42 E 3,31 N 13,44 E 13,84 N 76 8 E 2.74 N 13.91 ~ 14.18 N 78 51 E 2.70 N 14.38 E 14.64 N 79 21 E 2,54 N 14,35 E 14,57 N 79 57 E 2.73 N 14.65 E 14.90 N 79 26 E 2,70 N 14.56 E 14,81 N 79 29 E 3,05 N 14,92 E 15.23 N 78 26 E 3,15 N 14,82 E 15,15 N 78 0 E 3.40 N 14.52 E 14.91 N 76 49 E 3.41 N 14.71 E 15.10 N 76 57 E 2,82 N 14,63 E 14.90 N 79 5 E 2.48 N 14.41 E 14.62 N 80 13 ~ 2.38 N 13.92 E 14.12 N 50 1~ '~ 2,14 N 13,41 E 13,58 N .50 56 E 1.72 N 13,50 E 13,61 N 82 ~3 E 1.91 N 14.32 E 14.45 N 82 24 E 3.66 N 14.23 E 14.70 N 75 33 E 9,34 N 10,05 E 13,72 N 47 6 E 18,45 N 0,71 E 18,46 N 2 13 E 32,29 N 15,39 W 35,77 N 25 28 W 51,11 N 38,35 W 63,90 N 35 53 W 71.88 N 67.72 W 98.75 N 43 17 W 94,11 N 103,59 W 139.95 N 47 44 W 118.22 N 144.10 W 186.39 N 50 38 W 144.24 N 187.96 W 236.93 N 52 29 ~ ARCO ALASKA, INC. 27-7 KUPARUK NORTH SLOPE,ALASKA TR MEASURED VERT DEPTH DE 3.976.57 391 4052.76 401 4211.14 411 4331.7£ 421 4454.93 431 4580.4~ 441 4705.68 451 4830.31 461 4954.94 471 5085.05 481 5228.19 491 5382.11 501 5536.11 511 5689.14 521 5842.70 531 5994.28 541 6144.16 551 6292.86 561 6439.46 571 6584.75 581 COMPUTATION INTERPOLATED VA UE SUB-SEA !CAL VERTICAL PTH DEPTH COURS DEVIATION DEG MIN 7.00 3800.00 7.O0 3900.00 7.00 4000.00 7.00 4100.00 7.00 4200.00 7.00 4300.00 7.00 4400.00 7.00 4500.00 7.00 4600.00 7.00 4700.00 7.00 4800.00 7.00 4900.00 7.00 5000.00 7.00 5100.00 7.00 5200.00 7.00 5300.00 7.00 5400.00 7.00 5500.00 7.00 5600.00 7.00 5700.00 29 41 N 31 30 N 33 11 N 34 46 N 36 43 N 37 11 N 36 52 N 36 24 N 37 26 N 4.2 35 N 48 26 N 49 41 N 49 22 N 49 26 N 49 0 N 48 25 N 46 2 N 47 18 N 46 34 N 46 29 N LUE5 DATE: 19-NOV-B6 PAGE 5 6729.85 591 6874.70 601 6975.00 608 7.00 5800.00 7.00 5900.00 6.25 5969.25 DATE OF SURVEY: 28-0CT-86 .. KELLY BUSHING ELEVATION: 117.00 FT ENGINEER: G. SARBER FOR EVEN 100 FEET OF SUB-SEA DEPTH E ZIMUTH EG MIN 59 34 W 59 48 ~,J 59 47 W 59 24 W 59 10 W 59 0 W 58 51 W 58 27 W 58 0 W 55 28 W 54 25 W 56 53 W 58 10 W 60 41W 63 14 W 64 50 W 66 13 W 67 26 W 58 9 W 68 15 W 46 20 N 57 47 l.; 46 20 N 67 47 W 46 20 N 67 47 W VERTICAL SECTION FEET DOGLEG RECTANGULAR SEVERITY NORTH/SOUTH DEG/iO0 FEET COOR EAST FEE DINATES HORIZ. DEPARTURE /WEST DIST. AZIMUTH T FEET OEG MIN 289.15 1.78 172.13 N 348.29 1.67 201.94 N 411.62 1.27 233.77 N 478.97 1.52 267.87 N 550.90 1.59 304.60 N 626.71 0.52 343.58 N 702.06 0.41 382.49 N 776.39 0.15 421.17 N 250.68 2.69 460.18 N 933.56 4.55 506.28 N 1035.24 3.30 555.69 N 1151.79 0.61 531.19 N 1268.69 1.02 694.14 N 1384.46 2.22 753.39 N 1500.95 0.82 807.50 N 1614.71 1.08 857.55 N 1725.97 0.82 903.58 N 1835.45 1.42 946.93 N 1941.85 0.52 987.27 N 2046.33 1.42 1025.89 N 235. 286. 341. 399. 460. 526. 590. 654. 717. 786. 869. 966. 1065. 1165. 1268. 1370. 1472. 1573. 1672. 1770. 14 W 291.41 N 53 47 W 24 W 350.30 N 54 47 W O0 W 413.43 N 55 34 W 10 W 480.66 N 56 7 W 99 W 552.53 N 56 32 W 05 W 628.31 N 56 51 ~' 63 W 703.66 N 57 4 L 16 W 778.02 N 57 13 W 48 W 852.38 N 57 19 W 68 W 935.51 N 57 14 W 99 W 1037.73 N 55 58 W 93 W 1154.71 N 56 51 W 58 W 1271.~2 N 56 55 W 21 W 1387.55 N 57 6 W 40 W 1503.63 N 57 31 W 73 W 1616.88 N 5'7 58 W 44 W 1727.58 N 58 27 W 60 W 1836.54 N 58 57 W 90 W 1942.50 N 59 27 W 98 W 2046.66 'N 59 55 W 2150.69 2254.72 2326.77 0.00 1065.41 0.00 1105.00 0.00 1132.42 N 1868.40 W 2150.82 N 60 18 W N 1965.42 W 2254.75 N 60 39 W N 2032.60 W 2326'.77 N 60 52 W ARCO ALASKA, INC. 2T-? KUP.4RUK NORTH SLOPE,ALASKA MARKER TOP KUPARUK C BASE KUPARUK TOP KUPARUK A BASE KUPARUK PBTD TD COMPUTATION D4TE: 19-NOV-86 iNTERPOLATED'VALUES FOR CHOSEN HORIZONS MEASURED DEPTH BELOW KB FROM KB ORIGIN: TVD PAGE DATE OF SURVEY: 28-0CT-$6 KELLY BUSHING ELEVATION: 117.00 ENGINEER: G. SARBER 277 ESL, SUB-SEA 6521.00 5773.24 5656.24 6540.00 5785.16 5669.16 65~0.00 5786.i6 5669.I6 6738.00 5922.62 5805.62 6897.00 6032.40 5915.40 6975.00 6086.Z5 5969.25 556 SURFACE LOCATION A T FWL, SEC 1, TllN R3E UM RECTANGULAR COORdINATeS NORTH/SOUTH EAST/WEST 1008.93 N 1727.83 W 1013.97 N 1740.82 W 1013.97 N 1740.82 W 1067.63 N 1873.86 W 1111.10 N 1980.36 W 1132.42 N 20.32.60 W FT COMPUTATION DATE: 19-NOV-86 PAGE 7 ARCO ALASKA, INC. 2T-7 KUPARUK NORTH SLOPE,ALASkA TOP B,4SE TOP BASE PBTD TD MARKER KUPARUK C KUPARUK C KUPARUK A KUPARUK A -, ....... . ..... , ........ .--.. STRATIGRAPHIC MEASURED DEPTH BELDW KB 6521.00 6540.00 6540.00 6738.00 6897.00 6975.00 DATE OF SURVEY: 28-0CT-$6 KELLY BUSHING ELEVATION: 117.00 FT ENGINEER: G. SARBER ' FROM KB ORIGIN: 277 TVD SUB-SEA FSL, 556 FWL REC SURFACE LOCATION AT , SEC 1, TllN, REE, TANGULAR COORDINATES RTH/SOUTH EAST/WEST 5773.24 5786.16 5786.16 5922.62 6032.40 6086.25 5656.24 5669.15 5669.16 5805.62 5915.40 59,59.25 1008.93 N 1727.83 W 1013.97 N 1740.82 W 1013.97 N 1740,82 W 1067.63 N 1873.86 W 1111.10 N 1980.36 W 1132.42 N 2032.60 W ~J M FINAL MEASURED DEPTH 6975.00 WELL LOCATION TRUE VERTICAL DEPTH 6086.25 AT TD: SUB-SEA VERTICAL DEPTH 5969.25 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET OEG MiN 2326.77 N 60 52 SCHLUIdE}EROEiR B I RECT I ONAL SURVEY COMPANY ARCO ALASKA INC WELL 2T-? 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' ...~-~....~.-i-~..-4- -.L4.-..~.4-.- -~ ....... ., ........................................................................... ..., .................. ? ............................ ~ ...... ? ..................... , ~ ~ : : : ~ : : : : ; : : ; : : : : : : : : : , : : : : : i : : : : : : '~: : : : , : : : : : : : : ; : : ~ : : : : : : : · ~ : : ~ '"4'-'~'4'"'i"-I-'P'"~-4"-i';'"! i i i ! : ! i , ,.4-~....4,-4.1 ~ i i ..... ..:....4.-..4.--.4,1 i i i ...... 4...4-.i..'-.4! i i i ..... 4...4--~...%1 ! i i ...... 4,..4-,~....i--i i i i "4~-i"""L"4.1 i i ! ....... :,-~-4.-4...-~---4...-4,.-.4.---~.! i ! ! ! i i ! ..... 4'"":'"'4.'"~'"I'";'":'":'"'~'i i i ! ~ i ! i ....... 4..-.4.,..4.....~i: ~ i .... '~ ~'"';'"'~'": ~ i i; " i ;'' ~";'"'~'!: ~ ..... t "'4.' ~'"i ! i '! 9000 299, PROJECTION ON VERTICI21L PLRNE Z99. - I 19. SCRLED IN VERTICI:::IL OEP]'HS HORIZ SCALE = I/S00 IN/FT - STATE OF ALASKA ALAS, OIL AND GAS CONSERVATION COMI, SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate _~ Plugging ~ Perforate .'~ Pull tubing Alter Casing ~ Other '~ 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, lnc. RKB 117' Feet~j 3. Address 6. Unit or Property name P.0. Box 100360 Anchorage, AK 99510-0360 Kuparuk River Unit 4. Location of well at surface 277' FSL, 556' FWL, Sec. 1, T11N, R8E, UH At top of productive interval 1286' FSL, 1172' FEL, Sec. 2, T11N, R8E, UH At effective depth 1388' FSL, 1424' FEL, Sec. 2, T11N, R8E, UM At total depth 1409' FSL, 1477' FEL, Sec. 2, T11N, R8E, UM 7. Well number 2T-7 8. Approval number 7-35 9. APl number 50-- 103-20069 10. Pool Kuparuk River 0il Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 6975'MD 6086'TVD 6897'MD 6032'TVD feet feet feet feet Plugs (measured) Junk (measured) None None Casing Length Conductor 80' Surface 2739' Production 6419' Liner 747' Perforation depth: measured Size Cemented Measured depth 16" 245 sx CS II 110'MD 9-5/8" 750 sx AS III & 2772 'MD 285 sx Class G 7" 410 sx Class G & 6449'MD 200 sx AS I 5I, 6524 ' -6539 'MD Squeezed liner lap w/lO0 sx Class G 125 sx Class G 6228'o6975'MD 6571'-6613'MD True Vertical depth 110'TVD 2772 'TVD 5724'TVD 5573'-6086'TVD true vertical 5775'-5786'TVD 5807'-5836'TVD 12. 13. Tubing (size, grade and measured depth) 2-7/8", J-55 tbg w/tail ~ 6566' Packers and SSSV (type and measured depth) HB-1 pkr @ 6076', DB pkr ~ 6551', & TRDP-1A-SSA SSSV ~ 1786' Stimulation or cement squeeze summary See attached Addendum. Intervals treated (measured) Treatment description including volumes used and final pressure N/A Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14. Attachments (Addendum dated 01/29/87) Daily Report of Well Operations E~, Copies of Logs and Surveys Run the foregoing is true and correct to the best of my knowledge 15. I hereby certify that ~T V '-,' , -- ---- ,-'/ I Signed ~ ~..J~,/,,.~/ Form 10-404 Rev. 12-1-85 Title Associ ate Engineer Date (DANI) SW02/033 Submit in Duplicate ADDENDUM WELL: 7/31/86 1/17/87 2T-7 Arctic Pak w/200 sx AS I, followed by 53 bbls Arctic Pak. Stimulate Kuparuk "A" sand perfs 6571'-6613' per procedure dated 12/11/86 as follows: Stage #1: Stage #2a: Stage #2b: Stage #3: 37 bbls 150° diesel @ 1, 2200-1600 psi 35 bbls 50/50 IPA & diesel @ 2-1/4 BPM, 1600-2000 psi 90 bbls 50/50 IPA & diesel @ 1/2 BPM, 2000 - 1900 psi 35 bbls 100° diesel @ 1/2 BPM, 1900 psi Drilli~u~ervisor Date STATE OF ALASKA ALASK.. OIL AND GAS CONSERVATION COMb SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [-; Suspend ~ Operation Shutdown ~ Re-enter suspended well m_ Alter casing Time extension [] Change al3proved program~ Plugging '.~ Stimulate ~ Pull tubing - Amend order m Perforate - Other - · i 15o -- 2. Na~c~ OAPlearsa~, Inc Datum elevation (DF or KB) RKB 117' feet 6. Unit or Property' name 3. Ad~.es~. Box 100360 Anchorage, AK 99510-0360 Kuparuk River Unit , 4. Location of well at surface 7. Well number 277' FSL, 556' FWL, Sec. 1, TllN, R8E, UM 2T-7 At ~.O208~f, productive interval 8. Permit nUmber FSL, 1172' FEL, Sec. 2, TllN, R8E, UM 86-108 At ?§§~qiveF~[P,~h1424 '-"--' --'~--' FEL, Sec. 2 TllN, R8E, UM 9. APl number , 50- ].o3-2oo69 At~e~L, 1477' FEL, Sec. 2, TllN, R8E, UM 10. Pool Kdparuk River Oil Pool 11. Present well co'ndition summary Total depth: measured 6975 'ND feet Plugs (measured) None true vertical 6086 ' TVD feet Effective depth: measured 6897 'ND feet Junk (measured) None true vertical 6032'TVD feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 80' 16" 245 sx CS II llO'MD ll0'TVD Surface 2739' 9-5/8" 750 sx AS III & 2772'MD 2772'TVD 285 sx Class G Production 6419' 7" 410 sx Class G & 6449'MD 5724'TVD 200 sx AS I Squeezed liner lap w/lO0 sx Class G Liner 747' 5" 125 sx Class G 6228'-6975'MD 5573'-6086TM Perforation depth: measured 6524' - 6539'MD 6571' - 6613'ND true vertical 5775' - 5786'TVD 5807' - 5836'TVD Tubing (size, grade and measured depth) 2-7/8", 5-55, tbg w/tail @ 6566' Packers and SSSV (type and measured depth) - - HB-1 pkr @ 6076' DB pkr ~ 6551' TRDP-iA-SSA SSSV ¢ 1786' 12.Attachments Description summary of proposal,'',,'~ Detailed operations program , , 13. Estimated date for commencing operation ~ ~ Ii 1-19-87 .. ~ .... ~-, i'" ~ ~ ~', ~ '~.~,=L., ~ 14. If proposal was verbally approved ~.~,~ ~ ~-~ ~.%~ Name of approver gI'~l~.~ ~l~ Date approved , , , 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~~~ Title Associate Engineer Date /'./,~-~7 (./ Commission Use Only (JG) SA/212 · ,= Conditions of approval Notify commission_so representative_ may witness ! Approval No. :_--' Plug integrity BOP Test Location clearancel Approved by ~}' ~,[t:;~.~,i~ ~-, ~,,~ ~, ' Commissioner the commission Date ~-~/ Form 10-403 Rev 12-1-85 Submit in triplicate Summary of Proposal Well 2T-7 Stimulation ARCO Alaska, Inc. proposes to change the stimulation plans for Well 2T-7 from a fracture stimulation to stimulation by injection of a mixture of isopropyl alcohol and diesel. Because of the close spacing of the reservoir sands and faulting in the reservoir, fracturing has a high potential of causing communication between the A Sand and the C Sand. Plans are to treat the well with isopropyl alcohol as an alternate means of stimulation. JHC:sc:O059 ARCO Alaska, Inc. Post Office Box 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 DATE December 23, 1986 TRANSMITTAL # 5'861 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Open Hole. Final Logs (1.Lblueline unless specified otherwise) 2T~6 ~" DIL 8-21-86 1000-8206 D,, FDC Raw 8-21-86 7390-8181 'Cyberlook 8-21-86 7390-8181 2" FDC Porosity 8-21-86 7390-8181 ~5" FDC Porosity 8-21-86 7390-8181 ~-2" DIL 8-21-86 1000-8206 2T-7 "~2" FDC Porosity 8-26-86 6449-6934 x5" FDC Porosity 8-26-86 6449-6934 ~Cyberlook 8-26-86 6449-6934 '-2" FDC Raw 8-26-86 6449-6958 ~2" DIL 8-26-86 6449-6958 ~5" DIL 8-26-86 6449-6958 5" FDC Raw 8-26-86 6449-6934 Receipt Acknowledged: Distribution: NSK Drilling Vault (film) Rathmell D & M L. Johnston (vendor Package) ARCO Alllkl. Inc. is · Sul~$idiary of Atl&nlicRichlilldCompeny STATE OF ALASKA ALASKA ~_ AND GAS CONSERVATION COMMIL ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed· Operation shutdown ,~ Stimulate ~ Plugging -- Perforate -~ Pull tubing Alter Casing [] Other~ ComLplete 2. Name of Operator 5. Datum elevation (DF or KB) ARCO A]aska~ Inc RKB 117' Feet 3. Address 6. Unit or Property name P. O. Box 100360 Anchorage, AK 99510-0360 Kuparuk River Unit 4. Location of well at surface 7. Well number 277' FSL, 556' FWL, Sec. 1, TllN, RSE, UN ?T-7 At top of productive interval 8. Approval number 1286' FSL, 1172' FEL, Sec. 2, T11N, RSE, UM 298, 341~ & 423 . At effective depth .__ 9. APl number 1388' FSL, 1424' FEL, Sec. 2, T11N, R8E, UM 50-- 103-20069 At total depth 10. Pool 1409' FSL, 1477' FEL, Sec. 2, TllN, RSE, UM Kuparuk River 0il Pool 11. Present well condition summary Total depth: measured 6975 ' ND feet Plugs (measured) No ne true vertical feet 6086'TVD Effective depth: measured feet Junk (measured) true vertical 6897 'MD feet No ne 6032 ' TVD Casing Length Size Cemented Measured depth True Vertical depth Conductor 80' 16" 245 sx CS II 1lO'MD 110'TVD Surface 2739' 9-5/8" 750 sx AS Ill & 2772'MD 2772'TVD 285 sx Class G Production 6419' 7" 410 sx Class G & 6449'MD 5724'TVD 200 sx AS I Squeezed 1 iner lap w/lO0 sx Class G Liner 747' 5" 125 sx Class G 6228'-6975'MD 5573'-6086 Perforation depth: measured 6524' - 6539'MD 6571' - 6613'MD true vertical 5775' - 5786'TVD 5807' - 5836'TVD ~- , Tubing (size, grade and measured depth) ~" 2-7/8", J-55, tbg w/tail ~ 6566' '': Packers and SSSV (type and measured depth) · HB-1 pkr ~ 6076', DB pkr (~ 6551', TRDP-1A-SSA SSSV ~ 1786' ' ,...:.,r~,,;, .' ;, 12. Stimulation or cement squeeze summary ,': · N/ ::~'"':"::'.~" ''''~ I ntervaAIs treated (measured) '" '~,:, "<',~,',.'?.:,.,. · '.,-t~ ;'7~. -~.. Treatment description including volumes used and final pressure i 13. Representative Daily Average Production or Injection ,~[.~tj~ ~. , ~, ~ ~:. :., ~.., N/A OiI-Bbl Gas-Mcf Water-Bbl Casin s ~ , Prior to well operation !["~t-~ i'i~' ~._, Subsequent to operation ?~' , , 14. Attachments (Completion Wel 1 History) Daily Report of Well Operations ~ Copies of Logs and Surveys Run __..- 15.1 hereby certify that the foregoing is true and correct to the best of my knowledge ,'.~.~ .~-' &~~ Associate Engineer Signed Title Date . j iii..i.L.i i ...... .i . -,. TVD Form 10-404 Rev. 12-1-85 (DAM) ~wu/~zb Submit in Duplicate :.. ARCO 011 and Gas Company Well History - Initial Report- Daily Inatmctiona: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District . Field. :::J Kupa~Uk t~ver: i ~ : ~. 1.0/29186- 10/30/86 tCounty, parish or borough North Slope Borough Lease or Unit ADL 25569 Title Completion ISlate API 50-103-20069- Alaska IWell no. 21:-7 56.24%. The above i$ correct FOr form preparJ~l~nd-distributi~ see Procedure~Jll~nual, Section 10, Drilling, Pages ~ a~d 87~: 7!'::~ 6~75,-6228' C~~-~,drav:/do~mtst, rev circ, POOH. TIH v/3-1/8" b'~'~:: 5", tag wiper plug. Drl cmt 7":@-64~'~, 5" @ 6975~-6228~ 6725~, ~ C~T log 1Z.O ppg NaCl/~aS~ D~l cat f/6618~ to ~S~D @ 6725~, circ hole cln. Displ w~r w/12.0 brine, circ& filter brae, ?0OH. gU ~ " 7" @ 6~ ' 5" @ 6975~-6228' 6725~, PBTD Perf~g 11.9 ppg ~aCl/~aBr ~ CET & GCT; no sqz required. ~ke GR/JB m. Would ~':go into TOP. POOH. RU Schl & prepare to perf. I Date ] Title W/100 sx Cl "G" w/.85% D-60, .2% D-46 .& 5% KCI,..i~ff .t~a'l-' sqz 2150 psi @ 1/8 B~M. Rev out, POOE~~ TIH '~:§800', TIE: & drl cmt f/6015' to TOL ~ 6223', CBU. Tet' lnr lap -'~: "~O-[250-psi; OK. POOM. RIH w/R-3 pkr, set ~ 6177'. Diapl w/35 hbls wtr. ::~.:-.'~ sas? cu~X:_.}~ !;~;_:::~ ... :, . :. :' ,'.f..:, .,-.. :. . : PP~:.'~d~..~:f . . g'as--'-¢~~:~::/"::/~'~ :}~,'~.:~-?~::~:~:~- ~' }.:::~:' . i-'~:,:~.5:/:69~5: '622~<?:,: : ' ':::,:.~?-~':~S.L::~.;~ .... ::<;-~(-:.~c(::- ' '. ' -- 6223', ~s~-~r lap :o 1000 p~i; 0K~/:=.~.~, p~';" ~H~ ::.', ' '-.,. Pst, bled ~o 1250 pst-. gs~ IR, P00B:Eo ,59Z~~. "sq~ 1~ ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in btocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting cost center code District ICounty or Parish State Alaska I North Slope Borough Alaska Field ILease or Unit IWell no. Kuparuk River ADL 25569 2T-7 Auth. or W.O. no. ~Title AFE AK0740 I Completion Nordic 1 Operator ARCO Alaska, Inc. Spudded or W.O. begun IA.R.Co. Date Completion Date and depth as of 8:00 a.m. 10/31/86 11/01/86 th~ 11/03/86 ~Complete record for each day reported API 50-103-20069 W.I. rTotal number of wells (active or inactive) on this Icost center prior to plugging and 56.24% labandonment of this well I Hour Prior status if a W.O. 10/23/86 ! 1730 hrs. q 7" @ 644~', 5" @ 6975'-6228' 6725' PBTD, NU tree 11.9 ppg NaC1/NaBr Fin perf'g 6571'-6613', 6524'-6539' @ 6 SPF, 60° phasing perf'd twice to make 12 spf @ 120° phasing. RIH w/pkr, set RD WL. RU & rn 188 jts, 2-7/8", 6.5~/, J-55 EUE, AB-Mod, 8RD tbg & 12 jts, 2-3/8", 4.7~/, N-80 AB-Mod tbg w/SSSV @ 1786'~DB Pkr @ 6551', TT @ 6566'. Tst tbg to 2500 psi - ok. ND BO~E. NU tree. 7" @ 644~', 5" @ 6975'-6228' 6725' PBTD, RR Diesel NU & tst tree to 250/5000 psi. Pull tst plug. .Df~s~l well w/diesel. RR @ 1030 hrs, 10/31/86. " Old TD New TO 6725' PBTD Released rig Date 1030 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing Potential test data PB Depth Kind of rig 10/31/86 IType completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands Rotary Well no. ! Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected ~ ,.:. ~,, ,_~ ~ :,: .... :,'~. fr~ Ik ,t .~ ~ 1: ' For form prepa~ti~n and distribution, see Procedures"Manual, Section 10, Drilling, Pages 86 and 87. ARCO Alaska, inc. Post Office E 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 RE~JP~N TO: ARCO ALASKA, INC. ATTN: Kupar~k Records Clerk ATO 1119 P. O. Box 100360 .~_n cho r age AK 99510-0360 DATE 10-02-86 TRANSMITTAL # 5785 Transmitted herewith are the following items. Please acknowledge receipt and returD, one signed copy of this transmittal. OH LIS Tapes plus Listings-: Schl: One copy of each __~2T-7 08-26-86 Run ~:-~1 0097.0-6982.0,~3/~2'~--5--~/'/~-~/'/- 3K-i8 09-07-86 Run .~i~1 0993 0-9880 Receipt Acknowledged: S~ate oz AK '~ Am;h[]ra..qe Date: ARCO A;al~k~.. thc. ~$ ~ Su~$idi.lry of AllantlcRichhelclCompany STATE OF ALASKA ALASKA ,.,,L AND GAS CONSERVATION COMMIL _,ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon - Suspend -- Operation Shutdown '_~ Re-enter suspended well -- Alter casing J' Time extension ~ Change approved program ~' Plugging Z Stimulate Pull tubing Amend order-' Perforate'' Other 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. 117' RKB feet 3. Address 6. Unit or Property name P.' O. Box 100360 Anchorage~ AK 99510 K~nnr~k I~iv~.r Ilnit 4. Location of well at Surface 7. Well number 277'FSL, 556'FWL, Sec.1, T11N, R8E, UM 2T-7 At top of productive interval 8. Permit number 1278'FSL, 1246'FEL, Sec.2, T11N, R8E, UM (approx.) 86-108 At effective depth 9. APl number 1496'FSL, 1369'FEL, Sec.2, T11N, R8E, UN (approx.) 50-- 103-20069 10. Pool At t¢~¢~e~p/_t,h 1420, FEL, Sec.2, T11N, R8E, UM (approx.) Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured 6975 'MD feet Plugs (measured) None true vertical 6082 'TVD feet 6897 'MD None Effective depth: measured 6028 'TVD feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 80' 16" 245 sx CS II 1lO'MD 110'TVD Surface 2739' 9-5/8" 750 sx AS Ill & 2772'MD 2772'TVD 285 sx Class G Production 6419' 7" 410 sx Class G & 6449'MD 5719'TVD 200 sx AS I Liner 747' 5" 125 sx Class G 6228'-6975'MD 5571'-6082'TVD Perforation depth: measured None k E i::: E IV !) true vertical None SEP 2 5 198 Tubing (size, grade and measured depth) None Alaska Oil & Gas Cons. None AllCh0r3..r'! :~': Packers and SSSV (type and measured depth) 12.Attachments Description summary of proposal r~ Detailed operations program ~ BOP sketch ~ Well Hist°fY 13. Estimated date for commencing operation ' ~ ¢ ' .,, ;~ .~ ..? . 0ctober, 1986 ,~ ..;. 3 ;,. ~ 14. If proposal was verbally approved ~ ~' ! ~-'~"[]~ ~'ii''''' ii I'I'':!''!I~~ ~."-'- ~., , ~ ' "~' ~, '~ 'i ,, Name of approver Date ~b~rOv~e~l ~ ~I ~ ¢... 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~,~~., Title Associate Engineer Date ~.~¢~-~( Commission Use Only (DAN) 5A/094 Conditions of approval Notify commission so representative may witness I Approval No. ~ Plug integrity .~ BOP Test .~, Location clearance| ~Z¢'¢~.~ _ . , . . ..... -v~-~,.~~, Approved by ;7,:..: ..{;..~ i · j'~ Commissioner the commission Date ~,~. - ~.-, c',, I.., ,~,-, ', * ;,-, Form 10-403 Rev 12-1-85 S[ ,m n [ ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "initial Report" on the first Wednesday after a weii is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field ICounty. par:sn or borough North Slope Borough L ...... Unit ADL 25569 Tte Drill State Alaska Well no. 2T-7 Kuparuk River Auth. or W.O. no. AFE AK0740 Rowan #34 Operator ARCO Alaska, Inc. API 50-103-20069. ARCO W I. Prior s atus if a W.O. Spudded or W.O. begun Drill IDate IHour 8/23/86 Date and depth as of 8:00 a.m. 8/23/86 thru 8/25/86 8/26/86 8/27/86 8/28/86 Complete record for each day reported 0600 hrs. 7" @ 6449' 6748', (207'), Drlg Wt. 11.7, PV 24, YP 12, PH 9.5, WL 6.0, Sol 19 Accept rig @ 0600 hrs, 8/23/86. ND tree, NU & tst BOPE. TIH to FC @ 6364', drl FC, cmt & FS. Rm rathole f/6449'-6490', twisted off & BO, POOH. PU OS & TIH, engage fsh @ 771', POOH; full rec'y. TIH, rm 6449'-6551', circ. Conduct formation tst to 13.5 ppg EMW. Drl to 6748'. 7" @ 6449' 6975', (227'), Circ Wt. 11.7+, PV 15, YP 7, PH 8, WL 6.6, Sol 20 Drl to 6975', circ, 6 std short trip, TOH. RU Schl, att combo rn; hit bridge @ 6515', TOH. RIH w/DP, rm 6515'-6605', TIH to 6975' & circ. 7" @ 6449' 6975', (0'), Prep to rn lnr Wt. 11.7, PV 15, YP 8, PH 8, WL 5.0, Sol 20 Wrk pipe f/6555'-6750'; tight. TIH, spot diesel pill, TOH. RU Schl, rn DIL/GR/SP/SFL/FDC/CNL/CAL f/6966'-6449', RD Schl. TIH, circ 50 bbl diesel, att to TOH; tight, wrk to 6675', spot 50 bbls diesel pill, TOH. 7" @ 6449' 6975', (0'), ND BOPE Wt. 11.7+, PV 15, YP 8, PH 8, WL 5, Sol 20 Rn 20 its, 5", 18#/ft, S-140 HSFJ csg w/FC @ 6939', FS @ 6975' Cmt w/125 sx C1 "G" w/3% KC1, .9% D-127, .3% D-13 & .2% D-46. Displ using rig pmps, did not bump plug. RIH, spot 2000' diesel cap. ND BOPE. kE C E r/..i) SEP 2 5 19B ; Gas Cons, The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. 56.24% ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first W'ednesday after allowable has been assigned or well is Plugged. Abandoned. or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an olficia[ test is not required upon completion, report, compietion and representative res,' data in blocks provided. The "Final Report" form may be used for reeorting the entire operation if space is available. Alaska North Slope Borough Field ~tease or Unit Kuparuk River I ADL 25569 Auth. or W.O. no. ITitle AFE AK0740 I Drill Rowan #34 AP1 50-103-20069 cost center code Alaska JWell no. 2~-7 Operator ARCO Alaska, Inc. Spudded or W.O. begun Drill A.R.Co. W.I. 56.24% Date 8/23/86 ITota, number of wells (active or inactive)on cost center prior to plugging andpriorthis !abandonment of this well Hour status if a W.O. 0600 hrs. Date and depth as of 8:00 a.m. 8/29/86 Complete record for each day reported 5" @ 6973' 6975', (0'), RR Wt. 11.7+, PV 15, YP 8, PH 8, WL 5, Sol 20 ND BOPE, NU & tst adapter & master vlv. RR @ 0830 hrs, 8/28/86. SEP 2 5 Gas Cons. Old TO Nevi TD PB Depth 6975' TD 6897' PBTD Released rig Date Kind of rig 0830 hrs. 8/28/86 Rotary Classifications (oil. gas, etc.) Type completion (single. dual, etc.) Oil Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling. Pages 86 and 87. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI._ .~ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _~ Suspend - Operation Shutdown % Re-enter suspended well __- Alter casing Time extension _~ Change approved program ~ Plugging ~ Stimulate ~ Pull tubing ~ Amend order _-~ Perforate ' Other 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. 117' RKB feet 3. Address 6. Unit or Property name P. O. Box 100360 Anchorage, AK 99510 Kuparuk River Unit; 4. Location of well at surface 7. Well number 277'FSL, 556'FWL, Sec.1, TllN, RSE, UM 2T-7 At tod ofproductive interval 8. Permit number 1278'FSL, 1246'FEL, Sec.2, T11N, R8E, UM (approx.) 86-108 At elf:~ez~t~i~¢Ld~el~(~l~2'FEL, Sec.2, T11N, R8E, UM (approx.) 9. APl number 50- lo3-2oo69 At t~l./CF~h 1140' FEL, Sec 2, TllN, R8E, UM (approx.) 1~). Pool · Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured 6541 'MD feet Plugs (measured) None true vertical 5781, TVD feet 6364 ' MD None Effective depth: measured 5662'TVD feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 80' 16" 245 sx CS II 1lO'MD 110'TVD Surface 2739' 9-5/8" 750 sx AS Ill & 2772'MD 2772'TVD 285 sx Class G Production 6419' 7" 410 sx Class G & 6449'MD 5719'TVD 200 sx AS I Perforation depth: measured None,,,~ ii ":-:..i'''~P'/.~ ~ !~ ';~../:-!-!.~"' None true vertical /:.,i i, ': 'i :,.~ Tubing (size, grade and measured depth) None ~las!~.a 0ii .,:, ,-,.,., ;,:,:.. None A:::.!i:~'. Packers and SSSV (type and measured depth) 12.Attachments Description summary of proposal ,~ Detailed operations program .~ BOP sketch ,_ Well History, & Addendum (dated 8/6/86) ,¢~,,¢'% k ~.,~'.~,.~-~ ~:"~ 'i3, Estimated date for commencing operation .'i ;~ ,: ~ September, 1986 14. If proposal was verbally approved ~' :~ ;i .:; ";', ~ -~'~ii ~'~ ~.;;: '~ ",,;'.: ~i ~ ' ' .' '. ~: ~ '. ,: ,, . Name of approver D~ti~ )ippi;ove~ ;~ ~; '.:" ~ .... '-:, . 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~ .',~LL/)~t._.,- Title Associate Engineer Date ~/ Commission Use Only (DAM) SA/094 Conditions of approval Notify commission so representa!ive may witness I Approval ~ Plug integrity ~ BOP Test-~ Locatio.~ clearancel No. ,~. ( ~,~~~ byorderof Approved by Commissioner the commission Date Form 10-403 Rev'l -"~-8~' Sd , in triplicate ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Field Alaska ICounty, parish or borough North Slope Borough ILease or Unit ADL 25569 ITitle Drill IState Alaska Kuparuk River Well no. 2T-7 Auth. or W,O. no. AFF. AK0740 Rowan 34 Operator ARCO Alaska, Inc. API 50-103-20069 Spudded or W,O. begun IDate IHour Spudded 7/22/86 7/23/86 7/24/86 7/25/86 7/26/86 thru 7/28/86 7/29/86 Complete record for each day reported Date and depth as of 8:00 a.m. The above is correct Sign~_~.~_ ~ For form preparatj~and distribution...=--~ see Procedures Ik,f~ual, Section 10, ' 1800 hrs. ARCO W.I. Pr or status if a W.O. 56.24% 16" @ 110' 2380', (2275'), Drlg Wt. 9.8, PV 20, YP 19, PH 10, WL 10, Sol 11 Accept rig @ 1300 hfs, 7/22/86. NU diverter sys. 1800 hrs, 7/22/86. Drl 12¼" hole to 2380'. .Spud well @ 9-5/8" @ 2772' 2802', (422'), Tst BOPE Wt. 9.4, PV 13, YP 8, PH 8.0, WL 9.5, Sol 9 Drl 12¼" hole to 2802', short trip, CBU, TOH. RU & rn 69 jts, 9-5/8", 36#, J-55 BTC csg w/FC @ 2690', FS @ 2772'. Cmt 750 sx AS III & w/285 sx C1 "G". Displ using rig pmps, bump plug. ND diverter. Perform 110 sx AS I top job. NU & tst BOPE. 9-5/8" @ 2772' 3179', (377'), Drlg Wt. 9.6, PV 12, YP 8, PH 8.5, WL 8, Sol 6.5 TIH, tst csg to 2000 psi. DO cmt, flt equip & 10' new hole. Conduct formation tst to 12.7 ppg EMW. Slide f/2918'-3126', raise mud wt to 9.6 ppg, DD to 3179'. 9-5/8" @ 2772' 6018', (2839'), Drlg Wt. 9.9+, PV 15, YP 10, PH 9.0, WL 6.4, Sol 11 Raise mud wt to 9.9 ppg, slide 3179'-3621', rotary drl 8½" hole to 4965', turbine drl to 6018'. 3051', 3.4°, N38.1W, 3051TVD, -7 VS, .20N, 8.31E 3444', 19°, N52.8W, 3890', 28°, N54.4W, 4328', 34.6°, N60.2W, 4925', 36.6°, N55.4W, 5474', 49.7°, N53.5W, 5755', 49.6°, N57.9W, 3435 TVD, +66 VS, 49N, 48W 3842 TVD, 248 VS, 150N, 200W 4214 TVD, 477 VS, 273N, 394W 4693 TVD, 832 VS, 469N, 691W 5077 TVD, 1219 VS, 702N, 1005W 5259 TVD, 1433 VS, 822N, 1182W 9-5/8" @ 2772' 6541', (523'), Circ Wt. 11.2, PV 16, YP 7, PH 8.5, WL 8.4, Sol 15 Drl to 6449~ Conduct formation tst to 12.0 ppg EMW. Drl 6541', gas cut mud 10.1 ppg in, 9.7 ppg out. SI well, raise mud wt to 11.6+ ppg. Open well, circ 11.2 ppg mud. 6160', 48.7°, N63.9W, 5525 TVD, 1737 VS, 981N, 1443W Drilling Supervisor Drilling, Pages 86 and 87. · ARCO Oil and Gas Company Oaily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed, Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form· 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday ol~ the week in which oil string is set. Submit weekly for workovers and following setting of oil strin§ until completion. District Field Alaska County or Parish IState I North Slope Borough I Lease or Un t 25569 Complete record for each day while drilling or workover in progress Alaska Kuparuk River Date and depth as of 8:00 a.m. 7/30/86 7/31/86 8/01/86 Well no. 2T-7 9-5/8" @ 2772' 6541', (0'), Build mud vol Wt. 11.5, PV 25, YP 17, PH 8.5, WL 6.8, Sol 11 Circ 11.2 ppg mud in, 10.5 ppg out. Circ 11.6 ppg mud on choke; lost rtns @ 3800'-4400' MD. Open & monitor well. Build mud vol. (Lost total of 128 bbls.) 9-5/8" @ 2772' 6541', (0'), Rn'g 7" Wt. 11.2, PV 11, YP 9, PH 8.5, WL 11.2, Sol 10 Spot 14.0 ppg mud f/6541'-4546', POOH to 4500', C&C to 11.2 ppg. POOH, LD DP. RU & begin rn'g 7" csg. 7" @ 6449' 6541', (0'), Prep to displ w/diesel cap Wt. 11.2, PV 13, YP 10, PH 8.5, WL 11.2, Sol 10 Rn 158 jts, 7", 26#, J-55 BTC csg w/FC @ 6364', FS @ 6449'. Cmt w/185 sx 50/50 Healey Flyash C1 "G" w/4% D-30, .2% D-46 & .5% D-65, followed by 225 sx C1 "G" w/3% gC1, .9% D-127, .3% D-13 & .2% D-46. Displ using rig pmps; no rtns. Bump plug w/3500 psi; well flowing. SI well. Arctic Pak w/200 sx AS I & 53 bbls Arctic Pak. WOC. ND BOPE. Instl packoff & tst to 3000 psi. NU BOPE & prep to spot diesel cap. For form prep~a'F~n an d-'~ist ri b q,jj.O'~ see Procedurd.s.J~lanual Section 10, Drilling, Pages 86 and 87 Date JTitle Drilling Supervisor ARCO Oil and Gas Company Daily We,i History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District County or Parish Alaska Lease Field or Unit Kuparuk River Auth. or W.O. no. IT t e I AFE AK0740 North Slope Borough State ADL 25569 Drill Alaska Well no. 2T-7 Rowan 34 Operator ARCO Alaska, Inc. API 50-103-20069 A.R.Co. W.I. 56.24% Spudded or W.O. begun Date Spudded 7/22/86 Date and depth Complete record for each day reported as of 8:00 a.m. I New TO 1030 hrs, IDate Old TD 8/02/86 Released rig 7" @ 6449' 6541', (0'), RR RR @ 1030 hrs, 8/1/86. Classifications (oil, gas, etc.) Oil IPB Depth 8/1/86I iKind of rig Type completion (single, dual, etc.) Single I otal number of wells (active or inactive) on this ost center prior to plugging and I bandonment of this well our I Prlor status if a W,O. I 1800 hrs. Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Rotary Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The abo~ correct For form pre--nd distributio ,~ IDate ,~/~ ~ ITitle see Procedures Manual, Section 10, Drilling; Pages 86 and 87. ADDENDUM WELL: 7/31/86 2T-7 Arctic Pak w/200 sx AS I, followed by 53 bbls Arctic Pak. STATE OF ALASKA ALASh,,~ OIL AND GAS CONSERVATION COMi,,,dSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~ Operation Shutdown r~ Re-enter suspended well -- Alter casing L~ Time extension ~ Change approved program ~ Plugging ~ Stimulate :- Pull tubing ~ Amend order ~-- Perforate -- Other 2. Name of Operator ARCO Alaska, Inc. -- . 3. Address 6. P. 0. Box 100360 Anchorages AK 99510 4. Location of well at surface 7. 277'FSL, 556'FWL, Sec.1, TllN, RSE, UM At top of productive interval 8. ---- At effective depth At total depth ---- Plugs (measured) 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size Conductor 80' 16" Surface 2739' 9-5/8" _. Perforation depth: measured true vertical Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) Datum elevation (DF or KB) 117'RKB, 82' PAD Unit or Property name Kuparuk River Unit Well number 2T-7 Permit number 86-108 9. APl number 50-- 103-20069 10. Pool kuparuk River Oil Pool feet feet feet feet Junk (measured) Cemented 200 cf 750 sx AS III & 285 sx Class G & 100 sx AS I None 12.Attac h ments Description summary of proposal None 13. Estimated date for commencing operation July 31, 1986 14. If proposal was verbally approved Name of approver Lonnie Smith Measured depth llS'MD 2772'MD True Vertical depth 115'TVD 2772'TVD feet RECEIVED AUG- 1 1986 Alaska 011 & Gas Cons. Commission Anchorage . Detailed operations progr~!~ Date approved 7/30/86 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~'b~ /~~t.., Title Ass°clare Engineer Commission Use Only (LWK) Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance ,~.;::~;~.: :..,-,--,~-:.. ... Commissioner Date '7'Z/-~G SA/089 J Approval No. ~:~ ~O,c/ by order of the commission Date '~/-~-'~:~ Conditions of approval Approved by Form 10-403 Rev 12-1-85 Submit in triplicate 2T-7 APPLICATION FOR SUNDRY APPROVALS SUMMARY OF PROPOSAL Due to lost circulation zone encountered above the Kuparuk Sand, ARCO Alaska, Inc.~ proposes to: 1. Drill 8-1/2" hole to 6450'. 2. Run and cement 7" casing at 6450' with 185 sx 50/50 Poz Lead Slurry followed by 225 sx Class G tail slurry. Drill 6-1/8" hole to original planned TD ~ 6995'MD. 4. Run and cement 5", 18.0#, S-140, SFJ production liner from 6250' - 6995'MD with 100 sx Class "G" cement. Complete well as per drilling permit. SA/O89a:tw 07/31/86 RECEIVED AUG- 1 1986 Alaska 011 & Gas Cons. Commission Anchorage jUne 5, 1986 Mr. J. B. Kewin Regional. Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Telecopy: (907) 276-7542 Re: Kuparuk River Unit 2T-7 ARCO Alaska, Inc. Permit No. 86-108 Sur. Loc. 277'-FSL, 556'~7L, Sec. 1, TllN, RSE, ~,~. Btmhole Loc 1430'~SL 1519'FEL, Sec 2, TllN, RSE, ~ Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional pe_rmits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled, g~ere a diverter system is required, please also notify this office 24 hours prior to commencing ~quipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Very. truty~-yo., u-~-s, C. V. Chatterton: Chaiman of ~laska 0~1 and Gas Conservation ComSssion BY O~DER OF THE COmmISSION dlf Enc io sure Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery STATE OF ALASKA ALASKA ~_ .,.. AND GAS CONSERVATION CO,,~MISSION PERMIT TO DRILL 20 AAC 25.005 I la. Type of work Drill ,~ Redrill ~'1 lb. Type of well. Exploratory ~ Stratigraphic Test ~..Development Oil Re-Entry Fi Deepen©1 Service [] Developement Gas ~ Single Zone ~ Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 117', PAD 82' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Po( P.O. Box 100360 Anchorage, AK 99510 ADL 25569 ALK 2667 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 277'FSL, 556'FWL, Sec.1, T11N, R8E, UN iKuparuk River Unit Statewide At top of productive interval 8. Well nu .tuber Number 1278'FSL, 1246'FEL, Sec.2, T11N, R8E, UM 2T-7 #8088-26-27 At total depth 9. Approximate spud date Amount 1430'FSL, 1519'FEL, Sec.2, TllN, R8E, UM 07/01/86 $500¢000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 6995 ' ND 3761 ' ~ TB feet gT-8 2s,~ surface feet 2560 f6081 'TVD] feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 2960 feet Maximum hole angle 45 0 Maximum surface 1 665 psig At total depth CVD) 3321 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5~ H-40 Weld 80' 35' 35' 115' 115' ~200 cf 12~" 9-5/8" 36.0¢ J-55 BTC 2776' 35' 35' 2811 ' 2811 ' 670 sx AS I I I & HF-ER 285 sx Class G blend 8~" 7" 26.0¢ J-55 BTC 6961 ' 34' 34' 6995' 6081 ' 200 sx Class G (minimum HF-ER' TOC 500' above top of 19. To be completed for Redrill, Re-entry, and Deepen Operations. Kuparuk. Present well condition summary · .., ' i,-- ,"' ~ Total depth: measured feet Plugs (measured) ..... ,,~, .... ; ;~ ~, ~ ~ true vertical feet .~ ~ .~,'~ ~ Effective depth: measured feet Junk (measured) ~, ~'. :' :;~ '~ Casing Length Size Cemented Measur ~ Structural Conductor Surface ?'~ ¢' '? : ~ '¢ Intermediate Production ~,,~hw ~', Liner Perforation depth: measured ~.:,~sks. CJI b 6;;;:s Cons. true vertical ........ 20. Attachments Filing fee ~ Property plat ~ BOP Sketch ~ DiverterSketch ~ Drilling program ~ Drilling fluid program ~ Time vs depth plot ~ Refraction analysis ~ Seabed report ~ 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge . Signed % S ¢~ ~ r,~ ~o Title Regional D rilli n g Engineer Date remission Use Only PD/PD272 Permit ~umber ~t c~ ~ 50--/c,~ ~o~ 06/05/86 for other requiremeats Conditions of approval Samplos roquirod ~ Yes ~ ~o Mud Io~ roquirod ~ Yes ~ ~o ~ydro~en sulfide measures ~ Yes ~ ~o Directional survey required '~ Yes C ~o Othor: .... by orOer of Approvedby~,[, ~~ Commissioner the commission Date Form 10-401 Rev. 12-1-85 Sub4~ n triplicate i '1r~i6~771 _ . _ FSL. I 9' 000 .. ,. KUPRRUK R I VER UN I T 20" D I VERTER SCHEMAT I C DESCR ! PT ! ON 1. 16" CONDUCTOR. 2. TANKO STARTER HEAD. 3. TANKO SAVER SUB. 4. TANKO LONER QUICK-CONNECT ASSY. S. TANKO UPPER QUICK-CONNECT ASSY. 6. 20" 2000 PSI DRILLING SPOOL N/lO" OUTLETS. 7. 10" HCR BALL VALVES H/lO" OIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DO~IND DIVERSION. 8. 20" 2000 PSI ANNULAR PREVENTER. 7 6, 7 ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20 AAC2S. 035 (b) . MA I NTENANCE & OPERAT I ON 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. 2. CLOSE ANNULAR PREVENTER AND BLON AIR THROUGH BI VERTER L I NES EVERY 12 HOURS. 3. CLOSE ANNL~AR PREVENTER IN THE EVENT THAT AN INFLUX OF NELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOhlNW I ND 01VERS I ON. DO NOT SHUT IN NELL UNDER ANY C I RCUMSTANCES. < < mi. DIAGRAM #l 1~-5/~" ~300 PSI ~S~RA BOP STACX I. 16' - 2cx30 PSI TAN<~ STARTING i-F_AD I1' - ~ PSI CASING HEAD 4. 1~8" - ~ ~I PI~ ~ 5. 1~8" - ~ ~I ~I~I~ ~ W/~ ~ KI~ LI~ ~. I~" - ~ ~I ~E ~ W/PI~ ~ ~ T~, 7. 1~8' - ~ ~I ~ AC~TCR CAPACITY TEST I. Q..ECX AN3 FILL A~TCR RESE3~OIR TO PRO=ER LEVEL WITH ~IC FLUID. ~ THAT ACO. MJLATCR PRE~ IS ~ PSI 3. CI~.qERVE TIhI[, TI..EN CL0~E ALL UNZTS SIMJLTAhECIJSLY ALL LINITS ~ CLOSED WITH CHAROING PUN~ CFF. 4. RE~ CIN NADC RE~, T1-E A~ABI_E LONER LIMIT IS 45 SE~ CI.C~ING TINE AN~ 12_CW)_ PSI RE)4AINING PRF, SSU~. -" L I -" 4 2 t I:$-~0= S0P STACK TI~'T I. FILL BCP STACK AI~ CH01~ MANIFOLD WITH ARCTIC DIESEL. 2. O-ECK THAT ALL LOCK D0~ ,~ IN V~EI. Lt~ ERE F'LII~Y RETRACTED. SF. AT TEST PLUG IN V'M~).LJ-E=AD WITH RLI~INO JT ~ ~ IN LCX::XI::OA~ SCREWS. LI~ YALVES ~ TO ~ STACK. ALL 4. ~ Le TO 250...1~4~ F'CR ~0 M~N. IN- L. It4~ VALVES. CL__C~_ TC:P PIPE RAMS AhD HCR VALVES 04 KILL Ah~ C~ LI~ 6. TEST TO 250 PSI ~ ~AS IN STEP 4. T. C~IhUE TESTI~K~ ALL ~ZAL-~S-,, LI~.~, AhD C~S WITH A 2,50 P~! LC~ Ah~ 3(X)O PSI HIOH. TEST AS IN ST~ 4. DO NOT ~ T~qT ANY C~ THAT NOT A FULL CLOSING PC~ITIYE ~ C}~399E. FL~I~I4 TE~T C]~5 Tl~T DO hE~T FULLY 8. (~ TC~ PIPE RANI~ A~ C~__r~E 8OTTC~ PIPE R~. TEST 80TTC~ PIPE RA~ TO ~ PSI Ai~ ~ PSI. I0. CI.O~ BLIh~ RAMS Ah~ TEST TO 7_50 PSI Ah~ PSI. ~ANIFOL~ AhD LI~ES A~ FLA. L CF h~INO FLUID. SET ALL VALVES IN 0RILLIh~ POSITIC~. 12.' TEST STAh~IPE VALVES, K?lLY, KELLY CO~S, C~ILL PIPE ~,~ETY VALVE. AhD IN~I~E 8~ TO 8.90 PSI ~000 PS!. ~ = 13,..REC~ TEST I~C~;~AT!04 04 BLC;40UT P~~ TEST ,~-~ ? ~ ~ · FC~, SION, Ah~'~E~ TO Q~ILLINO SUP~ISC~. 5 i 0084001 ~EV. 2 MAY I5, 19~-g GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1. Move in rig. 2. Install Tankco diverter system. 3. Drill 12¼" hole to 9-5/8" surface casing point according to directional plan. 4. Run and cement 9-5/8" casing. 5. Install and test blow out preventer. Test casing to 2000 psig. 6. Drill out cement and 10' new hole. Perform leakoff test. -7. Drill 8½" hole to logging point according to directional plan. 8. Run open hole logs. 9. Continue drilling 8½" hole to provide 100' between plug back total depth and bottom of Kuparuk sands. 10. Run and cement 7" casing. Pressure test to 3500 psig. 11. Downsqueeze Arctic Pack and cement in 7" x 9-5/8" annulus. 12. Nipple down blow out preventer and install temporary Xmas tree. 13. Secure well and release rig. 14. Run cased hole logs. 15. Move in workover rig. Nipple up blow out preventer. 16. Pick up 7" casing scraper and tubing, trip in hole to plug back total depth. Circulate hole with clean brine and trip out of hole standing tubing back. 17. Perforate and run completion assembly, set and test packer. 18. Nipple down blow out preventer and install Xmas tree. 19. Change over to diesel. 20. Flow well to tanks. Shut in. 21. Secure well and release rig. 22. Fracture stimulate. --~ DEC-?ASSERI SHAL'E SHAKERS HUD CLEANER STIR ~. MUD CLEANER STIR STIR LWK4/ih TYPICAL HUD SYSTEH SCHEHATIC CONFiD NI'IAL DRILLING FLUID PROGRAM Spud to 9-5/8" Surface Casing Density 9.6-9.8 PV 15-30 Drill out to Weight U~ 8.7-9.2 5-15 YP 20-40 8-12 Viscosity 50-100 Initial Gel 5-15 10 Minute Gel 15-30 Filtrate API 20 pH 9-10 % Solids 10± 35-40 2-4 4-8 10-20 9.5-10.5 4-7 Weight Up to TD 10.3 9-13 8-12 35 -45 3-5 5-12 9.5-10.5 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW (Kuparuk average) and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. LWK5 / ih ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 31, 1986 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - 2T Pad (Wells 2 - 17) Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw If GRU13/L44 Enclosure RF_.C rED FEB 0 5 Alaska Oil & G;:s Con.. u.~:,. ..... ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany i ~, i ii i i m im · I I I I .. , ...... .~_ . , · k : ' - 17, . LOCATED IN PROTRACTED '' LOCATED IN pROTRACTED SEC. !, TIIN,RBE, U.M. SEC. I, TIIN, RBE, U.M. Z- Y = 5,970,38~.43 LAT. 70~9'~9.1287'' 10 - Y : 5,970,132.65 LAT. 70~9'46-6719" X = 498,944.93 LONG. 150~00' 30.807'' X = 498,945.27 LONG. 150000' 30,796" 40Z' FSL, 556' FWL OG = 77' PAD = 81.5 152'FSL, 556' F~L 0G = 76.0 PAD = 81.7 3 - Y = 5,970,357.4Z ~T. 70~I9'48.8828'' 11 = Y = 5,970,107.7~ LAT. 70°~9'46.4Z67'' X = 498,944.9~ LONG. 150000"30. 808'' X = 498,945.10 LONG. 150°00' 30.801" 377' FSL, 556' FWL 0G = 77' PAD = 8~.5 127' FSL, 556' F~L 0G = 75.9 PAD : 8].7 4 - Y: 5,970,332.46 ~,'"~. 70019'~.6372" 1Z - Y = 5,970,082.58 LAT. 70°19'46.1794" ~ , x = 498,944.84 LONG.150o00'30.809" o x = 498,944.98 LON~.iS0°0030.804" 352" FSL, 556' F~L 0G = 77' PAD = 81.6 '~ 102' FSL, 556' F~L 0G = 75.7 PAD = 81.7 5- Y = 5,970,307.52 LAT. 70°~9'48.3919'' ~ 13- Y = 5,970,057.59 LAT. 70°~9'45.9336" X = ~98,944. .91 LONG.150°00'30.808'' ~ ~ X77, = FSL,498'945'08556' F~L 0GLONG'IS0°00'30'801' = 75.5 PAD = 8Z 6 327' FSL, 556' F~L 0G = 77' PAD = 81.6 ~O ~ ' 6 - Y = 5,970,282.50 LAT. 70°19'48.1459" ~ ~ 14 - Y = 5,970,03260 LAT 70019'45.6879" X : 498,944.95 LONB.150000 ' 30. 806" ~ C> cg¢> ' ' ~ ~ ~> X : 498,944.9~ LONG.150°00'30,806" 302' FSL, 556' FWL 0G = 77' PAD = 81.7 __ ~ ~ ~ 52' FSL, 556' FHL 0G = 75.3 PAD : 81.7 co ~ 15 - Y = 5,970,007.69 LAT. 70°19'45.4428'' 7 - Y = 5,970,257.54 LAT. 70019'47.9003" ~ 0 ~ ~ X 498,944.93 LONG.150~O0'30.806'' X = 498,944.95 LONG.150°O0' 30-806" ~ ~ 27' FSL 556' FWL OG = 75 2 PAD = B1.6 277' FSL, 556' FWL OG = 77' PAD : 81.6 ~ , · 8 - Y = 5,970,232.63 LAT. 70019'47.6553" .~ 16 - Y = 5,969,982.85 LAT. 70°19'45.1985'' X : 498,944.96 LONG. 150000, 30.806" ~ ~ ~ X = 498,944.88 LONG. 150000, 30.807" 252' FSL, 556' FWL OG = 76.9 PAD = 8!.6 ~ 2' FSL, 556' FWL OG = 75.1 PAD = 81.7 ~> LOCATED IN PROTRACTED 9 - Y = 5,970.207.62 LAT. 70019'47.4093" X = 498,945.01 LONG. !50o00' 30. 804" ~ SEC.12, TI I N~ RBE~ U.M. 227' FSL, 556' FWL 0G = 76.3 PAD = 81.6 17 - Y = 5,969,957.72 LAT. 70°~9'4a.95~4'' X = 498,944.94 LONG. 150000' 30. 805" 23' FNL, 556' FWL 0G = 75.0 PAD = 8~.6 I. ALL COORDINATES ARE A.S.R~ZONEA. :,~, '~ ..... 2. SECTION LINE DISTANCES ARE TRUE. ~ ~ ~ ~. HORIZ; POSITIONS BASED ON TEME MON~ 2T- EAST, 2T- WEJ~T'~'~;~..~M~'L[ :~ D & ASSOC. 4. VERT. POSITIONS BASED ON TBM's 2T-6 ~ NIg+T5, EI1+52 PER F.R.B. B ASSOC. 5.0. G. ELEVATIONS INTERPOLATED FROM S/C DRAWING CED-RIXX-5 m m m j CERTIFICATE OF SURVEYOR: i ~EREBY CERTIFY THAT I AM PROPERLY _ su~,~ ,~ ~ s~ o~ ~s~ ~ ~ , ~ , THIS PL~T REPRESENTS ~ LOC~TION SURVEY I ~ ~E CO~T DRAWN WM U~ILL ~1/~ ~/ UUI~MUU/U~ ~ ~~'="UU"" .... ~'~LD~C~[~s,~ ~,.,.,sz,. AS- BUILT. LOCATIONS t,.iF~.> ~ ' .%-'-./7-/~..._~...G~ ~' ' ?~ ......................]i~w~..o. ,SK .~-~ Arctic Boulevard, Suite 201, Anchorage, Alaska ~9503 IIS~LE N.T.S. JIJOS ~- . i i i ii i i i i i (2) Loc (1,4 thru 22) (5) BOPE (23 th{'~ ~ (29 thru 31) (6) Add: Geology.~ Engin_ee ring: JAL. rev: 04/03/86 6.011 :. 2 Is well t° be located in a"defined pool .i..~. ..... .3~ Is well located proper distance from'property line [~ . 4. Is well located proper distance from other wells ........ 5. Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is Wellbore plat included . 7. Is OperatOr the only affected party ........ 8. Can permit be approved before ten-day wait .11~1~11]1.'"' · 12. 13. 14. 15. 16. 17. 18. 19 21 22. 23 25 26. 27. 28. For. 29. 30. 31.' 32. ee··e·ee·e ee·eeeeeee NO REMARKS Does operator have a bOnd in force .................................. ~ Is a conservation order needed . ' eeee·eee®eeee·eeee·eeee·eeeeeeeeeeeeee ,. Is administrative approval needed ................................... Is the lease number appropriate . . ' ........... ~ Is conductor tring provided Will surface casing protect fresh water zones ....................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ........... Is old wellbore abandonment procedure included on 10-403 [ .......... Is adequate wellbore separatioN proposed eeeeeeeee·leeleeeeeeeeee·eee Is a diverter system required ............................ IS the drilling fluid program schematic and lis~ of'~i;~ent ~d~q~ate Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~dDd) psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. exploratory and Stratigraphic wellsi Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are~survey results of seabed conditions presented Additional requirements ............................................. .] POOL INITIAL CLASS STATUS GEO. AREA UNIT NO. ON/OFF SHORE Additional Remarks: 0 HO 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. LZS TAPE VEEi'FZCATZ~]N L?STZ'NG .VP OlO.M02 VERIFiCATIC~ LISTING P.aGE i REEL HEADER '".,..,. ;ERVlCE NA~vIE :EDIT }ATE :86/0~/!2 )~IGIN : ',EEL NAME :14,2673 ';ONTINUATION ~ ~REV!OUS REEL : 'OMMENTS : LIBRARY T~P~ :iLE NAME :EDIT ~ERV!CE NAME : /ERSiON ~ : )~TE : 4AXiMU~ LENGTH : =iLE TYPE P~EVTGUS =ILE : . O0 ~ 1024 i:;:~ IN~-CR)~T!ON RErCRCS ...... 'qNEM CiDNTENTS UNIT TYPE CATE SIZ= CGDE 'N : ARC'3 AL,~SKA, iNC. GO0 000 015 055 NN : 2T-7 000 0,30 004 085 ;N : KU~&RUK RIVER GO0 003 0'14 065 ~NG: SE 000 $00 002 055 TOWN: lin OOO OOO 004 065 £~CT: i O00 900 002 055 CCUN: N'2iT~ SLOP5 OOO 000 012 065 STaI: ~LASKa 000 000 006 055 CT~Y: USa 000 000 00~ 065 MN5M CQNTSNT$ UNIT TYP5 .VP CiO.M02 VEqlFiC,'~Ti!2N LISTi~,~'G PAGE 2 : S CHLU~BFIR GE 2 : AL,a, SKA' CCMDIJ'TZNG CENTFiR ';'~: 'OMPANY = ARC2 ~L&SK, A INC ;ELL = 2T-7 :iELD = K.U P.A~UK 'OUNTY = NORT~ SLOPE 80ROUGH ;TATE = ALASKA )OB NUMBER AT ACC: 71699 IUN #ONE, DATE LOGGFID: Z5 ~AUG 86 .DP: T HALSTEAD ]ASING = 6.i25" $ 6449' - 6IT SIZE : 6.125" TO 6975' "YPE 'FLUID = ~EI,SHT~O )EHSITY = 11.6 L~/G RM = .2.Z90 ~ 62 DF IISCDSITY : 35.0 S RMF : 1.~60 ~' 58 DF ~H ': 8.0 RMC = 2.920 ~ 55 DF :LUID LDSS = 5.6 C3 RM AT 5HT = 1.053 ,S 143 qATRiX SANDSTONE ,.., .............. .......... T~;S e:T~ ~S ~',~T S:~:~ n:PTH SH~FT~C- ~V~L:Y~ ....... ~;eL9 P~;~TS, ......................... ...... .VD 010.HO2 VERIFICATION L!ST!NS P,~GE 3 SCHLUMBERGER LOGS DUAL ZNDUCTZON SPH DATA FORMATION 0 =NSZTY ..... COMP,.cNSAT_~D NEUTRO D~TA ~VAI,L~,L GIMi"4~ R~Y iN C~SIN OfiTA ~VAiL~BL INCLUDED W~TH THIS M,~GN~T~C TAPE: 5RIC&LLY F~CUSED LOG (,GZL) 5958' 'TO ~&9' COMPENS.&T.EO LOG (FDN) N LOG (FDN) i~;:: DST.q FORMAT :NTRY' BLOCKS R E G 0 'R D-,--,- 'TYPE !6 0 .i,A T UM SPECIFIC~,TION '4NE~4 S=RVIC'= SE;TVTCE )EPT SFLU 0IL ZLD C, IL rLM OiL SP OIL ~LOCKS UNIT FT C a M M V 'AP Z LOG O0 O0 O0 O0 00 SiZE 1 R E P R CODE '"' NT R Y 66 0 66 73 60 6.5 · 66 55 TYPE CL&SS >1,~' NI3 000 '00 O 0 ~ i ZPg Oi 0 0 4 i !20 46 0 0 4 1 120 44 J 0 4 l '] 10 '~,~ i ~ ,~.~ 4 ! REPR CCDE 68 68 68 PROCESS (OCT,~L) 00000000000000 O000OO00000000 00000000000000 OO300000OO0000 ,'~,jOOOOO,~OnO,300~, ~ _VP 0!0.~t02 VERi'FIC;~TiON LISTING P~&GE 4 )EPT 5982.0,300 SFLU $P -55.7158 qHOB 2 .'7422 ORH3 ~PHI -1.7579 NCNL 33 246 9 125 ]EPT 6900.000:0 SFLU S? -55.0000 GR ~HD8 2.4453 DRY'3 ~PHI 31.7871 NCNL DEPT 5800.0000 SFLU SP -51.0313 GR q dS,,B 2.4063 2 R~t'3 qPHi 40.2532 NCNL 3EPT 5700.0000 SFLU SP -5.2.7500 GR RHO8 2.2813 JR,dO ~PdI 30.4-199 NCNL 9 238 3EPT 6600.0003 S;LU S~ -55.5000 GR 'qW35 2.2227 DRHS %PHI £S.1733 2 5 D£PT 6500.0000 SFLU SP -5'3.3125 G~ RhC5 2.1953 Cqd2 ',l~ri 47.2655 NCNL 3 !0 Oi 0 0 310 Ol 0 0 230 Ol 0 0 350 ,02 0 0 420 O1 0 0 000 O0 0 0 890 O0 0 0 330 31 O 0 33 O :30 0 0 31 O O1 0 0 3EPT 5~OO.OOCO SFLu Sm -999.2500 GR -,~HC;5 -999. 2:0'3., CqM,-~. NP~Z -99~.253'3 NCNL . O. O. O. 3. O, O. 2. 7. O. 5. ]EPT 53 O O · L,"' 0"30 S=LU SC -999.2533 '3q q PHi - 999. 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TR.&ILER ::~ :I~_ ¢-,_ N2M=. ,- : E~'i'T.. , · ~FRViCE NAME : iEPSICN ~ : ]ATE : ,!AXiMUM LF-NGTH : 1,324 :ILE TYP~ : -999.2500 ILO -999.2500 GR -999.2500 NR2T -999.2500 FCNL -999.2500 ILO -9'29.2500 GR -9'99.2500 N~AT -999.2500 FCNL -999.2500 iLO -999.2500 GR -999. 2500 FCNL -999.2500 ILD -999.2500 GR -999.2500 bi,aT -999.2500 FCNL -999.2500 iLD -9~9.2500 GR -999.2500 NRAT -999.2500 FCNL -999.£500 iLD -9'9'9.2500 GR -999.2500 NRaT -'9'99.2500 FCNL -999.2500 iLO -999.2500 GR -999,250,0 NRAT -999.2500 FCNL -999.2500 ILD -999.2500 GR -999.2500 NRAT -999.2500 FCNL -999.2500 iLO -9)9.2500 GR -999.2500 -9~9.2500 ;CNL -999.2500 ILM -999.2500 CALl -999.2500 RNRA -9'99,2500 GR -999.2500 ILM -999,2500 CALl -999.2500 RNR~, -9'99.2500 GR -'999.2500 iLM -999.2500 C~Li '-999.2500 RNRA -999.2500 GR -999,2500 ILM -999.2500 CALl -999.2500 RNR& -999.2500 GR -999.2500 ILM -999.2500 CALl -999..2500 RNRA -999.2500 GR -999,2500 !LM -999.2500 CALl -999.2500 RNR& -999.2500 GR -999.2500 ILM -99'9.2500 CALl -999.2500 RNRA -999.2500 GR -999.2500 ILM -999.2500 CALl -999.2500 RNRA -999.2500 GR -999.2500 iLM -999.2~00 CALl -939.2500 RNRA -999.2300 GR -999.2500 -999.2500 -999.2500 24.8750 -999.2500 -999.2500 -'999.2500 28.7188 -999.2500 -999.2500 -999.2300 18.4844 -999.2500 -999.2500 -999.2500 28.3594 -999.2500 -999.2500 '-999.2500 15.1250 -999.2500 -999.2500 -999.2500 38.9587 -999.2500 -999.2500 -999.2500 ,33.6250 -999.2500 -'999.2500 -999.2500 14.9844 -999.2500 -999.2500 -999.2500 15.6250 .VP 010.H0£ VE~.iFICATICN LISTING 'PAGE 11 4EXT FILE NAME : :~=:~ TAPE TRAiLE~ ~::RVtCE NAME :EDIT )aTE :86/09/12 ]RZGZN :FS1A 'aPE NAME : :ONTINUATI~N ~ :01 ,~EXT T~PE NAME '~.MM.ENTS :LIBRARY TAPE ',:~:: REEL T'~,AILER ~ERViC:E NAME :EDIT )ATE :25/09/12 ] .R I G I N : ~.EF'L N~ME : 142573 'ONTINUATZON ~ :01 ,:EXT REEL N',IME : 'C~ENTS :LZSR~RY POST FRAC JOB REPORT SALES REP : JUNIOR TAFT ENGINEER : DAVID ROSS SALES LOCATION : ANCHORAGE SERVICE LOCATION: NORTH SLOPE MAILING ADDRESS: 6927 OLD SEWARD HYW MAILING ADDRESS : POUCH 340074 ANCHORAGE, AK 99518 PRUDHOE BAY,AK 99734 PHONE NUMBER : (907) 349-6518 PHONE NUMBER : (907) 659-2678 ARCO ALASKA INC. 03-23-1989 WELL INFORMATION JOB TICKET # : 409747 DATE OF JOB : 10-11-88 TREATING FLUID: PROPPANT TYPE : BJ TITAN RXL-4 16-20 CARBO-LITE CUSTOMER : ARCO ALASKA INC. REPRESENATIVE · · STEVE CHAMBERS WELL NAME : 2T-07 FORMATION .' KUPARUK A&C SANDS PERMEABILITY : 50 ~ROSITY : , .22 FRAC GRADIENT~ : .65 RESERIVOR PRESSURE : 3000 NET HEIGHT : 184 YOUNG'S MODULUS : 2800000 PERFORATED INTERVAL: SIZE : NUMBER 42:.46:504 B.H.T.P. MEASURED BY : PRIMARY TREATING STRING : T TREATING RATE : 20 BJ-TITAN SALES OFFICE : ANCHORAGE BJ-TITAN SALES REPRESENATIVE : JUNIOR TAFT BJ-TITAN SERVICE LOCATION : NORTH SLOPE BJ-TITAN ENGINEER : DAVID ROSS ARCO ALASKA INC. 10-17-1988 JOB TICKET # : DATE OF JOB : TREATING FLUID: PROPPANT TYPE : WELL INFORMATION 409747 10-12-88 BJ TITAN RXL-4 16-20 CARBO-L ITE CUSTOMER : ARCO ALASKA INC. REPRESENATIVE : WELL NAME . ' STEVE CHAMBERS 2T-07 FORMATION : PERMEABILITY : POROSITY : . · . KUPARUK A&C SANDS 50 RESERIVOR PRESSURE : NET HEIGHT : YOUNG'S MODULUS : PERFORATED INTERVAL: SIZE : NUMBER 3000 184 2800000 42'.. 46'504. B.H.T.P. MEASURED BY : PRIMARY TREATING STRING : T TREATING RATE : 20 BJ-TITAN SALES OFFICE : NORTH SLOPE BJ-TITAN SALES REPRESENATIVE : JUNIOR TAFT BJ-TITAN SERVICE LOCATION : BJ-TITAN ENGINEER : NORTH SLOPE DAVID ROSS TABLE OF CONTENTS I. ANALYSIS: A. REPORT FORMAT B. COMPUTER MODEL DESCRIPTION C. GENERAL JOB DESCRIPTION II . PUMP-IN TEST #1 : A. SUMMARY B. COLOR SIMULTANEOUS PLOT -.. C. SURFACE ~REATING PRESSURE'' D. CALCULATED BOTTOM HOLE PRESSURE E. INJECTION RATE F. SURFACE AND BOTTOM HOLE PRESSURE vs. TIME PRINTED DATA III. PUMP-IN TEST #2 : A. SUMMARY B. COLOR SIMULTANEOUS PLOT C. SURFACE TREATING PRESSURE D. CALCULATED BOTTOM HOLE PRESSURE E. INJECTION RATE F. SURFACE AND BOTTOM HOLE PRESSURE vs. TIME G. PRINTED DATA H. EFFICIENCY DATA I. BHP vs. SQRT(DT) J. BHP vs. SQRT(T+DT) -SQRT(DT) III. PUMP- IN TEST #2 CONT. : K. BHP vs. DT L. HORNER PLOT M. M D H PLOT N. BHP vs. g(tD) O. DIAGNOSTIC PLOT IV. MINI-FRAC TEST : A. SUMMARY B. COLOR SIMULTANEOUS PLOT .. C. SURFACE TREATING-pREssuRE- D. CALCULATED BOTTOM HOLE PRESSURE E. INJECTION RATE F. SURFACE AND BOTTOM HOLE PRESSURE vs. TIME G. PRINTED DATA V. FRACTURE TREATMENT : A. SUMMARY B. COLOR SIMULTANEOUS PLOT C. SURFACE TREATING PRESSURE D. CALCULATED BOTTOM HOLE PRESSURE E. INJECTION RATE F. SAND CONCENTRATION G. SURFACE AND BOTTOM HOLE PRESSURE vs. TIME H. LOG NET PRESSURE vs. LOG TIME I. PRINTED DATA REPORT FORMAT The information included in this report represents all data as recorded by an on-site computer system. All plots and data are divided into sections and outlined in the table of contents. On location, the data was incorporated into the Smith-Nolte model for bottom hole pressure analysis.~This ~del can be~.emPloyed to determine' down- hole conditions during a fracturing treatment. The first section of this report contains this document as well as the job description. The job decription is an outline of the entire job, depicting significant events in chronological order. Section two contains the data collected during the actual frac job, this includes all plots and printed data. Ail data presented in this report is assumed to be correct to the best of this operator's knowledge, and in no way implies or states liability thereof. THE COMPUTER MODEL: The computer model is based on Nolte and Smith's SPE PAPER #8297. The model is designed to provide a basis for interpretation of fracture treatment pressures. Four main areas of interest exsist in the interpretation of fracturing pressure plots. These are as follows: 1. A positive slope of .1 to .2, interpreted as an area of confined height growth. 2. A negative slope, interpreted as an area of unstable height growth. , 3' a SlOPe of 0, described'by Nolte and'Smith'as a problem area since the constant pressure region may precede a rapid increase in pressure, resulting in a pressure or screen out. 4. A 1 to 1 slope indicating a pressure or screen out ( flow restriction). In the model, the bottom hole pressure is calculated using the formula: BHP = STP - Tfp + Hh where: BHP is the calculated bottom hole pressure. STP is the measured surface treating pressure. Tfp is the calculated-tubing friction pressure. Hh is the calculated hydrostatic head. The surface treating pressure and rates are imput from the frac monitor. Sand is imput from the sand densiometer or can be imput manually. Therefore, these values are not calculated. The main computational areas in this computer model are as follows: 1. A time averaging routine which takes the average of every 10 calculated bottom hole values, resulting in a data point being 'plotted every 12 seconds. A fracturing plot is then generated from this time averaged data (see fracturing pressure plot). 2. A technique for predicting friction pressures, utilizes N' and K' along with a polynomial fit of lab generated friction curve data. This curve fitting technique is able to predict friction pressures equal to the lab generated data throughout changing flow rates. 3. A model used that predicts the effect of sand on the hydrostatic and the friction pressures, and can mathematically follow up to fifty fluid fronts down the treating string. During the job, a fluid system may be changed many times. The computer operator has the flexibility to tell the computer which fluid is being used and at any time change to the appropriate fluid system. When a fluid change occurs, the the new fluid front is followed down the treating string. This results in a real~ '~c computation for the friction pressures when fluid c ~ ses occur. · · 9 2T-07 (A&C SAND) FLUID ANALYSIS & FRACTURE STIMULATION OCTOBER 11-12 1988 JOB DESCRIPTION: The 2T-07 data frac and frac were done on the 11th, and 12th of October 1988. The data analysis portion of the job was composed of 2 pumpin-shutin tests, and 1 mini-frac test. An ARCO BHP tool was run in the well by OTIS wireline, in order to obtain and record accurate BHP's for pressure decline analysis, and friction pressure correlations. The fluid that was analized was BJ Titan RXL-4 w/ 5% diesel. The fluid was designed to .develope 10~' ~ Df its- x-link .in 1 minu+~. Although the. x-link of the fluid. is Primarily tim~',iependent, a temPerature rise of 4-5 OF over the first minute was also simulated during the quality control tests. 40 ppt of Silica Flour was added to the fluid on the Mini Frac stage,, and the Pad stage of the frac for additional leak-off control. Unfortunately due to logistical problems during the mini- frac stage, no efficiency data was obtained for the fluid with silica flour. However, based on the data obtained from the second pump-in test, the decision was made to pump the original job design, with the exception of reducing the rate to 15 BPM just prior to starting the sand stages. Higher than anticipated STP's during the pump-in, and mini-frac stages, created concern that the additional sand friction that would be encountered at 20 BPM would cause us to exceed the pressure limitation of 6,200 psi. The frac job was delayed until the morning of the 12th due to problems encountered with retrieving the BHP tool. The STP's encountered during the pad stage of the frac were 800-900 psi lower then the STP's observed earlier. A substantial amount of friction created by the wireline in the hole on the previous stages was one possible explanation for the large difference. With the exception of a short shut down at the start of flush, the job was pumped to completion. A total of 89,200 lbs of 16-20 Carbo-Lite was pumped. 2T-07 PUMP-IN TEST #1 OCTOBER 11, 1988 JOB DESCRIPTION: Pump-in ~est #1 called for pumping 150 bbls. of BJ Titan RXL-4 w/5% diesel at 20 BPM. However, due to a delay in achieving the 20 BPM rate 190 bbls of fluid was actually pumped before shut down. Once 20 BPM was achieved the average STP encountered was approximately 5,530 psi. Based on the BHP measurements the tubing friction calculated out to be approximately 525 psi/1000' At shut in the calculated bottom hole ISIP was 3,724 psi. Unfort~ately the signal from.the BHP tool went.out prior ,to obs~v.ing an.obvious ct.osure.pressure and'the decision was made to bleed the pressure off, and not use the calculated BHP for the pressure decline analysis. A total of 7.69 minutes of calculated BHP was recorded after shutin with no obvious closure pressure observed. The decision was made to combine the second and third pump-in tests into one 100 bbl stage, after the BHP tool had been retrieved and run back in the hole. JOB TICKET # : 409747 CUSTOMER : ARCO ALASKA INC. DATE OF JOB : 10-11-88 POST JOB REPORT CALCULATED BOTTOM HOLE TREATING PRESSURE VS TIME C ~t 72~ L C 64~ U~ T B 32~ H ' '1 ' ' I " '1 ' ' I "" I ' '1 ' ' 1" ' , , , S 6 , I , f , i_ , f . f . t , f I 6.8 2.7 5.4 8.2 16.9 13,5 16.3 19.6 2t.8 TI~, JOB TICKET # : 409747 CUSTOMER : ARCO ALASKA INC. DATE OF JOB : 10-11-88 POST JOB REPORT SIMULTANEOUS PLOT OF JOB PARAMETERS 9.6 S · ~ ,~.8~ i6.8 4.8 3.8 1.8 6.8 ..... : ....... : .......6488 566~ 4666 .................... 4680 H .................... 3296 P .... : ....... ' 2466 2.5 .... . ...................................... 888 I I , ^11"1 ¥ ~J 8.8 3.1 6.2 9.3 12.4 15.5 18.7 TI~, flI~TES 6 21.8 JOB TICKET # : 409747 CUSTOMER : ARCO ALASKA INC. DATE OF JOB : 10-11-88 POST JOB REPORT SURFACE TREATING PRESSURE VS TIME 2.7- 5.4 8.2 18.9 13.6 16.3 19,8 ., 21.8 JOB TICKET # : 409747 CUSTOMER : ARCO ALASKA INC. DATE OF JOB : 10-11-88 POST JOB REPORT TOTAL SLURRY PUMP RATE VS TIME M P-29.98 R .... 58 T 15.88 E 12.~ 18.88 B P 7.~ iq 5.88 6.66 6.6 · I , I , I , i ~ I~ , I , I , 2.7 5,4 8.2 /6.9 13.6 16.3 19.6 21,8 TIRE, fl IItITES JOB TICKET # : 409747 CUSTOMER : ARCO ALASKA INC. DATE OF JOB : 10-11-88 POST JOB REPORT SURFACE AND BOTTOM HOLE PRESSURE VS TIME 3288 2488 888 8 8.8 2.? 3888 P 248~ E $ 18~8 ~ 686 5.4 8.2 18.9 ~3.6 16.3 19.8 21.8 TIME, ti I~'1~ A~CO ALASKA INC. 409747 PAGE 1 DATE: 10-11-88 FRAC JOB DATA ET SUB~AC~ TIME PRESSUltE MIN PSI ~ HOLE PUMP SAND PI~SSURE RATE CONC. PSI BPM PPG SLOPE (LO~/LO~) FLUID NO. STAGE 0.34 788 3310 0.0 0.43 788 3310 0.0 0.51 788 3310 0.0 0.60 995 3224 1.4 0.68 1172 3694 0.0 . 0. 0. 0. 0. 0.0 0.0 0.0 0.0 0.0 Stage # 0.77 1488 0.86 1970 0.95 2542 1.04 3084 1.13 3941 3797 0.7 0. 3959 3.4 0. 4446 4.1 0. 4786 5.6 0. 5264 8.4 0. 0 0 0 0 0 .0 .0 .0 .0 .0 1.22 1.31 1.42 1.51 1~59 1.-ii 1.87 1.95 2.04 4118 5575 7.4 4177 5476 8.6 4197 5531 8.3 4187 5561 8.0 4187 5569 8.0 4187 4187 4158 4148 4148 o. 5708 ~ 7.0 5654 7'.4 5600 7.6 5598 7.5 5610 7.4 . 0. 0. 0. 0. 0. 0. 0. 0. 1 1 0 0 0 . 0 0 0 0 2.8 2.8 2.0 2.0 1.2 .1.2 0.8 0.8 -0.1 -0.1 0 0 0 0 0 2.13 4315 5760 7.5 2.22 '4660 5951 8.6 2.31 4966 6177 9.2 2.40 5281 6375 9.9 2.49 5389 6431 10.3 . 0. 0. 0. O. -0.0 -0.0 1.2 1.2 1.9 2.58 5429 6451 10.4 2.67 5419 6437 10.4 2.77 5389 6421 10.4 2.86 5360 6377 10.4 2.95 5330 6346 10.5 . 0. 0. 0. O. .9 .8 .8 .0 .0 0 0 0 0 0 3.04 5301 6311 10.5 3.13 5251 6254 10.6 3.21 5212 6205 10.6 3.31 5143 6134 10.6 3.39 5084 6103 10.4 O. O. 0. 0. O. -0 -0 -0 -0 -0 .3 .3 .6 .6 .8 0 0 0 0 0 3.49 5044 6060 10.4 3.58 4985 5964 10.7 3.67 4936 5916 10.7 3.76 4897 5879 10.7 3.85 4828 5799 10.8 . 0. 0. 0. 0. -0 -0 -0 -1 -1 .8 .6 .6 .0 .0 3.94 4030 5166 9.7 4.03 3507 4947 7.6 4.12 3468 4910 7.6 4;'21 3478 4904 7.7 4.30 3438 4887 7.5 . 0. 0. 0. 0. -1.0 -1.0 -9.8 -9.8 -1.6 ARCO ALASKA INC. 409747 FRAC JOB DATA ET SURFACE TIME PRESSURE MIN PSI BOTTOM HOLE PUMP PRESSURE RATE PSI BPM 4.39 3419 4.48 3399 4.57 3389 4.66 3379 4.75 3399 SAND CONC. PPG 4.84 3931 4.93 3951 5.02 4079 5.11 4266 5.20 4256 4862 7.6 0.0 4863 7.4 0.0 4846 7.4 0.0 4846 7.4 0.0 4816 7.7 0.0 5.29 4562 5.37 4611 5.46 4818 5.55 4847 5.64 4818 5~.~ 484 5.82 5035 5.91 5044 6.00 4837 6.09 4680 5127 9.3 0.0 5136 9.3 0.0 5207 9.7 0.0 5270 10.5 0.0 5229 10.7 0.0 6.18 4414 6.26 4355 6.35 4887 6.44 4985 6.53 5044 5399 11.6 5410 11.9 5551 12.3 5494 12.8 5416 13.1 5574 13.4 5500 13.9 5283 14.0 5093 14.2 6.62 5084 6.71 5104 6.80 5123 6.89 5222 6.98 5281 0.0 0.0 0.0 0.0 0.0 7.07 5301 7.15 5399 7.23 5370 7.32 5350 7.41 5350 '0- 0 0.0 0.0 0.0 0.0 7.50 5340 7.59' 5291 7.68 5074 7.77 5005 7.86 4975 4846 14.1 0.0 4775 14.1 0.0 4996 15.9 0.0 4977 16.6 0.0 4960 17.0 0.0 7.95 4975 8.04 4975 8.12 4966 8.21 4975 8.2'9 4975 4909 17.5 .0.0 4995 17.1 0.0 4960 17.5 0.0 5025 17.6 0.0 4936 18.4 0.0 5007 18.1 0.0 4975 18.8 0.0 4957 18.8 0.0 4926 18.8 0.0 4903 19.0 0.0 4931 18.8 0.0 4892 18.7 0.0 4646 18.9 0.0 4568 18.9 0.0 4561 18.8 0.0 4561 18.8 0.0 4559 18.8 0.0 4526 18.9 0.0 4574 18.7 0.0 4574 18.7 0.0 PAGE 2 DATE: 10-11-88 SLOPE FLUID ( LOG / LOG ) NO. STAGE -1.6 0 -0.7 0 -0.7 0 -0.3 0 -0.3 0 -0.5 0 -0.5 0 4.3 0 4.3 0 2.8 0 2.8 0 2.1 0 2.1 0 2.2 0 2.2 0 -0.3 -0.3 1.1 1.1 -1.3 -1.3 -5.2 -5.2 -1.7 -1.7 -1.3 -1.3 -0.0 -0.0 0.5 0.5 -0.1 -0.1 -0.9 -0.9 -1.4 -1.4 -0.6 -0.6 -6.7 -6.7 -3.5 -3.5 -2.3 -2.3 ARCO ALASKA INC. 409747 FRAC JOB DATA ET SURFACE TIME PRESSURE MIN PSI BOTTOM HOLE PUMP SAND' PRESSURE RATE CONC . PSI BPM PPG 8.38 4995 8.47 5015 8.56 5054 8.65 5084 8.74 5054 4592 18.7 0.0 4557 19.0 0.0 4636 18.8 0.0 4669 18.8 0.0 4632 18.8 0.0 8.83 5015 8.91 4788 9.00 4680 9.09 4837 9.17 4808 4585 18.9 0.0 4474 18.3 0.0 4678 16.6 0.0 4579 18.0 0.0 4559 17.9 0.0 9.26 4562 9.35 4591 9.43 4916 9.52 4877 9.61 4906 9.70 5015 9.79 4966 9.88 4798 9.97 4828 10.07 4828 4415 17.4 0.0 4521. 16.9 0.0 4671 17.9 0.0 4630 17.9 0.0 4630 18.1 0.0 4950 16'.g 4666 18.2 4822 16.4 4638 17.6 4657 17.5 10.16 4847 10.24 5015 10.33 5025 10.42 4749 10.51 5232 0.0 0.0 0.0 0.0 0.0 10.60 5232 10.69 5232 10.78 5212 10.87 5143 10.96 4611 4804 16.8 0.0 4719 18.2 0.0 4739 18.1 0.0 4618 17.3 0.0 4792 18.9 0.0 11.05 5448 11.13 5695 11.22 5685 11.30 5626 11.39 5596 4794 18.9 0.0 4812 18.8 0.0 4796 18.8 0.0 4715 18.9 0.0 4427 17.6 0.0 11.48 5576 11.57 5557 11.66 5547 11.75 5537 11.84 5517 4946 19.3 0.0 4994 20.3 0.0 4981 20.3 0.0 4941 20.2 0.0 4927 20.1 0.0 11.93 5517 12.02 5517 12.10 5517 12 .'.18 5488 12.27 5507 4937 20.0 0.0 4868 20.2 0.0 4852 20.2 0.0 4876 20.1 0.0 4827 20.2 0.0 PAGE 3 DATE: 10-11-88 SLOPE FLUID (LO~/LOG) NO. 0.7 0 0.7 0 -0.1 0 -0.1 0 2.2 0 STAGE 2.2 0 -0.0 0 -0.0 0 1.1 0 1.1 0 -0.2 0 -0.2 0 -0.6 0 -0.6 0 0.5 0 ,. 0'.5 0 4.1 0 4.1 0 2.3 0 2.3 0 -0.3 -0.3 0.3 0.3 -0.2 -0.2 0.7 0.7 0.7 0.7 -1.3 -1.3 -1.3 -1.3 -1.4 -1.4 -1.4 -1.4 -1.6 -1.6 4874 20.0 0.0 -1.6 4807 20.3 0.0 -1.6 4766 20.5 0.0 -1.5 4797 20.2 0.0 -1.5 4827 20.2 0.0 -1.3 .% ARCO ALASKA INC. 409747 FRAC JOB DATA ET SURFACE TIME PRESSURE MIN PSI ~ HOLE -PUMP SAND PRESSURE RATE CONC. PSI BPM PPG 12.36 5498 12.45 5507 12.54 5488 12.63 5498 12.72 5498 4754 20.5 0.0 4776 20.4 0.0 4762 20.4 0.0 4770 20.4 0.0 4754 20.5 0.0 12.81 5488 12.90 5488 12.99 5468 13.10 5468 13.18 5468 4732 20.5 0.0 4722 20.6 0.0 4750 20.4 0.0 4734 20.4 0.0 4754 20.3 0.0 13.32 5458 13.40 5458 13.49 3212 13.58 2158 13.67 1478 · i3.82 ' 1'232 '13.90 1202 13.99 1202 14.11 1192 14.19 1202 4760 20.3 0.0 4777 20.2 0.0 3578 14.5 0.0 3221 10.1 0.0 3297 4.7 0.O -.. 3 68 O ~ 0'~ 2 ~0: 0'- 3724 0.0 0.0 3724 0.0 0.0 3714 0.0 0.0 3724 0.0 0.'0 14.28 1202 14.37 1192 14.45 1202 14.54 1192 14.62 1192 3724 0.0 0.0 3714 0.0 0.0 3724 0.0 0.0 3714 0.0 0.0 3714 0.0 0.0 14.71 1192 14.80 1202 14.88 1192 14.97 1192 15.05 1192 3714 0.0 0.0 3724 0.0 0.0 3714 0.0 0.0 3714 0.0 0.0 3714 0.0 0.0 15.14 1192 15.23 1192 15.32 1192 15.40 1182 15.49 1192 3714 0.0 0.0 3714 0.0 0.0 3714 0.0 0.0 3704 0.0 0.0 3714 0.0 0.0 15.57 1182 15.66 1182 15.74 1172 15.83 1192 15.92 1172 3704 0.0 0.0 3704 0.0 0.0 3694 0.0 O. 0 3714 0.0 0.0 3694 0.0 0.0 16.00 1172 16.11 1172 16.20 1163 16~. 28 1182 16.37 1163 3694 0.0 0.0 3694 0.0 0.0 3684 0.0 0.0 3704 0.0 0.0 3684 0.0 0.0 PAGE 4 DATE: 10-11-88 SLOPB FLUID (LOG/LOG) NO. STAGE -1.3 0 -1.4 0 -1.4 0 -1.4 0 -1.4 0 -1.3 0 -1.3 0 -1.3 0 -1.3 0 -1.1 0 -1.1 0 -0.7 0 -0.7 0 -16.0 0 -16.P 0 O.o o' 0.0 0 0.0 0 0.0 0 -0.4 0 -0.4 0 -0.1 0 -0.1 0 -0.1 0 -0.1 0 -0.3 0 -0.3 0 -0.3 0 -0.3 0 -0.6 0 -0.6 0 -0.6 0 -0.6 0 -0.5 0 -O.5 0 -0.4 0 -0.4 0 -0.7 0 -0.7 0 -0.7 0 -0.7 0 -1.1 0 -1.1 0 -1.6 0 -1.6 0 ARCO ALASKA INC. 409747 FRAC JOB ET SURFACE ~ HOLE TIME PRESSURE PI~ESSI/RE MIN PSI PSI 16.45 1153 16.54 1163 16.62 1153 16.71 1143 16.80 1133 3675 3684 3675 3665 3655 16.88 1133 16.97 1133 17.05 1113 17.14 1123 17.23 1123 3655 3655 3635 3645 3645 17.31 1113 17.40 1123 17.49 1123 17.57 1113 17 -5 1113 '~ 7./4. 112'3 17.83 1133 17.92 1103 18.00 1103 18.12 1094 3635 3645 3645 3635 3635 · 3655 3625 3625 3615 18.21 1103 18.29 1103 18.38 1103 18.47 1103 18.55 1103 3625 3625 3625 3625 3625 18.64 1103 18.72 1113 18.81 1113 18.89 1103 18.98 1103 3625 3635 3635 3625 3625 19.07 1103 19.16 1133 19.24 1074 19.33 1094 19.41 1094 3625 3655 3596 3615 3615 19.50 1094 19.59 1084 19.67 1084 19.76 1094 19.84 1084 3615 3606 3606 3615 3606 19.93 1074 20.01 1074 20.14 1074 20~22 1064 20.31 1054 3596 3596 3596 3586 3576 DATA PUMP RATE BPM 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0. 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 SAND CONC. PPG 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 PAGE 5 DATE: 10-11-88 SLOPE FLUID (LO~/LO~) NO. STAGE -1.4 0 -1.4 0 -1.1 0 -1.1 0 -1.7 0 -1.7 0 -2.1 0 -2.1 0 -3.8 0 -3.8 0 -2.2 0 -2.2 0 -1.6 0 -1.6 0 -2.1 0 . . --2'.1 0 -1.5 0 -1.5 0 -1.5 0 -1.5 0 -1.7 0 -1.7 0 -1.7 0 -1.7 0 -1.5 0 -1.5 0 -1.2 0 -1.2 0 0.5 0 O.5 0 -0.5 0 -O.5 0 0.9 0 0.9 0 0.9 0 0.9 0 0.8 0 0.8 0 -0.4 0 -0.4 0 -0.4 0 -0.4 0 -0.4 0 -0.4 0 -1.0 0 ARCO ALASKA INC. 409747 FRAC JOB ET SURFAC~ ~ HOLE TIM~ PRESSURE PRESSURE MIN PSI PSI 20.39 1064 20.48 1064 20.56 1064 20.65 1054 20.74 1064 3586 3586 3586 3576 3586 20.82 10'64 20.91 1064 20.99 1064 21.08 1074 21.17 1064 3586 3586 3586 3596 3586 DATA PUMP RATE BPM 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 SAND CONC. PPG 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 21.25 1074 3596 0.0 0.0 21.34 1064 3586 0.0 0.0 21.42 1064 3586 0.0 0.0 21.51 1064 3586 0.0 0.0 21.59 1094 3615 0.0 .0.0 0.0 21.,~ 1034 3556 0.0" 0.0 PAGE 6 DATE: 10-11-88 SLOPE FLUID (LOG/LO~ ) NO. STAGE -1.0 0 -1.0 0 -1.0 0 -0.9 0 -0.9 0 -0.7 0 -0.7 0 -0.5 0 -0.5 0 2.2 0 2.2 0 1.5 0 1.5 0 -1.7 0 -1.7 0 4,4 0 4.4 0 2T-07 PUMP-IN TEST #2 OCWI~BER 11, 1988 JOB DESCRIPTION: Pump-in test #2 called for pumping 100 bbls. of BJ Titan RXL-4 w/5% diesel at 20 BPM. An actual 108 bbls was pumped prior to shut down. 19.4 BPM was achieved 5.95 minutes into the stage and remained there until shut down. The average STP encountered at max rate was approximately 5,200 psi. Once again the tubing friction calculated out to be 500-530 psi/1000'. At shut in the calculated bottom hole ISIP was 3,765 psi. A total of 12.64 minutes of calculated BHP .was' recorded . after-shutin~.-A-closure pressure of. 3,614 psi Was' ~hosen based on-the BHP vs. SQRT (DT) plot, which Corresponds to an 11.1 minute closure time. Based on these values P*= 94 psi was calculated by the computer using Nolte's curve match method. An average efficiency of .468 was then calculated based on zero correction for leakoff during pumping. The computer also calculated an ISIP of 3,772 psi, Pc = 3,607 psi, Tc = 10.5 min. and P* = 90 psi based on a linear regression method, using the straight line portion of BHP vs. g(tD) loss volume function. JOB TICKET # : 409747 CUSTOME'R : ARCO ALASKA INC. DATE OF JOB : 10-11-88 POST JOB REPORT SURFACE TREATING PRESSURE VS TIME 61]1]11 S U R l ' ' I ' - I ' I '- I ' I ' I ' · _ 2.6 $.3 7.9 18.9; 13.1 19;.8 18.4 21.8 {IRE, R INU~I~ JOB TICKET # : 409747. CUSTOMER : ARCO ALASKA INC. DATE OF JOB : 10-11-88 POST JOB REPORT SIMITLT~EOUS PLOT OF JOB PARAMETERS STP 25.6 - ~.8 22.5 .Z9,6 C 15.6 0 Fi 12.5 C 16,6 7.5 P P 5,6 2.5 6.6 ¢1:1.5.6 T E :tZ.5 B 16.6 I'1 5,6 2.5 6.8 6.6 7266 S .................. 6488 T P 4669 B ,,t068 H I , i 3.6 6.6 9.6 11,9 14,9 17,9 TIKE, Fi IWtJTES 2488 - 1680 P S 888 I ' 6 29.9 JOB TICKET # : 409747 CUSTOMER : ARCO ALASKA INC. DATE OF JOB : 10-11-88 POST JOB REPORT TOTAL SLURRY PUMP RATE VS TIME P ti 22.~ iq P *Z9 R T lg.M 18.1~1 B -P 7.~ II 5.66 6.ii8 , I , I , I ,~ l , I , I ,\ I 6.6 !.3 2.5 3.8 5.6 6.3 7.5 8.8 -- TI~E, flI~TES 18.8 JOB TICKET # : 409747 CUSTOMER : ARCO ALASKA INC. DATE OF JOB : 10-11-88 POST JOB REPORT CALCULATED BOTTOM HOLE TREATING PRESSURE VS TIME L ¢ H I ' I ' ' "1 " I ' I ' ~ , I , I ~ I , I , I , I , 8.8 2.6 .5,2 7.8 18.4 13.1 15,7 18.3 JOB TICKET # : 409747 CUSTOMER : ARCO ALASKA INC. DATE OF JOB : 10-11-88 POST JOB REPORT SURFACE AND BOTTOM HOLE PRESSURE VS TIME B 4688 P R 4mm s 3288 1666 ......................... P S 888 ................................................................ I 8 , I , I , I , I, , I , I , I , .. 8.8 5468 U ................................................... 4689 R ....:.'.~'- . ,.- .,.', :.'/-. .i.' , . ..'.,. ...'. .i .':..', '....' ..".:~..4298 I~F i . ............................................................... ?,466 E 24~M ............................................................. 1~88 1288 - 2.6 5.3 7.9 i6.5 i3.i 15.8 :18.4 21.8 TI~E, ARCO ALASKA INC. 409747 F.RAC JOB DATA ET SURFACE TIME PRESSURE MIN PSI BOTT(IM HOLE PUMP SAND PRESSURE RATE CONC. PSI BPM PPG 1.46 3448 1.55 3458 1.64 3478 1.72 3478 1.82 3507 4822 7.0 0.0 4842 7.0 0.0 4854 7.0 0.0 4846 7.1 0.0 4880 7.1 0.0 1.91 3507 1.99 3586 2.09 3606 2.18 3655 2.27 3921 4838 7.3 0.0 4894 7.3 0.0 4918 7.4 0.0 4946 7.4 0.0 5135 8.0 0.0 2.36 4532 2.45 4877 2.53 5035 2.62 5468 2 .... 5705 2.d0' 5793 2.89 5773 2.98 5636 3.07 5527 3.16 5498 5316 9.2 5669 10.6 5758 10.8 6002 11.6 6232 12..1 6-293 , 12.3 6267 12.3 6158 12.3 6017 12.3 5981 12.1 3.25 5448 3.34 5350 3.43 5370 3.52 5360 3.61 5241 0.0 0.0 0.0 0.0 0.0 0,-0 0.0 0.0 0.0 0.0~ 3.70 5172 3.79 5044 3.88 4946 3.97 4877 4.06 4778 5949 12.2 0.0 5846 12.3 0.0 5844 12.4 0.0 5855 12.3 0.0 5758 12.4 0.0 4.15 4700 4.24 4660 4.33 4650 4.42 4591 4.51 4345 5642 12.4 0.0 5522 12.4 0.0 5435 12.4 0.0 5332 12.5 0.0 5258 12.5 0.0 -4.60 4483 4.69 5025 4.78 5104 4.87 4897 4.96 4788 5152 12.5 0.0 5085 12.6 0.0 5032 13.0 0.0 4957 13.0 0.0 4725 13.1 0.0 5.05 4542 5.14 4404 5.23 4315 5.31 4276 5.40 4276 4689 13.2 0.0 5049 14.8 0.0 5073 15.2 0.0 4813 15.4 0.0 4547 16.3 0.0 PAGE 1 DATE: 10-11-88 SLOPE FLUID ( LOG /LOG ) NO. 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 STAGE 0.0 0 -0.0 0 0.1 0 0.1 0 0.2 0 0.2 0 2.1 0 1.9 0 1.9 0 2.0 0 2.0 0 1.9 0 1.9 0 1.3 0 0.6 0 0.6 0.1 _0.1 -0.2 -0.6 -0.6 -1.6 -1.6 -1.8 -2.1 -2.1 -2.2 -2.2 -1.9 -1.9 -4.8 2.5 2.5 1.1 1.1 4254 16.7 0.0 -8.1 4032 16.8 0.0 -13.5 3935 16.9 0.0 -13.5 3878 17.0 0.0 -12.2 3916 16.8 0.0 -12.2 Stage # ARCO ALASKA INC. 409747 FRAC JOB DATA ET SUBFA~ TIME PRESSURE MIN PSI ~ HOL~ PUMP SAND PRESSURE RATE CONC. PSI BPM PPG 5.51 4030 5.59 4207 5.68 4847 5.85 4995 5.94 5104 3819 16.5 0.0 4141 15.3 0.0 4109 17.7 0.0 4154 18.9 0.0 4212 19.4 0.0 6.02 5133 6.11 5143 6'20 5143 6.29 5172 6.38 5182 4220 19.5 0.0 4209 19.5 0.0 4220 19.5 0.0 4243 19.4 0.0 4254 19.5 0.0 6.46 5192 6.55 5182 6.64 5202 6.73 5241 6'82 526! 7.00 5143 7.09 5133 7.25 5172 7.34 5192 4265 19.5 4267 19.5 429~ 19.4 4352 19.3 4366 19.4 4268 ~ '19~5" 4187 19.6 4183 19.5 4228 19.6 4258 19.5 7.43 5212 7.51 5241 7.60 5261 7.68 5281 7.77 5281 0.0 0.0 0.0 0.0 0.0 7.86 5281 7.95 5035 8.04 1557 8.13 995 8.26 1261 0.o 0.0 0.0 0.0 0.0 8.34 1241 8.43 1241 8.52 1222 8.60 1222 8.69 1232 4257 19.6 0.0 4294 19.5 0.0 4315 19.6 0.0 4340 19.-6 0.0 4332 19.7 0.0 8.78 1222 8.87 1222 8.96 1222 9.05 1212 9.13 1212 4347 19.5 0.0 4371 19.2 0.0 1837 13.4 0.0 3224 1.0 0.0 3783 0.0 0.0 9.22 1212 9.31 1202 9.40 1192 9:48 1202 9.57 1202 3763 0.0 3763 0.0 3748 0.0 3744 0.0 3753 0.0 0.0 ' 0.0 0.0 0.0 0.0 3744 0.0 0.0 3744 0.0 0.0 3737 0.0 0.0 3734 0.0 0.0 3734 0.0 0.0 3734 0.0 0.0 3724 0.0 0.0 3734 0.0 0.0 3724 0.0 0.0 3724 0.0 0.0 PAGE 2 DATE: 10-11-88 SLOPE FLUID (LO~/LOG) NO. STAGE -2.5 0 12.3 0 12.3 0 4.3 0 4.3 0 0.1 0 0.1 0 -0.4 0 -0.4 0 2.7 0 0.3 0 0.3 0 0.3 0 0.3 0 3.9 0 '-2,3 0 -2.3 0 -4.1 0 -0.4 0 -0.4 0 2.3 0 2.3 0 2.1 0 2.2 0 2.2 0 1.1 0 1.1 0 -5.2 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 -1.9 0 -1.9 0 -0.8 0 -0.8 0 -0.5 0 -0.9 0 -0.9 0 -0.8 0 -0.8 0 -0.4 0 -0.4 0 -0.7 0 ARCO ALASKA INC. 409747 FRAC JOB TIME PR~SSm~ MIN PSI BOTTO~ HOLE PRESSURE PSI 9.66 1202 9.75 1202 9.84 1192 9.92 1192 10.12 1202 3724 3724 3714 3714 3724 10.20 1192 10.29 1192 10.38 1192 10.46 1182 10.55 1192 3714 3714 3714 3711 3714 10,64 1182 10,72 1182 10,82 1182 10.90 1182 10-~9 1182 1i. J. 1182 11,17 1182 11,33 1182 11,47 1182 11,55 1172 3704 3704 3704 3704 3704 3'704 3704 3704 3704 3694 11.64 1172 11.73 1172 11.82 1172 11.91 1172 12.00 1163 3694 3694 3694 3688 3684 12.08 1163 12.17 1163 12.26 1163 12.34 1163 12.43 1153 3684 3684 3684 3684 3678 12.53 1163 12.61 1153 12.70 1153 12.79 1153 12.88 1153 3678 3675 3675 3675 3675 12.96 1153 13.05 1153 13.14 1153 13.23 1143 13.32 1143 3675 3665 3675 3671 3665 13.41 1143 13.50 1143 13.58 1143 13;67 1143 13.76 1143 3665 3665 3655 3665 3665 DATA PUMP RATE BPM 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 SAND CONC. PPG 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0,0 0,0 0.0 0..0 0,0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 PAGE 3 DATE: 10-11-88 SLOPE FLUID (LOG/LOC) NO. STAGE -0.7 0 -0.6 0 -0.7 0 -0.7 0 -0.7 0 -0.4 0 -0.4 0 -0.4 0 -0.4 0 -0.4 0 -0.4 0 -0.4 0 -0.4 0 -0.4 0 .0..4 0 -0.4 0 -0.4 0 -0.3 0 -0.2 0 -0.4 0 -0.4 0 -0.6 0 -0.6 0 -0.7 0 -1.2 0 -1.2 0 -0.7 0 -0.7 0 -0.4 0 -0.4 0 -1.3 0 -0.9 0 -0.9 0 -0.6 0 -0.6 0 -0.3 0 -0.3 0 -0.1 0 -O.0 0 -0.0 0 4.9 0 4.9 0 -4.5 0 -4.5 0 -1.8 0 ARCO ALASKA INC. 409747 PAGE 4 DATE: 10-11-88 FRAC JOB ET SURFACE BOTTO~ HOLE TIME PRESSURR PRESSURE MIN PSI PSI DATA PUMP RATE BPM SAND' CONC. PPG SLOPE ( LOG / LOG ) FLUID NO. STAGE 13.84 1143 13.93 1143 14.02 1133 14.10 1133 14.19 1133 3665 3665 3655 3655 3655 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 -0.5 -0.5 -2.3 -2.3 -1.2 14.28 1123 14.45 1123 14.54 1133 14.71 1123 14.80 1123 3645 3655 3648 3645 3645 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 -1. 14.89 1123 14.97 1123 15.06 1123 15.15 1123 15 ~3 1123 - 1'i2.3 15.45 1113 16.14 1103 16.24 1103 16.34 1103 3645 3645 3645. 3645 3645 · , '31635 3642 3625 3625 3625 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 ' 0..0 · ."~ '0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 -1. 0. 0. 0. 3 2 0 0 0 "0' 0 0 0 0 16.44 1113 16.54 1103 16.63 1103 16.73 1094 16.83 1103 3627 3625 3625 3622 3625 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 . 16.93 1094 17.02 1103 17.12 1094 17.22 1094 17.32 1094 3615 3625 3615 3622 3624 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 -0. 17.42 1094 17.52 1094 17.62 1094 17.71 1084 17.81 1084 361'5 3615 3615 3614 3614 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 -0. 17.91 1094 18.01 1084 18.11 1084 18.20 1084 18.30 1094 3615 3606 3606 3606 3615 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 -0. 18.43 1084 18.52 1084 18.68 1074 18 .'78 1084 18.88 1084 3614 3606 3605 3597 3606 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 -0. 0 0 0 0 0 ARCO ALASKA INC. 409747 FRAC JOB ET SURFACE BOTTOm4 HOLE TIME PRESSURe. PRESS~ MIN PSI PSI 18.98 1084 19.07 1064 19.17 1084 19.34 1074 19.44 1084 3606 3603 3597 3596 3597 19.53 19.63 19.73 19.83 19.92 1074 1074 1074 1074 1074 3604 3596 3596 3596 3596 20.02 20.12 20.22 20.31 20.41 -.. 2.G _ £ 20,61 20.71 20.81 20.90 1074 1064 1054 1064 1064 10~ 106% 1064 1064 1054 3596 3594 3592 3586 3586 3586 3586 3586 3584 DATA PUMP RATE BPM 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 SAND CONC. PPG 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 -. '0.0' 0.0 0.0 0.0 0.0 PAGE 5 DATE: 10-11-88 SLOPE FLUID (LO~ / LO~ ) NO. STAGE -0.8 0 -0.6 0 -0.6 0 -0.5 0 -0.5 0 -0.4 0 -0.4 0 -0.9 0 -0.9 0 -0.9 0 -0.9 0 -0.9 0 -0.9 0 -0.9 0 · 0.9 0 -1.5 '0' -1.5 0 -1.4 0 -1.1 0 -1.1 0 CUSTOMER WELL NAME : "ARCO ALASKA INC." "2T-07" RESERVOIR DATA E - YOUNG'S MODULUS, E+6 psi POISSON'S RATIO PERMEABLE HEIGHT, ft FRACTURE HEIGHT, ft RATIO OF PERMEABLE TO FRACTURE AREAS DATE 2.94 0.220 184.0 184.0 0.00 "10-11-88" JOB DATA FLUID VOLUME, gal PUMPING TIME, min n' - FLOW BEHAVIOR INDEX a - VISCOSITY DEGRADATION COEFFICIENT 4536 8.3 0.450 0 FALL-OFF PARAMETER CLOSURE PRESSURE, psi CLOSURE TIME, min · . ISIP (B..OTLI~..M HOLE)', · . 'P* MATCH DECLINE ~ESSURE, psi ~' '' K - CORRECTION FOR C WHILE PUMPING 3614 1 94 1.0 FLUID LOSS COEFFICIENT AND FRACTURE GEOMETRY EFFICIENCY (BASED ON TIME) FRACTURE GEOMETRY MODEL FLUID LOSS COEFFICIENT, ft/sqr(min) FRACTURE LENGTH (one wing), ft FRACTURE WIDTH (average), in 0.474 PK 1.45E-03 75 0.1319 KGD - 1.44E-03 75 0.1306 EFFICIENCY (BASED ON PRESSURE) FRACTURE GEOMETRY MODEL FLUID LOSS COEFFICIENT, ft/sqr(min) FRACTURE LENgtH (one wing), ft FRACTURE WIDTH (average), in 0.462 PK 1.45E-03 73 0.1259 KGD 1.42E-03 74 0.1230 RAD 1.13E-03 106 0.1023 RAD 1.12E-03 105 0. 0968 EFFICIENCY (AVERAGE) FRACTURE GEOMETRY MODEL FLUID LOSS COEFFICIENT, ft/sqr(min) FRACTURE LENGTH (one wing), ft FRACTURE WIDTH (average), in 0. 468 PK 1.45E-03 74 0.1288 KGD 1.43E-03 75 0.1268 RAD 1.12E-03 106 0.0995 PARAMETE~ VALIDATION ISIP (from FALL-OFF regression), psi P* (from Pc , tc and ISIP), ISIP (from Pc , tc and P*), tc (from Pc , P* and ISIP), Pc (from tc , P* and ISIP), 3765 90 3772 10.5 3607 I,I FRACTURE B.H.P. vs PRESSURE DECLINE DELTA (SORT) PLOT 8000 7000 6O0O 5000 4000 3000 20OO 0.0 -- I I I I I I I I I I I I I I I"I~ I I I I ! I I I I I'1 I I I I I I I I I I I I I I 1 I I I I I 1 I 1 I I 0.5 1.,'0 1.5 2.0 2.5 3.0 SORT (T + DT) - S©RT (DT), minl,/2 8000 ~ 7000 4000_ - - 3000 _ 2000-, 0.0 FRACTURE PRESSURE DECLINE B. H. P. v's SORT (DELTAT) PLOT o. I I I I I I I I I 2.0 SQ'RT (DELTA T) , minl/2 '~ ..... i i I i i I i I .0 4.0 i_ / ,'- 3800 3750 3700 5650 3600 5550 5500 FRACTURE PRESSURE HORNER PLOT DECLINE 1 10 HORNER TIME, (T + DT) ,/ DT FRACTURE PRESSURE DECLINE B. H.. P. vs DELTA T PLOT LJ LLJ 8OOO 7000 6OOO 5OOO 4000 3OOO 20OO 0.0 2.0 4.0.' 6.0 8.0 10.0 12.0 14.0 SHUT-IN TIME , min FRACTURE PRESSURE M D H PLOT DECLINE 3800 3750 3700 3650 3600 0 3550 35O0 1 10 0.1 SHUT-IN TIME , min 8OOO ~ 7000 i cn 6000 - (.f) - ~,, 5000 - _j - 0 - I - ~ 4000- 0 - 0 , 03 - 3000 ,': 2000 - 1.0 FRACTURE PRESSURE B. H. P. vs g (rD) DECLINE PLOT i I I 'i I I I I I ' I I I, '.1 I I I I I ' I' I I I I 1.5 2.0 LOSS VOLUME FUNCTION I I I I: I- I 2.5 g(tD) FRACT~ IRE PRESSURE DECLINE DIAGNOSTIC PLOT 1000 _ 100 ' 10 0.1 I I I I I I ""~. I I EQUIVALENT I I' I I 1 I I I I I 10 100 TIME , min 2T-07 MINI-FRAC TEST OCTOBER 11, 1988 JOB DESCRIPTION: The mini-frac test called for pumping 300 bbls. of BJ Titan RXL-4 w/5% diesel + 40 ppt Silica Flour at 20 BPM. 19.1 BPM was achieved 5.42 minutes into the stage and flucuated between 19 and 20 BPM until 8.54 minutes. At that time the inability to open frozen tank valves forced a manditory reduction in rate and finally a total shut down at 10.4 minutes into the job. Due to the slow shut down and various attempts to regain rate, and the fact that only 173 bbls of fluid had been pumped, it was decide~ the pressure decline data was invalid..At that time t~ decision was~made to. abOrt.the mini' frac and flush the well' with diesel. The STP's observed during the pumping ranged from 4,778 to 5,301 psi, which was again higher than anticipated. After considerable thought the decision was made to pump the orginal frac design as planned, with one exception. The decison was made to reduce the rate to 15 BPM prior to starting the sand stages in order to reduce high sand friction that would be encountered. JOB TICKET # : CUSTOMER : ARCO ALASKA INC. DATE OF JOB : 10-11-88 POST JOB REPORT SIMULTANEOUS PLOT OF JOB PARAMETERS 25.0 - 25,0 22.5 S 1~.0 12.5 10.0 7.~ 5.8 2.5 8.8 , , , 28.8 .................. ....... , ........... 4888 P 428t] ' , I ...................... I 248~P 7.~ ....... 18~ 5.8 ................. 1288 2.~ ........................ 688 I 8.8 3.1 6.3 9.4 12.6 15.7 18.9 22.8 17.5; 12.5 16.6 JOB TICKET # : CUSTOMER : ARCO ALASKA INC. DATE OF JOB : 10-11-88 POST JOB REPORT SURFACE TREATING PRESSURE VS TIME I 8 8.8 2.8 5.S 8.3 11.8 13.8 16.5 19.3 22.8 TI~, {~ IWtJTi2{ JOB TICKET # : CUSTOMER : ARCO ALASKA INC. DATE OF JOB : 10-11-88 POST JOB REPORT TOTAL SLURRY PUMP RATE VS TIME , · ' I ' I ' I ' I ' I ' 1~.~ 18.~ 7.58 5.88 8.88 8.8 2.8 5.5; 8.3 11.8 13.8 16.5 19.3 T I{'{E, im I{'IUTE~ JOB TICKET # : CUSTOMER : ARCO ALASKA INC. DATE OF JOB : 10-11-88 POST JOB REPORT CALCULATED BOTTOM HOLE TREATING PRESSURE VS TIME C ~ 5469 L. C 4666 .U ~ 2488 1988 1298 8 6.9 I ' I ' ' I ' I "' '1 " ' I ' ' ' 2.8 6.5 8.3 1t.6 13.8 16.5 ],9.3 TI~, I'IIHUTES JOB TICKET # : CUSTOMER : ARCO ALASKA INC. DATE OF JOB : 10-11-88 POST JOB REPORT SURFACE AND BOTTOM HOLE PRESSURE VS TIME 8888 H 64~ 4688. P 2488 P I 6.6 ~ ]~ ~ 666 P S 6 I 2.8 5.5 8.3 t.1.6 13.8 !6.5 1.9.3 22.6 T ll'lX, I'IIItUT~ ARCO ALASKA INC. FRAC JOB ET SURFACE ~ HOLE TIME PRESSURE PRESSURE MIN PSI PSI 0.00 995 0.09 995 0.18 995 0.29 995 0.38 2394 0.46 2808 0.55 2680 0.64 2877 0.73 3054 0.82 3478 0.91 3616 1.00 4059 1.08 4581 1.17 4700 1.26 4867 1.34- 4985 1.44 4995 1.53 5005 1.62 4995 1.71 4926 1.80 4611 1.89 4315 1.98 4453 2.06 4443 2.15 4640 2.24 5182 2.33 5340 2.42 5310 2.51 5261 2.60 5192 2.69 5163 2.78 5104 2.87 5123 2.96 4946 3.05 4828 3.13 4778 3.22 4769 3.31 4778 3.39 4798 3.48 4818 3.57 4847 3.66 4867 3.75 4897 3~84 4956 3.93 4975 3517 3527 3517 3289 4693 5232 4599 4498 4407 4234 4222 4277 4611 4590 4626 472.1 4709 4700 4685 4661 4420 4226 4402 4362 4406 4709 4557 4471 4428 4315 4284 4217 4223 4095 3900 3814 3772 3800 3836 3892 3885 3911 3956 3994 4041 DATA PUMP RATE BPM 0.0 0.0 0.0 0.6 0.6 2.1 3.3 4.8 7.2 10.4 11.6 13.4 14.8 15.5 16.0 16'.3- 16.4 16.5 16.5 16.5 15.9 14.4 15.2 15.4 15.7 17.3 18.9 19.1 19.1 19.3 19.3 19.4 19.4 19.5 19.5 19.7 19.8 19.8 19.7 19.5 19.6 19.6 19.6 19.4 19.5 SAND CONC. PPG 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 PAGE 1 DATE: 10-11-88 SLOPE FLUID ( LOG / LOG ) NO. STAGE 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0.0 -0.7 -0.7 -0.6 -0.6 -0.7 -0.5 -0.5 -0.1 0.1 0.1 0.1 -0.0 -0.0 -2.1 -2.1 -0.6 -0.4 -0.4 1.3 1.3 -0.2 -0.2 -1.3 -1.6 -1.6 -1.3 -1.3 -4.2 -4.2 -5.2 -2.1 -2.1 0.4 0.4 1.2 3.0 3.0 0 0 0 0 0 · Stage ARCO ALASKA INC. ET SURFACE TIME PRESSURE MIN PSI 4.04 5035 4.12 5094 4.21 5113 4.30 5143 4.39 5182 4.48 4.57 4.66 4.74 4.83 4.92 5.01 5.10 5.19 5.28 · . 5.37 ' 5.45 5.54 5.63 5.72 FRAC JOB DATA BOTTO~ HOLE PUMP PRESSUR~ RATE PSI BPM SAND CONC. PP~ 4130 19.4 0.0 4203 19.1 0.0 4222 19.4 0.0 4171 19.7 0.0 4240 19.6 0.0 5192 4288 19.4 0.0 5192 4339 19.4 0.0 5202 4302 19.4 0.0 5202 4340 19.2 0.0 5222 4345 19.3 0.0 5232 5232 5251 5281 ,5281 53~_~ 5310 5291 5301 5301 4350 19.3 4355 19.3 4385 19.2 4250 20.0 4259 20.0 4285 ~ 19..9 4301 19.9 4294 19.9 4274 20.0 4274 19.9 0.0 0.0 0.0 0.0 0.0 '. '0.:0 0.0 0.0 0.0 0.0 5.81 5291 4260 20.0 0.0 5.90 5291 4284 19.9 0.0 5.99 5301 4285 19.9 0.0 6.07 5291 4298 19.8 0.0 6.15 5301 4276 20.0 0.0 6.24 5301 4299 19.9 0.0 6.33 5301 4289 19.9 0.0 6.42 5301 4276 20.0 0.0 6.51 5291 4307 19.9 0.0 6.60 5291 4309 19.8 0.0 6.69 5291 4307 19.8 0.0 6.78 5291 4324 19.6 0.0 6.87 5301 4304 19.8 0.0 6.95 5301 4298 19.8 0.0 7.04 5291 4337 19.6 0.0 7.13 5291 4297 19.8 0.0 7.21 5291 4295 19.8 0,0 7.30 5281 4311 19.7 0.0 7.39 5291 4322 19.7 0.0 7.48 5301 4311 19.9 0.0 7.57 5291 4378 19.5 0.0 7.65 5291 4322 19.7 0.0 7.74 5301 4354 19.6 0.0 7~83 5291 4363 19.5 0.0 7.92 5291 4342 19.6 0.0 PAGE 2 DATE: 10-11-88 SIX)PR FLUID ( LO(]/LO(] ) NO. STA~E 3.7 0 3.7 0 5.1 0 -0.6 0 -0.6 0 1.9 0 1.9 0 1.1 0 1.5 0 1.5 0 1.0 1.0 0.9 0.9 -0.5 -0.5 -0.3 -0.3 -0.2 -0.1 -0.1 0.1 0.1 0.5 0.5 0.4 -1.4 -1.4 0.3 0.3 1.4 0.3 0.3 1.5 1.5 -1.1 -1.1 0.0 -0.2 -0.2 0.3 0.3 1.1 0.1 . 0 0 0 0 ARCO ALASKA INC. ET SURFACE TIME PRESSURE MIN PSI 8.01 5291 8.10 5291 8.18 5281 8.27 5281 8.36 5271 8.45 5271 8.54 5232 8.63 4542 8.71 4562 8.80 4562 8.89 4571 8.98 4581 9.06 4581 9.15 4601 9.24 462? 9.~3 4631 9.42 4631 9.50 4640 9.59 4660 9.68 4670 9.77 4503 9.86 2739 9.95 2739 10.05 2769 10.14 1695 10.22 1458 10.31 1291 10.40 1291 10.49 1291 10.57 1291 10.66 1301 10.75 1301 10.86 1301 10.95 1301 11.06 1291 11.15 1291 11.23 1291 11.32 1291 11.41 1301 11.50 1291 11.59 1488 11.67 1429 11.76 1409 11.94 1379 12.02 1360 FRAC JOB DATA BOTTOM HOLE PUMP SAND PRESSURE RATE CONC. PSI BPM PPG 4359 19.5 0.0 4327 19.7 0.0 4551 18.6 0.0 4231 20.1 0.0 4432 19.1 0.0 4377 19.4 0.0 4187 20.1 0.0 4074 18.2 0.0 4109 17.2 0.0 4166 17.4 0.0 4085 17.4 0.0 4153 17.0 0.0 4113 17.3 0.0 4187 17.1 0.0 4136 17.4 0.'0 4178 17.2 4232 17.0 4222 17.2 4251 17.3 0o0 ' 0.0 0.0 0.0 0.0 PAGE 3 DATE: 10-11-88 SLOPE FLUID (LOG/LOG) NO. 0.1 0 -0.3 0 -0.3 0 3.5 0 3.5 0 1.4 0 -3.9 0 -3.9 0 -8.8 0 -8.8 0 -4.5 0 0.8 0 O.8 0 1.6 0 1.6 0 0.3- 0 0.3 0 0.5 0 0.5 0 1.9 0 4139 16.8 0.0 2.4 3784 10.8 0.0 2.4 3690 9.6 0.0 -39.0 3751 9.5 0.0 -39.0 3552 8.6 0.0 -14.8 STAGE 3420 3.0 0.0 -136.8 0 3488 1.1 0.0 -136.8 0 3812 0.0 0.0 -21.4 0 3812 0.0 0.0 -21.4 0 3812 0.0 0.0 -16.9 0 3822 0.0 0.0 -16.9 0 3822 0.0 0.0 -8.8 0 3822 0.0 0.0 -4.4 0 3822 0.0 0.0 -4.4 0 3812 0.0 0.0 -1.8 0 3812 0.0 0.0 3812 0.0 0.0 3812 0.0 0.0 3819 0.0 0.0 3803 0.0 0.0 4010 0.0 0.0 3950 0.0 0.0 3931 0.0 0.0 3901 0.0 0.0 3885 0.0 0.0 -1.8 -1.7 -0.3 -0.3 -0.0 -0.0 27.3 27.3 -4.3 -4.3 ARCO ALASKA INC. FRAC JOB DATA ET SURFAC~ ~ ~ HOLE TIME PRES8~,. '~UP~ MIN PSI PSI PUMP RATE BPM SAND CONC. PPG 12.27 1350 3872 0.0 0.0 12.36 1350 3872 0.0 0.0 12.83 1330 3852 0.0 0.0 12.91 1330 3862 0.0 0.0 13.00 1330 3852 0.0 0.0 13.18 1330 3852 0.0 0.0 13.27 1320 3849 0.0 0.0 13.52 1320 3842 0.0 0.0 13.61 1310 3832 0.0 0.0 13.75 1310 3832 0.0 0.0 13.84 1310 13.93 1310 14.01 1310 14.10 1310 14~19 1310 . 14.36 1310 14.45 1301 14.54 1754 14.63 1911 14.71 1468 14.80 1429 14.88 1409 14.97 1409 15.06 1399 15.14 1399 15.23 1379 15.31 1379 15.40 1379 15.49 1369 15.57 1369 15.66 1360 15.75 1379 15.84 1350 15.92 1350 16.01 1350 16.09 1340 16.18 1350 16.26 1340 16.35 1320 3832 3832 3832 3822 3832 375'5 3832 3822 4276 4656 0.0 0.0 0.0 0.0 0.0 0.2 0'.0 0.0 0.0 0.0 3996 3950 3931 3931 3921 0.0 0.0 0.0 0.0 0.0 3921 3911 3901 3901 3891 0.0 0.0 0.0 0.0 0.0 3891 3881 3895 3881 3872 0.0 0.0 0.0 0.0 0.0 3872 3872 3872 3862 3862 0.0 0.0 0.0 0.0 0.0 3862 3852 3852 3852 3849 0.0 0.0 0.0 0.0 0.0 16.44 1340 16.53 1330 16.61 1330 16.'70 1330 16.78 1320 0.0 0.0 0.0 0.0 0.0. .- - --0,'o ' 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 PAGE 4 DATE: 10-11-88 SLOPE FLUID (LOG/LO~) NO. STAGE -3.4 0 -3.4 0 1.0 0 1.0 0 -9.2 0 -4.6 0 -4.6 0 -4.5 0 -4.5 0 -3.3 0 -3.3 -1.4 -1.4 1.5 1.5 --0.8 -0.8 -0.5 12.3 12.3 28.9 28.9 -8.6 -8.6 -5.8 -5.8 -3.7 -3.4 -3.4 -2.1 -2.1 -1.8 -1.8 2.9 -3.6 -3.6 -1.1 -1.1 -0.7 -0.7 -3.7 -3.7 -0.4 -0.1 -0.1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ARCO ALASKA INC. ET TIME MIN FRAC JOB SURFAC~ BOTTOM HOLE PRESStH~-"~-~ PP.~SSURE PSI PSI DATA PUMP RATE BPM SAND CONC. PPG 16.87 1330 3842 0.0 0.0 16.96 1320 3842 0.0 0.0 17.04 1330 3849 0.0 0.0 17.13 1320 3849 0.0 0.0 17.23 1320 3842 0.0 0.0 17.41 1320 3842 0.0 0.0 17.49 1823 4246 0.0 0.0 17.58 2788 4837 0.2 0.0 17.67 2542 4475 3.2 0.0 17.76 2374 3708 8.0 0.0 17.85 17.94 18.03 18..12 18 '~4 18.51 18.59 18.68 1-8.76 18.84 18.93 19.02 19.11 19.20 19.28 19.37 19.46 19.54 19.63 19.72 19.81 19.90 19.98 20.07 2138 1744 1163 1192 1192 1202 1192 1202 1192 3350 3677 3517 3707 3714 · ~ 3 '14 3724 3714 3724 3721 1202 1182 1202 1202 1212 3724 3704 3724 3724 3734 1202 1192 1212 1202 1212 3724 3724 3734 3724 3734 1212 1192 1212 1212 1212 3734 3729 3734 3734 3734 1212 1379 1852 2374 2374 3734 3901 4335 4601 4896 2276 2384 4179 4024 20.16 20.25 20.33 20.42 20.51 20.60 20.68 3.6 3.2 0.4 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 3.4 5.4 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 PAGE 5 DATE: 10-11-88 SLOPE FLUID (LOG/LOG) NO. STAG~ -1.2 0 -1.2 0 0.7 0 0.7 0 -0.7 0 1.3 0 20.7 0 20.7 0 54.7 0 54.7 0 -55.6 0 -11.3 0 -11.3 0 -20.5 0 -18.2 0 -,14..5. -14.5 -9.3 -9.3 -5.6 -5.6 -2.8 -1.1 -1.1 -0.3 -0.3 -0.1 -0.1 2.7 0.5 0.5 0.1 0.1 -3.0 -3.0 2.4 0.5 0.5 103.5 103.5 25.2 25.2 0 0 0 0 0 0 0 0 0 2T-07 (A&C SAND) FRACTURE STIMULATION OCTOBER 12, 1988 JOB DESCRIPTION: The 2T-07 frac was performed on 10-12-88. The treatment was designed to stimulate 184 net feet of the Kuparuk A & C Sands. Due to the high STP's encountered during the Data Frac, the decision was made to reduce the rate to 15 BPM prior to starting the sand stages. Pumping began with a 465 bbl Pad stage of BJ Titan RXL-4 w/5% Diesel + 40 ppt Silica Flour. 20 BPM was achieved at 5.5 minutes into the job. The average STP during the Pad was approximately 4,575 psi. At 26.7 minutes into .the job the rate was reduced to 15 BPM and the. following sand st.ages were pumped. ' . . ~. 40'bbi of 2 PPG'~ 40 bbl of 4 PPG 50 bbl of 6 PPG 82 bbl of 8 PPG 85 bbl of 10 PPG 96 bbl of 12 PPG At 52.7 minutes into the job flush was staged and a forced shut down due to a slow opening valve on the slick diesel tank occured. At 55.6 minutes flush continued with slurry from the tub. At 56.3 minutes the slick diesel replaced the tub slurry for the remainder of the 36 bbl flush. At 58.17 minutes the job was pumped to completion. The computer calculated 89,295 lbs of 16-20 Carbo-Lite had been pumped. Steve Chambers, Dane Cantwell, John Currier, Anne Lowen, and Gary Limb were the ARCO personnel attending the job. JOB TICKET # : 409747 CUSTOMER : ARCO ALASKA INC. DATE OF JOB : 10-12-88 POST JOB REPORT SURFACE TREATING PRESSURE VS TIME F 48~ 1888 P I 12.3 24.5 36.8 49.1 61.4 ?3.6 85.9 98.2 TIIIE, M Iltll~ JOB TICKET # : CUSTOMER.' 409747 ARCO ALASKA INC. DATE OF JOB : 10-12-88 POST JOB REPORT SIMULTANEOUS PLOT OF JOB PARAMETERS 8.8 14.8 28.1 42.1 F~.! '/8.1 84.2 98.2 TIIIE, HIMIJTI~ JOB TICKET # : 409747 CUSTOMER : ARCO ALASKA INC. DATE OF JOB : 10-12-88 POST JOB REPORT PROPPANT CONCENTRATION VS TIME P R 13.~ ............. 0 P 12.88 ................................... ,p ., T 9.~ .................. ¢ ?.58 0 N 6.8~ ........................................... P P 1.58 8.~ 24 34.8 39.6 44.6 49.8 TillS, I'1111iJTES 54.8 59.6 64.8 JOB TICKET # : 409747 CUSTOMER : ARCO ALASKA INC. DATE OF JOB : 10-12-88 , POST JOB REPORT CALCULATED BOTTOM HOLE TREATING PRESSURE VS TIME 8696 C ~ 7296 L C ~ : -.. B 3288 It T 2488 P I 8 6.6 I ' I 12.3 24.5 36,.8 49.1 61.4 73.6 85.9 TIFIE, i111qUTE3 JOB TICKET # : CUSTOMER : 409747 ARCO ALASKA INC. DATE OF JOB 10-12-88 POST JOB REPORT NET BOTTOM HOLE PRESSURE VS TIME (LOG/LOG SCALE) 1979 1.8 1.8 3.1 5;.6 9.9 17.6 31.2 55.3 98.2 TI{l{, {'{ I~'1'~{ JOB TICKET # : 409747 CUSTOMER : ARCO ALASKA INC. DATE OF JOB : 10-12 -88 POST JOB REPORT SURFACE AND BOTTOM HOLE PRESSURE VS TIME I~TP <Z> BI4TP 7298 5488 S IJ 888 688 P 0 8.8 12.3 24.5 36.8 49.1 61.4 73.6 85.9 98.2 'rl~, {'{ IItITEI{ ARCO ALASKA INC. 409747 FRAC JOB DATA ET SURFACE TIME PRESSURE MIN PSI BOTTOM HOLE PUMP SAND PRESSURE RATE CONC. PSI BPM PPG 0.06 1153 0.24 1163 0.41 1133 0.58 1123 0.79 1113 3675 0.0 0.0 3684 0.0 0.0 3655 0.0 0.0 3645 0.0 0.0 3635 0.0 0.0 0.97 1.14 1.32 1.50 1.68 1094 3625 0.0 1103 3625 0.0 1251 3734 0.0 1921 4091 1.5 3084 4566 6.3 1.86 2.04 2.22 2.39 2 '~ , '2. 2.91 3.09 3.27 3.45 4030 4798 5153 5675 5941 '5842 5744 5606 5438 5320 5106 5609 5906 6228 6403 · ~ 27o 6144 5977 5798 5641 8.2 9.9 10.8 11.9 12,5 12:6, 12.8 12.9 13.1 13.2 .62 .80 .97 .14 .32 5301 5330 5212 4985 4818 5576 5459 5255 5033 4766 13.4 14.2 14.6 14.8 15.2 .5O .67 .84 .01 .33 5025 4591 3951 3517 4305 4637 4194 3526 3014 3105 16.7 17.1 17.1 15.5 19.4 .50 .68 .86 .25 .42 4315 4266 4237 4256 4246 3248 3186 3159 3185 3161 20.2 20.2 20.2 20.2 20.3 .59 .77 .99 .16 .34 4266 4296 4355 4394 4414 3184 3223 3262 3318 3317 20.2 20.1 20.3 20.2 20.2 7.61 7.78 8.02 8;19 8.37 4473 4512 4522 4512 4512 3367 3447 3457 3419 3435 20.3 20.2 20.2 20.3 20.1 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 .0 .0 .0 .0 .0 .0 .0 .0 .0 .0 .0 .0 .0 .0 .0 PAGE 1 DATE: 10-12-88 SLOPR FLUID (LOC / LO~ ) NO. STAGE 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 1.5 0 4.7 0 4.1 0 2.6 0 1.7 0 1.9 0. 0,7 0 -0.2 0 -0.8 0 -1.6 0 -1.5 0 -1.7 0 -0.7 0 -1.5 0 -2.5 0 -3.8 0 -5.0 0 -12.7 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 28.1 0 21.3 0 6.2 0 19.5 0 0.0 0 0.0 0 0.0 0 Stage # ARCO ALASKA INC. 409747 FRAC JOB DATA ET SURFACE TIME PRESSURE MIN PSI ~ HOLE PUMP SAND PRESSURE RATE CONC . PSI BPM PPG 8.55 4542 8.78 4493 8.95 4473 9.13 4512 9.30 4483 3416 20.3 0.0 3411 20.3 0.0 3426 20.2 0.0 3441 20.2 0.0 3418 20.2 0.0 9.47 4473 9.71 4483 9.89 4473 10.07 4473 10.25 4483 3412 20.1 0.0 3420 20.1 0.0 3377 20.3 0.0 3420 20.1 0.0 3409 20.1 0.0 10.41 4483 10.59 4493 10.77 4483 10.95 4473 11.12 4493 i- 3 4.483 '11.47 4483 11.64 4483 11.82 4493 12.00 4493 3402 20.2 0.0 3410, 20.1 0.0 3433 20.1 0.0 3430 20.1 0.0 3422 20.2 0.0 341'8 - 20.2 0.0 3429 20.1 0.0 3443 20.2 0.0 3441 20.2 0.0 3434 20. I 0.0 12.18 4473 12.39 4503 12.56 4493 12.74 4503 12.92 4493 3425 20.1 0.0 3444 20.1 0.0 3413 20.2 0.0 3463 20.1 0.0 3423 20.2 0.0 13.10 4503 13.31 4493 13.48 4512 13.65 4512 13.83 4512 3425 20.2 0.0 3408 20.3 0.0 3443 20.2 0.0 3460 20.1 0.0 3428 20.3 0.0 14.01 4522 14.19 4512 14.39 4512 14.56 4512 14.74 4522 3451 20.2 0.0 3446 20.2 0.0 3441 20.2 0.0 3487 20.1 0.0 3455 20.2 0.0 14.92 4512 15.10 4522 15.31 4532 15.48 4522 15.66 4512 3434 20.2 0.0 3467 20.1 0.0 3495 20.0 0.0 3477 20.1 0.0 3478 20.1 0.0 15.84 4522 16.02 4522 16.20 4532 16:40 4552 16.57 4542 3483 20.0 0.0 3446 20.2 0.0 3465 20.2 0.0 3519 20.0 0.0 3530 20.1 0.0 PAGE 2 DATE: 10-12-88 SLOPE FLUID ( LOG /LOG ) NO. STAGE 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 11.5 0 3.3 0 4.7 0 0.6 0 1.5 0 1.1 0 -0.4 0 2.2 0 1.5 0 1.5 0 0.9 0 0'.8 0 0.8 0 0.6 0 0.6 0 -0.5 0 -0.9 0 -1.7 0 -0.7 0 -0.7 0 -0.5 0 -1.0 0 -1.0 0 -1.3 0 -1.3 0 -2.1 0 -2.1 0 -2.2 0 -0.8 0 -0.8 0 0.3 0 0.3 0 -0.4 0 0.9 0 0.9 0 0.2 0 0.2 0 -0.3 0 0.3 0 2.9 0 ARCO ALASKA INC. 409747 FRAC JOB DATA ET SURFACE TIME PRESSURE MIN PSI ~ HOLE PUMP SAND- PRESSUR~ RATE CONC. PSI BPM PPG 16.75 4542 16.93 4552 17.11 4552 17.31 4552 17.48 4562 3486 20.1 0.0 3495 20.1 0.0 3502 20.1 0.0 3532 20.0 0.0 3527 20.0 0.0 17.66 4552 17.84 4571 18.02 4571 18.20 4581 18.40 4591 3500 20.1 0.0 3535 20.0 0.0 3528 20.1 0.0 3522 20.1 0.0 3537 20.1 0.0 18 18 18 19 19 20 20 .57 4562 .75 4571 .93 4581 .11 4571 .~ 4581 .49 4581- .6'7 4562 .85 4562 .03 4562 .21 4552 3510 3524 3510. 3539 3510 350'3 3499 3518 3507 3504 20.1 20.1 20.2 20.0 20.2 .. · 2'012 20.1 20.1 20.1 20.1 20.41 4532 20.58 4552 20.76 4562 20.94 - 4552 21.18 4552 3487 3506 3531 3498 3515 20.1 20.1 20.0 20.1 20.1 21.35 4562 21.53 4562 21.71 4571 21.89 4571 22.07 4581 3505 3523 3503 3532 3557 20.1 20.1 20.1 20.0 20.0 22.25 4562 22.42 4562 22.59 4562 22.77 4571 22.95 4562 3527 3531 3523 3548 3540 20.0 20.0 20.0 20.0 20.1 23.13 4571 23.34 4571 23.51 4562 23,69 4562 23.87 4581 3539 3539 3520 3495 3514 20.0 20.0 20.0 20.2 20.2 24.05 4571 24.23 4571 24.43 4571 24.61 4581 24.80 4591 3556 3530 3545 3536 3567 19.9 20.1 20.0 20.0 20.0 0.0 0.0 0.0 0.0 0.0 0'.0 '. 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 PAGE 3 DATE: 10-12-88 SLOPE FLUID (LO~/LO~) NO. STAGE 1.3 0 1.3 0 1.5 0 1.3 0 1.3 0 1.2 0 1.2 0 0.4 0 0.4 0 -1.2 0 -0.5 0 -0.4 0 -0.6 0 -0.9 0 0..4 - 0 .' ~0.'1' 0 -1.2 0 1.4 0 1.4 0 1.7 0 0.8 0 0.8 0 1.7 0 1.7 0 1.9 0 1.4 1.4 1.4 1.4 1.9 1.5 1.5 1.3 0.7 1.1 1.1 2.0 1.6 1.5 2.1 3.7 2.0 -0.0 0.2 3.5 ARCO ALASKA INC. 409747 FRAC JOB DATA ET SURFACE TIME PRESSUR~ MIN PSI BOTTOM HOLE PUMP SAND PRESSURE RATE CONC. PSI BPM PPG 24.97 4591 25.15 4581 25.35 3626 25.52 3606 25.70 3626 3546 20.1 0.0 3534 20.1 0.0 3487 15.6 0.0 3489 15.5 0.0 3530 15.4 0.0 25.92 3616 26.09 3606 26.36 3576 26.54 3586 26.72 3586 3531 15.4 0.0 3544 15.3 0.2 3543 15.1 0.7 3550 15.1 1.0 3563 15.0 1.1 -26.89 3547 27.06 3507 27.24 3448 27.45 3458 2- ~ 3438 27.79 3448 27.96 3409 28.14 3389 28.31 3350 28.48 3350 3511 15.1 1.2 3465 15.1 1.3 3423 15.0 1.3 3409 15.1 1.3 340.1 .15..1 1.4 3397 1~.~ 1.4 3345 15.1 1.5 3327 15.1 1.5 3296 15.0 1.5 3279 15.0 1.6 28.66 3360 28.84 3360 29.02 3399 29.19 3399 29.38 3379 3278 15.0 1.6 3265 15.0 1.8 3300 15.0 2.2 3275 15.1 2.5 3244 15.1 2.8 29.63 3399 29.80 3389 29.98 3399 30.15 3409 30.33 3350 3279 15.0 3.0 3230 15.1 3.2 3187 15.0 3.3 3240 15.0 3.4 3156 15.0 3.6 30.51 3399 30.69 3409 30.86 3448 31.04 3448 31.21 3507 3185 15.0 3.6 3152 15.0 3.7 3194 15.0 3.7 3159 15.0 3.8 3214 15.0 3.9 31.39 3498 31.58 3537 31.98 3527 32.15 3567 32.33 3527 3196 15.0 3.8 3216 14.9 4.0 3153 14.9 4.5 3168 14.9 4.8 3119 14.9 4.9 32.50 3576 32.68 3596 32.86 3576 33 .'03 3567 33.20 3596 3142 14.9 5.0 3102 15.0 5.1 3102 14.9 5.1 3093 14.8 5.2 3076 14.9 5.3 PAGE 4 DATE: 10-12-88 SLOPE FLUID ( LOG / LOG ) NO. STAGE 5.3 0 2.0 0 -6.6 0 -13.6 0 1.2 0 12.3 0 6.1 0 9.2 0 3.1 0 -6.1 0 -6.1 0 -23.9 0 -16.8 0 -4.5 0 -17.5 0 '16.9 0 -15.6 0 -21.2 0 -37.9 0 -31.8 0 -40.4 0 -35.9 0 -7.7 0 -1.5 0 -10.6 0 -10.6 0 -6.8 0 -6.8 0 0.9 0 -8.7 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Stage # ARCO ALASKA INC. 409747 PAGE 5 DATE: 10-12-88 FRAC JOB DATA ET SURFACE BOI'TC~ HOLE TIME PRESSUR~' ~-~ PRESSURE MIN PSI '~ PSI PUMP RATE BPM SAND CONC. PPG SLOPE ( LO~ / LO~ ) FLUID NO. STAGE 33.44 3636 3127 15. 33.62 3714 3160 14. 33.79 3665 3112 14. 33.97 3714 3132 14. 34.14 3783 3125 14. 5.1 5.2 5.2 5.3 5.3 -0.4 -1.3 4.9 32.9 22.3 34.31 34.51 34.68 34.86 35.04 3764 3144 3714 3148 3793 3175 3764 3180 3813 3132 14. 14. 14. 14. 14. 5.3 5.4 5.6 5.9 5.9 27. 16. 16. 16. 11. Stage # 35. 35. 35. 35. 35. 36. 36. 36. 36. 37. 21 3842 3154 43 3852 3159 61 3842 3128 78 3911 3198 96 ,3882 3047 31 66 85 O3 38. '~ '~ .' 3'0'24 3'951 3087 3961 3036 4020 3041 4079 3109 14.8 14.8 14.8 15.1 1.5.0 14..9 15.0 14.8 14.9 14.8 6.4 6.8 7.1 7.2 7;3 7.2 7.4 7.4 7.5 . -53. 8. 65. '0' 0 0 0 0 37. 37. 37. 37. 37. 19 4138 3106 14. 37 4197 3098 14. 54 4138 3060 14. 72 4256 3114 14. 90 4266 3064 14. 7.4 7.6 7.6 7.7 7.8 -91. 33. 15. -75. -12. 3 6 7 6 9 38. 38. 38. 38. 38. 38. 39. 39. 39. 39. 39. 40. 40. 40. 40. 07 4148 2962 24 4237 2995 44 4177 3027 61 4168 2942 79 4207 2966 96 4158 2910 13 4148 2870 30 4128 2845 53 4118 2803 70 3281 2504 14. 14. 14. 14. 14. 14. 14. 14. 14. 13. 87 3941 2836 14. 06 3941 2941 14. 23 3980 2834 14. 46 4049 2948 14. 63 4138 2935 14. 7.8 7.8 7.8 7.9 7.9 7.9 8.0 8.1 8.1 8.3 8.2 7.9 8.1 8.5 8.6 O. 0. 0. 0. 0. . 0. 0. 0. O. O. 0. 0. 0. 0. 0 0 0 0 Stage # 0 ' 40.81 40.98 41.16 41;33 41 .'55 4473 3017 4237 2954 4345 3038 4503 3109 4660 3195 15. 14. 14. 14. 15. 8.4 7.5 6.9 6.8 8.2 . 0. 0. -27. 28. ARCO ALASKA INC, 409747 FRAC JOB DATA ET SURFACE TIME PRESSURE MIN PSI BOTTOM HOLE PUMP SAND PRESSURE RATE CONC. PSI BPM PPG 41.72 4700 41.90 4719 42,07 4719 42.25 4650 42.47 4640 3200 15,0 8.3 3216 15.0 8.4 3221 '15.2 8.3 3096 15.1 8.5 3066 15.2 9.3 42.64 4611 42.81 4591 43.00 4552 43.17 4522 43.35 4552 2990 15.2 9.2 2946 15.2 8.9 2868 15.2 8.7 2872 15.1 8.9 2901 15.1 9.1 43.57 4532 43.82 4463 44.00 4473 44.17 4493 44.~-4 4503 %4.57 , 4'532 44.75 4562 44.92 4621 45.09 4660 45,31 4680 2880 15.1 9.3 2686 15,2 9.5 2610 15.2 9.8 2599 15.2 10.-0 2564 15.2 .10.0 255.0 15. 2 2511 15.2 2576 15.1 2584 15.1 2588 15.1 45,51 4670 45.69 4650 45.87 4621 46.08 4542 46.25 4571 10.1 10.1 10.1 10.1 10.2 46.49 4453 46.66 4473 46.84 4394 47.01 4374 47.19 4345 2510 15.2 10.4 2454 15.2 10.3 2323 15.3 10.3 2282 1.5.1 10.2 2318 15.1 10.6 47.36 4424 47,58 4374 47.76 4424 47.93 4493 48.11 4493 2220 15.1 10.9 2067 15.3 11.1 1987 15.1 11.4 1910 15.2 11.9 1932 15.0 12.2 48.28 4414 48.49 4601 48.67 4571 48.85 4581 49.02 4453 1791 15.3 12.3 1746 15.1 12.3 1662 15.3 12.4 1714 15.3 12.0 1680 15.1 11.6 49.19 4512 49.37 4374 49.59 4404 49.77 4315 49.95 4335 1754 15.0 11.4 1753 15.0 11.3 1742 15.0 11.6 1639 15.0 11.9 1526 14,9 12.1 1516 15.1 12.1 1451 14.7 12.1 1296 15.0 11.8 1216 15.0 11.7 1180 15.1 11.6 PAGE 6 DATE: 10-12-88 SLOPE FLUID ( LOG / LOG ) NO. STAGE 66.6 0 45.8 0 25.8 0 -29.6 0 -20.5 0 -78.8 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.0 0 0.o 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0,0 0.0 0.0 0,0 0,0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Stage # ARCO ALASKA INC. 409747 PAGE 7 DATE: 10-12-88 FRAC JOB DATA RT TIME MIN SURFACR ~ HOLE PR~SSUR~ PRESSURR PSI PSI PUMP RATE BPM SAND- CONC. PPG SLOPE (LO~/~) FLUID NO. STAGE 50.13 4355 1194 15.1 11.5 50.31 4345 1246 15.1 11.4 50.51 4237 1114 15.2 11.4 50.69 4315 1203 15.2 11.4 50.86 4325 1250 15.1 11.3 0.0 0.0 0.0 0.0 0.0 51.03 4384 1303 15.1 51.21 4414 1263 15.3 51.38 4414 1306 15.1 51.60 4365 1338 15.2 51.77 4404 1324 15.2 11 11 11 11 11 .4 .5 .4 .3 .4 .0 .0 .0 .0 .0 51.95 4424 1332 15.3 52.13 4443 1360 15.2 52.30 4266 1638 14.4 52.52 4640 1975 15.0 52.70 1153 5003 0.0 . . '52'.88 53.05 53.23 53.40 53.62 1'064 .. '4'9'44 1645 3550 1172 4617 1232 2333 571 4380 3.6 0.2 5.9 0.0 11.2 10.8 10.3 4.9 · . O..0 0.0 0.0 0.0 0.'0 0.0 0.0 0.0 0.0 0.0~ -52.2 -52.2 -46.3 -46.3 . - 0 0 0 0 53.79 601 4419 0.0 53.97 611 4429 0.0 54..15 601 4428 0.0 54.33 621 4438 0.0 54.56 611 4428 0.0 0.0 0.0 0.0 0.0 0.0 -37 -28 -11 -5 -0 .2 .8 .8 .9 .9 0 0 0 .0 0 54.73 601 4438 0.0 54.91 601 4418 0.0 55.09 650 4453 0.0 55.26 2128 3649 4.6 55.44 2384 3668 5.5 0.0 0.0 0.0 0.0 0.0 -1 -1 -261 -23 -39 .7 .1 .8 .8 .3 55.64 2926 3430 8.1 55.82 3123 3282 9.1 55.99 3498 3180 10.6 56.16 4010 3278 12.0 56.33 4897 4252 13.1 56.54 5379 4665 14.0 56.71 5419 4901 14.2 56.89 5448 5142 14.2 57.07 5409 5370 14.1 57.24 5429 5637 14.2 0.2 4.8 5.9 1.3 0.0 0.0 0.0 0.0 0.0 0.0 -44 -125 -95 -35 299 186 113 69 39 36 .2 .2 .4 .8 .8 .8 .8 .0 .9 .4 57.42 5409 5854 14.2 57.64 5370 6177 14.3 57.81 5301 6773 14.3 57;99 2631 4791 3.4 58.17 1931 4154 0.0 0.0 0.0 0.0 0.0 0.0 27.2 17.2 4.5 51.2 -132.4 ARCO ALASKA INC. 409747 FRAC JOB ET SURFACE ~ HOLE TIME PRESStTRE PRESStrRE MIN PSI PSI 58.34 1921 58.56 1921 58.73 1941 58.91 1941 59.08 1951 4177 4185 4200 4200 4210 59.26 1951 59.43 1941 59.65 1941 59.82 1970 60.00 1941 4210 4200 4200 4229 4200 60.17 1941 60.41 1941 60.65 1970 60.83 1931 61.00 .1941 61.'~3 19~~ 61.35 1941 61.57 1931 61.75 1941 61.92 1931 4200 4200 4229 4190 4200 4'200 4190 4190 4200 4190 62.10 1931 62.27 1931 62.45 1941 62.67 1931 62.84 1931 4190 4190 4200 4190 4190 63.02 1931 63.23 1931 63.41 1931 63.58 1931 63.76 1931 4190 4190 4190 4197 4190 63.93 1921 64.11 1931 64.28 1921 64.46 1911 64.68 1931 4187 4187 4185 4177 4190 64.85 1931 65.03 1921 65.20 1921 65.38 1921 65.60 1921 4190 4180 4180 4190 4195 65.77 1921 65.95 1921 66.12 1921 66~30 1931 66.-47 1921 4180 4180 4180 4190 4180 DATA PUMP RATE BPM 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 SAND CONC. PPG 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.-0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 PAGE 8 DATE: 10-12-88 SLOPE FLUID ( LOG / LOG ) NO. STAGE -153.7 0 -0.0 0 3.2 0 3.2 0 0.0 0 -3.1 0 0.6 0 -0.4 0 1.4 0 -0.7 0 -0.1 0 1.8 0 -1.2 0 1.1 0 1.6 0 -0.1 0 -1.0 0 -0.8 0 0.4 0 -0.3 0 -0.3 0 -0.2 0 O.8 0 -0.2 0 0.1 0 0.1 0 0.1 0 0.0 0 0.8 0 -0.1 0 1.0 0 1.0 0 1.6 0 1.6 0 0.9 0 0.9 0.5 0.3 0.3 0.4 0.4 0.3 0.3 -0.9 0.0 ARCO ALASKA INC. 409747 PAGE 9 DATE: 10-12-88 FRAC JOB DATA ET SURFACE TIME PRESSUBI~ MIN PSI ~ HOLE PUMP SAND- FR~SSUB~ RATE CONC. PSI BPM PPG SLOPE (LOG/LO~) FLUID NO. STAGE 66.70 1921 66.87 1911 67.05 1921 67.22 1911 67.40 1921 4187 0.0 0.0 4174 0.0 0.0 4180 0.0 0.0 4170 0.0 0.0 4180 0.0 0.0 0.0 0.0 -0.4 -0.7 -0.7 67.62 1921 67.79 1921 67.97 1911 68.14 1921 68.32 1902 4175 0.0 0.0 4170 0.0 0.0 4170 0.0 0.0 4180 0.0 0.0 4160 0.0 0.0 -0 -0 -0 -0 -0 .6 .6 .3 .3 .3 68.50 1911 68.72 1911 68.89 1911 69.06 1911 69.24 191! · 69.62 1911 .69.80 1902 69.97 1902 70.15 1902 4170 0.0 0.0 4170. 0.0 0.0 4170 0.0 0.0 4164 0.0 0.0 4164 0.0 .0.0 4 8o 0.o ...o.o 4164 0.0 0.0 4160 0.0 0.0 4160 0.0 0.0 4160 0.0 0.0 -0.2 -0.4 -0.4 -0.4 -0.5 '-0'~ 7 -0.6 -0.5 -0.3 -0.2 0 0 0 0 0 .. 0. 0 0 0 0 70.32 1902 70.50 1902 70.72 1892 70.90 1902 71.07 1902 4160 0.0 0.0 4160 0.0 0.0 4154 0.0 0.0 4160 0.0 0.0 4160 0.0 0.0 -0 -0 -0 -0 -5 .1 .0 .0 .0 .6 71.25 1902 71.42 1902 71.63 1882 71.80 1902 71.98 1902 4160 0.0 0.0 4160 0.0 0.0 4146 0.0 0.0 4160 0.0 0.0 4154 0.0 0.0 1 0 -1 1 0 .2 .5 .7 .7 .9 0 0 0 0 0 72.15 1902 72.33 1902 72.50 1902 72.72 1892 72.90 1902 4157 0.0 0.0 4160 0.0 0.0 4160 0.0 0.0 4151 0.0 0.0 4160 0.0 0.0 -2 1 0 0 -1 .0 .0 .6 .3 .5 0 0 0 0 0 73.08 1902 73.25 1892 73.43 1902 73.63 1892 73.81 1892 73.99 1902 74.16 1892 74.34 1892 74."51 1892 74.73 1892 4151 0.0 0.0 4160 0.0 0.0 4151 0.0 0.0 4156 0.0 0.0 4151 0.0 0.0 4160 0.0 0.0 4151 0.0 0.0 4151 0.0 0.0 4151 0.0 0.0 4141 0.0 0.0 -1.4 1.0 -2.0 -2.6 1.5 6.2 -2.4 -1.2 -0.5 -0.1 0 0 0 0 0 ARCO ALASKA INC. 409747 FRAC JOB ET SURFACE BOTTOM ROLE TIME PRESSURE PRESSURE MIN PSI PSI 74.90 1892 75.08 1892 75.25 1892 75.43 1882 75.64 1882 75.82 1882 75.99 1882 76.17 1911 76.34 1882 76.52 1882 76.74 1882 76.91 1882 77.09 1882 77.26 1882 77%44 1882 . · 77.65 1882 77.82 1892 78.00 1882 78.18 1872 78.35 1872 78.53 1872 78.74 1882 78.92 1872 79.09 1872 79.27 1882 79.44 1872 79.66 1872 79.83 1872 80.01 1872 80.18 1872 80.36 1872 80.53 1872 80.75 1872 80.92 1872 81.10 1872 81.28 1872 81.45 1862 81.67 1872 81.84 1872 82.02 1872 82.19 1862 82.37 1872 82 t54 1862 82.76 1872 82.94 1872 4151 4144 4151 4147 4141 4141 4141 4151 4141 4141 4141 4141 4141 4141 4141 4146 4141 4141 4131 4131 4131 4141 4141 4141 4141 4131 4136 4131 4131 4131 4131 4131 4131 4128 4131 4131 4121 4131 4134 4131 4151 4131 4121 4131 4131 DATA PUMP RATE BPM 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.-0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 SAND' CONC. PPG 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0- .. 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 PAGE DATE: SLOPE ( LOG /LOG ) 6.7 -4.8 -0.3 3.3 -1.6 -2.6 -0.8 -0.2 -0.0 0.0 0.0 0.0 0.0 0.6 0.9 -0.5 -1.2 -1.0 0.6 0.5 -0.5 0.5 -0.0 0.9 0.3 0.3 0.2 0.8 0.4 0.3 0.2 0.1 0.1 0.0 0.0 0.0 0.0 1.4 3.1 -3.8 -0.8 -0.1 -2.5 2.6 10 10-12-88 FLUID NO. STAGE ARCO ALASKA INC. 409747 PAGE DATE: 11 10-12-88 FRAC JOB DATA ET SURFACE TIME PRESSURE MIN PSI BOTTOM HOLE PUMP SAND PRESSURE RATE CONC. PSI BPM PPG SLOPE (LOG/LO~) FLUID NO. STAGE 83.11 1872 83.29 1872 83.46 1862 83.68 1862 83.85 1862 4141 0.0 0.0 4121- 0.0 0.0 4128 0.0 0.0 4126 0.0 0.0 4124 0.0 0.0 -1.8 -1.0 0.7 -0.1 0.4 84.03 84.21 84.38 84.56 84.78 1852 4111 0.0 0.0 1862 4121 0.0 0.0 1862 4121 0.0 0.0 1862 4124 0.0 0.0 1862 4121 0.0 0.0 0 -0 -0 0 0 .1 .3 .2 .7 .5 84.96 85.13 85.31 85.48 .8~ '-85.88 86~05 86.23 86.40 8'6.58 1882 1862 1852 1862 1872 1862 1852 1862 1862 1852 4141 4121 4111 4121 4126 · ,. · 4121 4121 4121 4121 4111 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 1.0 0.4 0.4 0.4 mO -0 -0 -0 -1 .7 .1 .1 .1 .0 0 0 0 0 O' . 0 0 0 0 86.80 86.97 87.15 87.32 87.50 1833 1833 1823 1813 1823 4098 4091 4082 4072 4062 0~0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 -0 -0 -1 -1 -1 .9 .9 .4 .7 .7 87.70 87.88 88.06 88.23 88.41 1803 1813 1803 1803 1793 4082 4072 4062 4062 4055 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 -0.9 -0.9 -0.8 0.4 -0.7 88.58 88.80 88.98 89.15 89.33 1793 1783 1783 1783 1793 4052 4042 4042 4052 4052 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 -1 -1 -1 -1 0 .6 .4 .4 .3 .9 0 0 0 0 0 89.50 89.71 89.89 90.06 90.24 1783 1793 1793 1793 1764 4052 4046 4046 4052 4023 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0 -0 0 0 0 .3 .1 .6 .0 .0 90.41 90.59 90.81 90.99 91.i6 1783 1793 1793 1783 1793 4042 4052 4052 4052 4052 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 -0.5 -0.5 -0.1 -0.1 -0.1 ARCO ALASKA INC. 409747 FRAC JOB ET SURFACE ~ HOLE TIME PRESSURE PRESSURE MIN PSI PSI 91.34 1793 91.51 1783 91.72 1793 91.89 1793 92.07 1793 92.24 1783 92.42 1783 92.72 1616 92.89 1675 93.07 1704 93.24 1724 93.42 1744 93.72 1764 93.90 1773 94.07 1773 · 94 ~ 1.773 94.42 1783 94.72 1783 94.90 1793 95.07 1803 95.25 1803 95.43 1803 95.73 1813 95.90 1803 96.08 1813 96.25 1813 96.43 1813 96.73 1813 96.91 1803 97.08 1813 97.26 1833 97.44 1813 97.74 1813 97.91 1823 98.08 1813 4052 4049 4052 4052 4052 4046 4042 3888 3934 3963 3983 4003 4016 4032 4032 4032 4042 4042 4052 4062 4062 4062 4065 4062 4072 4072 4072 4072 4069 4072 4091 4072 4072 4082 4082 DATA PUMP RATE BPM 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 SAND CONC. PPG 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 PAGE DATE: SLOPE ( LO~ / LOG ) 0.6 0.5 0.3 -1.3 0.2 -0.9 -0.8 -6.7 -6.7 -3.0 -1.2 2.8 4.0 4.8 4.7 3.8 4.0 3.6 3.6 3.8 3.8 2.9 2.6 2.1 1.4 0.9 7.3 1.6 1.6 1.4 1.1 1.2 1.6 1.3 0.9 12 10-12-88 FLUID NO. STAGE