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198-158
STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil❑ Gas❑ SPLUG❑ Other ❑ Abandoned II ' Suspended❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ❑ WAGE WDSPL❑ No.of Completions: Service 0 Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp.,Susp.,or tt'i$Iti 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 11/20/2017(�� 198-158/317-366/ ' 3.Address: 7. Date Spudded: 15.API Number: pt P.O. Box 100360 Anchorage,AK 99510-0360 9/16/1998 50-103-20028- .?/' 4a. Location of Well(Governmental Section): 8.Date TD Reached: 16.Well Name and Number: Surface: 269'FNL,94'FEL,Sec 11,T1ON,R8E,UM 9/24/1998 KRU 2K-21A • . Top of Productive Interval: 9.Ref Elevations: KB: 154 17. Field/Pool(s): 1242'FNL,802'FWL,Sec 14,T1ON,R8E,UM GL: 114 BF: Kupurak River Field/Kuparuk Oil Pool. Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 735'FNL, 1193'FEL,Sec 15,T1ON,R8E,UM surface v ADL 25604 4b.Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 498311 y- 5938035 Zone- 4 12579/6369 ' ALK 2678 TPI: x- 493930 y- 5931785 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 491935 y- 5932294 Zone- 4 1810/1721 1600/1552 5. Directional or Inclination Survey: Yes ❑ (attached) No ❑ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 n/a (ft MSL) n/a 22. Logs Obtained: List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential, gamma ray,caliper, resistivity, porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and RECEIVED perforation record. Acronyms may be used.Attach a separate page if necessary ilia DEC 1 9 2017 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 36 115 36 103 24 170 sx AS II 9.625 36 J-55 35 3919 35 2650 12.25 850 sx ASII,400 sx Class G 7 26 J-55 33 10757 33 6229 8.5 400 sx Class G 2 3/8 4.6 1-80 10068 12317 6112 6381 2.75 Slotted Liner 24.Open to production or injection? Yes ❑ No 2 25.TUBING RECORD If Yes, list each interval open(MDITVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3.5 10240 100001/6078 Perforations Plugged 10189/6174 Pog--A4,31.0 Dm(sr) 0189/6174 4J.)ioDN(sr) 26.ACID, FRACTURE,CEMENT SQUEEZE,ETC. Was hydraulic fracturing used during completion? Yes❑ No 0 �^ nlig1l� Per 20 AAC 25.283(i)(2)attach electronic and printed information �9allNNED AN 201 j DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED LL 9413'-1844' 260 BBL 15.8ppg Class G in tubing and IA tagged in tubing 1755'to Surface 135 bls 15.7ppg AS1 in tubing, IA,OA Topped off tubing w/-20 gal 15.6 Portlan type I cement 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A PLUGGED BACK Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period - Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate Form 10-407 Revised 11/2015 V"T(- 1/a.008 CONTINUED ON PAGE 2 Submit ORIGINIAL or�q� *< otyrz -4, RDDN1S I.(- DEC _' 1 2017 • • 28.CORE DATA Conventional Core(s): Yes ❑ No 0 Sidewall Cores: Yes ❑ No 2 If Yes,list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No 2 • Permafrost-Top Surface Surface If yes, list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1600 1552 Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval N/A N/A information,including reports,per 20 AAC 25.071. I()3(e°1Z(e(r \.A.1Q - Formation at total depth: N/A N/A 31. List of Attachments: Daily Operations Summary,Schematics Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological reoort.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: Jill Simek a 263-4131 Email: JiII.Simekacop.com Printed Name: G.L.,Allvord Title: Alaska Drilling Manager Signature: ,! C ' Phone: 265-6120 Da . /2//i/20/7 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 1a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item lb: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and ND for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results, including,but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only • • SUNDRY NOTICE 10-407 ConocoPhillips Well 2K-21A Plug and Abandonment November 27, 2017 ConocoPhillips Alaska, Inc. performed Plug and Abandonment operations on 2K-21A, commencing operations on October 11, 2017 and completing the Plug and Abandonment on November 20, 2017. 260 bbls of 15.8 ppg Class "G" cement was pumped to place a plug from 9,413ftKB in the tubing and tubing x production casing annulus (IA). Cement was tagged at 1,844' RK , and tubing and production casing perforated for circulation of the surface cement plug. 135 bbls of 15.7 ppg ArcticSet 1 cement was then pumped to place cement in the tubing, IA, and production casing x surface casing annulus (OA). The tree was removed and a cement top job was performed. The wellhead was then removed, well capped, and excavation backfilled. Pictures below show cement to surface, marker plate installed, and final site condition after backfill. The field Well Service Report is attached. r # x r ate" R >: a x • • - : � x ,z a . WELL EVENTS SUMMARY • Date Well Event 11/18/2017 (P&A) STATE INSPECTION (GUY COOK) FOR CEMENT, WELD MARKING PLATE, REMOVE EQUIPMENT, BACKFILL EXCAVATION (COMPLETE) 11/17/2017 (P&A) CUT AND REMOVE WELLHEAD >4' BELLOW TUNDRA(COMPLETE) 11/15/2017 (P&A PREP) EXCAVATE EGRESS, INSTALL STAIRS COMPLETE. 11/14/2017 (P&A) EXCAVATE HOLE TO 15' FOR P&A, SET SHORING BOX (COMPLETE) 11/11/2017 (P&A PREP) TOP OFF TUBING CEMENT COMPLETE. 11/7/2017 (P&A PREP): REMOVE TREE, IA CASING VALVE &OA CASING VALVE, REPLACED WITH BLINDS OR PLUGS, MEASURED TOC: T="'60', IA=-9'6", OA=-5'6". 11/6/2017 P&A PREP 11/5/2017 P &A PREP. 10/30/2017 (AC EVAL):T DDT(PASSED), IA DDT(PASSED), OA DDT(PASSED),TOC T(^'24"), TOC IA(^'9' 5"),TOC OA (-13' 3"). 10/27/2017 PUMPED 5 BBL FW SPACER AND 135 BBLS OF 15.7#AS1 CEMENT DOWN TUBING,TAKING RETURNS TO TANKS. AVG PUMP RATE OF 2.5 BPM @ 400 PSI. 15.7#CEMENT RETURNS SEEN FROM BOTH OA AND IA. SHUT DOWN PUMPS. SI WELL. FLUSH SURFACE LINES. JOB COMPLETE. 10/26/2017 RIH W/2" GUN LOADED 5' 1 SPF 0 DEG PHASING. GUN ORIENTATED 0 DEG OF HIGH SIDE.TAGGED CEMENT @ 1841'. PERFORATED INTERVAL= 1750' - 1755', CCL TO TOP SHOT= 5.6' CCL STOP DEPTH = 1744.4'. LOG CORRELATED TO SLB SQUEEZE GUN RECORD DATED 21-OCT-2017. POOH. 10/23/2017 PUMPED 5 Lft3LS DIESEL 10 ESIAt3LISH FLUW IU IA KtIURNS IANK. PUMPED 2UU 1313LS HUI 180 DEG SEAWATER DOWN TUBING,TAKING IA RETURNS. ABLE TO CIRC IA AT 1 BPM AND 200 PSI. OPENED UP TO TAKE OA RETURNS. PRESSURED UP TO 1,700 PSI AND ESTABLISHED OA CIRCUATION. 10/21/2017 RIH WITH CBL AND TAG CEMENT TOP IN TBG AT 1810' RKB, LOG CBL FROM 1810' - 1500' RKB, NO 10/16/2017 MIT TBG AND IA 10/16/2017 TAG TOC @ 1844' RKB, RECOVER SAMPLE OF CEMENT. LRS TO PERFORM MITIA, MITT, & DRAW 10/11/2017 PUMPED 260 BBLS OF 15.8#CLASS G CEMENT, DISPLACE WITH 5" FOAM WIPER BALL FOLLWED BY KUPD 2K-21A Con©coPhillips Well Attribute'''. Max Angle D TD Ala 11E Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) canocavhithps 501032012301 KUPARUK RIVER UNIT PROD 94.30 12,449.02 12,579.0 '" ..° Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 2K-21A,12119/201712'.31'.46 PM SSSV:LOCKED OUT 75 11/1/2014 Last WO: 39.99 1/180990 ,....Vertical Schematic(actual)....... Annotation Depth(ftKB) End Date Annotation Last Mod By End Date .......,i;;. M . ARKER ( ..,,,... Last Tag: 12,182.0 6/29/1999 Rev Reason:P8A WELL pproven 12/18/2017 Plate 4'Below Tundra),44 0 ICasing 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 44.0 115.0 115.0 62.58 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread SURFACE 9 5/8 8.921 44.0 3,919.3 2,923.3 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread -ti CONDUCTOR;44.0-115.0^ ' PRODUCTION 7 6.276 44.0 10,757.5 6,335.0 26.00 J-55 BTC CMT PLUG;44.06KB 'd... Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread APERF;1,750.0-1,755.0---. ',(/a WINDOW'A' 6 5.000 10,425.0 10,430.0 6,297.2 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread APERF;1,7820-1,787.0 ''. SLOTTED LINER 2 3/8 1.995 10,068.2 12,316.6 6,381.6 4.60 L-80 FL4S Cement Squeeze;44.0 ftKB ,,,'.. Liner Details CMT PLUG;44.0 ftKB Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 10,068.2 6,112.0 59.71 FISH NECK 3.5"'GS'FISH NECK 1.940 SAFETY VLV;1,810.0 pill 12,286.3 6,381.7 89.19 SEAL SEAL SUB 1.303 Tubing Strings Tubing Description String Me...ID(in) Top(ftKB) Set Depth(ft..I Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection TUBING 31/2 2.992 75.1 10239.6 6,199.7 9.30 J-55 EUE8rdABMOD Completion Details GAS LIFT;2,880.1 Nominal ID Top(ftKB) Top(ND)(111/8) Top Incl(°) Item Des Corn (in) 1,810.0 1,720.6 41.32 SAFETY VLV CAMCO TRDP-1A-ENC SAFETY VALVE(LOCKED OUT 2.812 9/27/96) 9,940.9 6,048.4 60.21 GASLIFT CAMCO MMG 2.867 9,955.3 6,055.6 60.18 NIPPLE OTIS X SELECTIVE LANDING NIPPLE 2.813 SURFACE;44.03,9193 9,986.9 6,071.3 60.11 PBR BAKER 80-40 PBR w/10'STROKE w/4"SEAL 3.000 10,000.6 6,078.1 60.08 PACKER BROWN HB RETRIEVABLE PACKER 2.890 GAS LIFT;5299.8 10,188.9 6,173.6 58.96 PACKER BROWN HB RETRIEVABLE PACKER 2.890 10,227.5 6,193.5 59.01 NIPPLE OTIS 2.813"XN NIPPLE W/2.75"NO GO 2.750 GAS LIFT,7,644.5 10,238.8 6,199.3 59.06 SOS BAKER SHEAR OUT SUB 3.000 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) GAS LIFT;8,701.4 Top(ND) Top Incl Top(11KB) (ftKB) (°) Des Com Run Date ID(in) 44.0 44.0 0.07 MARKER MARKER PLATE 11/18/2017 0.000 GAS LIFT;9,389. Plate(4' Below APERF;9,411.OA,4130,, Tundra) CMT PLUG;1,844.0ftKB 11� .i OMT PLUG;1,844.0m(B Perforations&Slots Shot Den Top(TVD) Btm(ND) (shots/ Top(1I140) Bte,(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 1./S0.0 1,755.0 1,674.6 1,678.5 A-5,A-4,2K- 10/26/2017 1.0 APERF 5 FT X 2.0"OD GASLIFT,05409 21 POWERFLOW,1SPF, 0°PHASE,6 SHOTS, 0.45"EHD NIPPLE.9,955.3 1 782 0' 1,787.0 1,699.4 1,703.2 A-5,A-4,2K- 10/21/2017 1.0 APERF 5 FT X 2.0"OD 21 POWERFLOW,1SPF, 0°PHASE,6 SHOTS, PBR;9,986.8 0.45"EHD PACKER;10,000.6 9.411.0' 9,413.0 5,790.8 5,791.8 A-5,A-4,2K- 7/2/2017 4.0 APERF 21 10.183.0 12286.0 6170.6 6,381.7 9/26/1998 32.0 SLOTS ' Cement Squeezes Top(TVD) Btm(ND) Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com 9,459.0 10,240.0 5,814.2 6,200.0 CMT PLUG 6/8/2017 .j 10,240.0 10,430.0 6,200.0 6,297.2 CMT PLUG 6/8/2017 10,430.0 12,317.0 6,297.2 6,381.6 CMT PLUG 6/8/2017 II I 10,068.0 12,317.0 6,112.0 6,381.6 CMT PLUG 6/8/2017 II I 1,844.0 9,413.0 1,745.8 5,791.8 CMT PLUG 10/11/201 260 bbls of 15.8 ppg Class"G"cement 7 PACKER;10,188.9 1,844.0 9,413.0 1,745.8 5,791.8 CMT PLUG 10/11/201 260 bbls of 15.8 ppg Class"G"cement P 44.0 1,787.0 44.0 1,703.2 CMT PLUG 10/27/201 PUMPED 5 BBL FW SPACER AND 135 BBLS OF NIPPLE;10,227.5 ` I 7 15.78 AS1 CEMENT DOWN TUBING,TAKING RETURNS TO TANKS.AVG PUMP RATE OF 2.5 BPM @ 400 PSI. 15.7#CEMENT RETURNS SEEN SOS;10,238.8 I FROM BOTH OA AND IA. It 44.0 1.787 0' 44 0 1,703 2 CMT PLUG 10/27/201 PUMPED 5 BBL FW SPACER AND 135 BBLS OF CEMENT in 312;9.459.0 ftKB - 7 15.78 AS1 CEMENT DOWN TUBING,TAKING ;- RETURNS TO TANKS.AVG PUMP RATE OF 2.5 :'' BPM @ 400 PSI. 15.7#CEMENT RETURNS SEEN :ii'': FROM BOTH OA AND IA. •-'/ 44.0 1.787.0 44.0 1,703.2 Cement 10/27/201 WINDOW'A';10,425.0-10,430.0 rtj ,; Squeeze 7 CEMENT in 7";10,240.0814131-f °-1Mandrel Inserts 91 St a[i on Top(ND) Valve Latch Port Size TRO Run I .. I _N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn -. 1 2,860.1 2,338.5 MERLA TMPD 1 GAS LIFT GLV BK 0.156 1,343.0 7/10/1999 PRODUCTION;44.0-10,757.5` ! 5 I 2 5,799.8 3,903.6 MERLA TMPD 1 GAS LIFT GLV BK 0.250 1,362.0 7/9/1999 SLOTS;10,183.012,296.0- ;! 3 7,644.5 4,876.4 MERLA TMPD 1 GAS LIFT GLV BK 0.250 1,454.0 7/9/1999 Notes 4 8,701.4 5,433.4 MERLA TMPD 1 GAS LIFT OV BK 0.188 0.0 8/13/2013 II 5 9,389.6 5,780.5 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 9/26/1998 we 6 9,940.9 6,0484 CAMCO MMG-2 11/2 GAS LIFT DMY BK 0.000 0.0 9/26/1998 SLOTTED LINER;10,088.2-� � Notes:General&Safety 12,318.8 CEMENT 23/8"X 312 OPEN r;; End Date Annotation HENT;10,430.0 2 ffer, 9/26/1998 NOTE WELL SIDEDTRACKED TO'A' CEMENT in,3/8'L5KB 10,088.0 ftKB KUP 111FD • 2K-21A ConocoPhillips Aidsk i,III.,, Conor ehillips ...•• 2K-21 A,12/19/201712:31:47 PM............ :...Vertical schernebc(actual) LNIWYY MARKER Plate(4'Below Tundra),44 0 'o es: enera • a e ' q:. End Date Annotation ;3 i'. 11/4/2010 NOTE:View Schematic w/Alaska Schematic9.0 S 10/31/2015 NOTE:LEFT 4 pieces of 7/8"Grapple on GLV @7645'RFB(-1.5"each) ` 12/18/2017 NOTE:REMOVE EQUIPMENT,BACKFILL EXCAVATION(COMPLETE) .".n CONDUCTOR;44.0-1150' CMT PLUG;44.051(8 - . ) �' 12/18/2017 NOTE:(P8A)STATE WITNESSED(GUY COOK)FOR CEMENT,WELD MARKING PLATE APERF;1,750.0-1,755.0- ::',1'g)"s APERF;1,782.0-1,787.0 :,.x3 Cement Squeeze;44.0 RKB Ns ,^:.,.A CMT PLUG;44.0 RIO s SAFETY VLV;1,810.0 rT 1111 GAS LIFT,2,860.1 Imo, _I SURFACE;44.03,919.3 GAS LIFT;5,799.8 GAS LIFT,7,644.5 GAS LIFT;8,701.4 GAS LIFT;8,389.6 APERF;9,411.0-9,413 0 C17711964,111. MT PLUG;1,844.0 RKB CMT PLUG;1,844 0 RKB s GASLIFT,9,940.9 ;:.. NIPPLE;9,955.3 PBR;9,986.9 PACKER,10,000.6 m 1 I _I PACKER;10,188.9 NIPPLE;10,227.5 IP r SOS;10,238.8 L 1' CEMENT in 312`;9,459.0 RKB N' �'fi WINDOW A%10,425.0-10,430.0., CEMENT n 7';10,240.0 ftKB r- '-1 11 a I 11 PRODUCTION;44.0-10,757.5` J •i i. SLOTS;10,183.0.12,288.0 'r I SLOTTED LINER;10,0882- 12,.3163166 .8 CEMENT 23IB"X31?OPEN J HOLE;10,430.0 RK8 CEMENT n 2 3I8"Liner; 10,068.0 RKB • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg Reil� 'qft/i 7 DATE: 11/18/17 P. I. Supervisor FROM: Guy Cook SUBJECT: Surface Abandonment Petroleum Inspector KRU 2K-21A Conoco/Phillips Alaska Inc PTD 1981580; Sundry 317-366 - 11/18/17: I traveled to Kuparuk to KRU 2K-21A and met with Roger Winter(CPAI) to inspect cement to surface and witness the installation of the identification marker plate. I witnessed cement to surface that was fully cured. The plate was welded on and from the top of the identification plate to ground surface was measured at 4 feet. The identification plate was bead welded with the proper information including: the well name, PTD#, the name of the operator, the name of the well and the API#. After my inspection of the identification plate installation, the process of filling the cellar and the surrounding area, excavated for safe access, began. Attachments: Photographs (3) SCANNED b 2017-1118_Surface_Abandon_KRU_2K-21 A_gc.docx Page 1 of 3 I • • Surface Abandonment— KRU 2K-21A (PTD 1981580) Photos by AOGCC Inspector G.Cook 11/18/17 el-"+ • rk‘ est •. n g- 7 P 11- vt o. 4.4.:.:1:•,.,•„•:,„,.-.- ��y�,, � • • It r . i \ 1 ' f .\ . --. E :) - ) 20 17-1 11 8_Surface_Abandon_KRU_2K-2 1A_gc.docx Page 2 of 3 • • •...... - ' 411 " -4 0 , , ,•,. ' 0 ,,,, , •'''1 ... .. • ' 0" . . t•-..) *-6.... • . ** •"*.Y..illik. '''' 44f'1'.* , ...... r ,,... .. . ••-••••' .,. ' .- r7 0, "% —",...-. .....t.... - . 1 \ *.‘ ... \ t:'Z'''': , ..., _ ,. „•••• ,, . '• \ ,,,,,,41..".;,..' ' . . , .• • ' ' ... "• ... ..• !... . .. ••• -4 ,4. / .• ••• '''' igg. • '. 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N N N N N N - r� ' a • o Q^ O O O coN N CO OU O p� r O O " p U O O O O O 4, 4+ C O W C N In N N N d C OU O co a) • U 01 Z rn a) da a W Y p LU cc r^ E E Z Q. Q Q Q Y C Y N w v to (41 Z N N N E N Ya) N C d Q O N N N N N = Z y O O •� ■C ,1 u 3 @• c a E E 0 C#3 a Q R _ H a 0. H SOF To • ,vi& I//7,4'8 THE STAT Alaska Oil and Gas rtt, ,-s—d��,,A of CLAsKA onservation Commission o 5i} _=__ _- 333 West Seventh Avenue t GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 *° Main: 907.279.1433 OF 44:174-1‘14. Fax: 907.276.7542 www.aogcc.alaska.gov Jill Simek Staff Well Integrity Engineer ConocoPhillips Alaska, Inc. SCANNED AUG 2 5 2[0, PO Box 100360 Anchorage,AK 99510 Re: Kuparuk River Field, Tabasco Oil Pool, KRU 2K-21A Permit to Drill Number: 198-158 Sundry Number: 317-366 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, rt ,II &La C./y P oe ter Commission r DATED this/fday of August,2017. RBDMS 1 V P“-,,i L 3 2017 • . , • • 4..- .. ir... STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ., V r r_V i 1 1)-r5 $j f8 APPLICATION FOR SUNDRY APPROVALS l t 20 AAC 25.280 »•- 1.Type of Request: Abandon 0 . Plug Perforations El Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend 0 Perforate 0 Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well ❑ Alter Casing 0 Other:❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory 0 Development I] ' 198-158 ' 3.Address: Stratigraphic ElService ❑ 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-103-20123-01 . 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A • Will planned perforations require a spacing exception? Yes 0 No 0/ KRU 2K-21A 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25604 , Kuparuk River Field/Kuparuk River Oil Pool , 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 12,579' 6,369' , , 12317 6382 0 9459 NONE Casing Length Size MD TVD Burst Collapse Conductor 79' 16" 115' 115' Surface 3,884' 9 5/8 3,919' 2,923' Production 10,724' 7" 10,758' 6,335' Liner 2,249' 2 3/8 12,317' 6,382' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A 3.500" J-55 10,240' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-BROWN HB RETRIEVABLE PACKER ' MD=10001 TVD=6078 PACKER-BROWN HB RETRIEVABLE PACKER • MD=10189 TVD=6174 • SAFETY VLV-CAMCO TRDP-IA-ENC SAFETY VALVE(LOCKED OUT • MD=1810 TVD=1721 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 0 Service ❑ 14.Estimated Date for 8/15/2017 15.Well Status after proposed work: Commencing Operations: OIL 0 WINJ 0 WDSPL ❑ Suspended El 16.Verbal Approval: Date: GAS ❑ WAG 0 GSTOR ❑ SPLUG 0 Commission Representative: GINJ ❑ Op Shutdown 0 Abandoned 0 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Jill Simek Contact Name: Jill Simek Authorized Title: S- i -I Integrity Engineer Contact Email: Jill.Simek@cop.com 1J Contact Phone: (907)263-4131 Authorized Signature: ,I,', Date: Ohl COMMISSION USE ONLY Conditions of approval: Noti •mmission so that a representative may witness Sundry Number: 3 (7- 3C4z,� Plug Integrity BOP Test 0 Mechanical Integrity Test ❑ Location Clearance Other: Post Initial Injection MIT Req'd? Yes 0 No t17 Spacing Exception Required? Yes ❑ No I' Subsequent Form Required: f d ._4 RBbMS 1.,1-- /,,.- .i L 3 2017 APPROVED BY Approved by: av COMMISSIONER THE COMMISSION Date: g —/S_ /7 ici 8/ ,tel vrz- if,utl1 7i— SubmitRAipGel A . Form ane Form 10-403 Revised a/2017 c �S valid for 12 months from the date of approval. Attachmentssin Duplicate • • RECEIVED ConocoPhillips AUG o4 ,2017 Alaska P.O. BOX 100360 AO CC ANCHORAGE,ALASKA 99510-0360 GCC Commissioner, State of Alaska 25 July 2017 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 Plug and Abandon (P&A) Kuparuk Producer 2K-21A(PTD#: 198-158). 2K-21A is a Kuparuk A sand producer drilled in 1998. In January 2017, while in the process of installing a gas lift design after a scale blast, slickline encountered a restriction in the tubing at approximately 734' KB. Subsequent drifts have indicated continuing subsidence; the last successful drift was for a 1.80" HEX plug. In July, 2017 the well was suspended with 40 bbls of 15.8ppg Class"G" cement, pumped down the tubing and slotted liner to isolate the formation from the wellbore. Top of Cement was tagged in the tubing at 9,459' KB and a passing MIT-T was obtained. The tubing was then perforated at 9,411' to 9,413' KB for future circulating/cementing operations. The well is a coil-tubing drilled sidetrack, exiting the motherbore from a 5' window cut at 10,425' KB in the 7" casing. The sidetrack is completed with a 2-3/8" slotted liner to 12,316.6' KB set in 3 %"tubing at 10,068.2' KB. After noticing the drift issues, well paths on nearby wells, 2K-32 and 2K-30, were adjusted to sweep2K-21A resource; Additionally, Shark Tooth expansion grassroots wells are planned for 2K. Since the drillsite's manifold is filled to capacity, and 2K-21A will no longer be providing any service, 2K-21A has been identified for Slot Recovery P&A.✓ Per this procedure, P&A operations will be performed by pumping 260 bbl down the tubing and up the tubing x production casing annulus (IA) to approximately 2,000' KB. Tubing and production casing will be perforated above Top of Cement(TOC) and a second plug will be pumped, to bring cement to surface in the tubing, IA, and production casing x surface casing annulus (OA). The well will then be excavated 4 feet below original ground level, wellhead and cellar removed, and site backfilled with gravel/fill to ground level. Sincerely, i Ji I Si ek V111 ntegrity Engineer . • • ConocoPhillips 2K-21A P&A Permit to Drill #: 198-158 Per this procedure, P&A operations will be performed by pumping 260 bbl down the tubing and up the tubing x production casing annulus (IA) to approximately 2,000' KB. Tubing and production casing will be perforated above Top of Cement (TOC) and a second plug will be pumped, to bring cement to surface in the tubing, IA, and production casing x surface casing annulus (OA). The well will then be excavated 4 feet below original ground level, wellhead and cellar removed, and site backfilled with gravel/fill to ground level. Proposed P&A: Cementing: Objective: Plug #1 - Fill the wellbore with cement from tubing punch (9,413' KB) to approximately 2,000 KB. We will be circulating cement down the 3 '/2" tubing and up the 3 1/2" x 7" annulus. Cement Volume Calculations (TOC approximately 2,000' KB in tubing and annulus): • Volume in 3 1/" x 7" annulus: (9,413' —2,000') x 0.026363 bbl/ft = 195.4 bbl • Volume inside 3 '/" tubing: (9,413' —2,000') x 0.008696 bbl/ft = 64.5 bbl • Total volume: 195.4 + 64.5 = 259.9 bbl • Displacement volume: (2,000' KB) * (0.008696 bbl/ft) —3 bbl spacer= 14.4 bbl 1. Contact Halliburton a week before the scheduled P&A date, to allow'adequate time for pilot testing of the P&A cement design (Mark Dean, 907-275-2613). The job is designed for 260 bbls of 15.8# Class "G" cement. 2. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 3. Ensure a 5" foam ball is loaded into the tree prior to the cement job. 4. MIRU cementers. Ensure to rig up a cement clean up line using an isolation valve and "T" connection off the tree. 5. Ensure that hardline is rigged up to pump down the tubing and take returns to a tank from the 3 '/2" x 7" (IA) annulus. Also ensure that there is a way to pump down the IA in case the tubing pressures up. 6. PT surface equipment as required 7. Establish circulation with diesel. 8. Pump 3 bbls fresh water spacer 9. Pump 260 bbls of 15.8 ppg Class "G" cement. 10. Drop 5" Foam Ball 11. Pump 3 bbls fresh water spacer. JS • S 12. Displace with 14.4 bbls diesel to leave Top of Cement in tubing and IA at 2,000' KB. 13. Shut down pumps and close in Tubing and IA. - 7 not overdisplace. 14. Wash up cement pumps and clean up surface lines. 15. RDMO Slickline / Little Red . Objective: Tag TOC, CMIT-TxIA, DDT-TxIA 1. WOC for 48 hr or until field blend UCA chart shows cement developed 1,500 psi compressive strength. 2. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 3. RU Slickline and PT Equipment as required. 4. RIH and tag TOC @ approximately 2,000' KB. Record results and report tag depth to Well Integrity Engineer. 5. RU LRS and PT Surface Equipment as required. 6. Perform CMIT-TxIA to 1,500 psi. Record results. 7. Perform DDT on Tubing and IA. Record results. 8. Report issues & results to Well Integrity Engineer. 9. RDMO E-line / Little Red Objective: Punch 31/2" tubing and 7" production casing to establish circulation for surface cement plug. 1. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 2. RU e-line and PT Equipment as required. 3. RIH with dual-string perforating gun, referencing 7/20/2017 schematic and tubing details for depth correlation. 4. Punch 30' above TOC, as close to mid joint as possible. 5. Pump 8 bbls diesel through tubing holes to ensure adequate rate for cementing (+/- 2 bpm <= 2,000psi). Ensure circulation to both IA and OA. 6. If 2 bpm circ. rate is not achievable, RIH with a second tubing punch and punch holes 32' above the previous holes. 7. RDMO Pumping Services: Objective: Plug #2 - Fill the wellbore with cement from perforating depth (-2,000' MD) to surface. We will be circulating cement down the 3 1/2" tubing and up the 9-5/8" x 7" annulus as well as up the 7" x 3 1/2" annulus.' Js • • Cement Volume Calculations: • Volume in 3 '/2" x 7" annulus: (2,000'-0') x 0.026363bb1/ft = 52.7.bbl • Volume in 7" x 9 5/8" annulus: (2,000'-0') x 0.029710 bbl/ft = 59.4 bbl • Volume inside 3 '/2' tubing: (2,000'-0') x 0.008696 bbl/ft = 17.4 bbl • Excess: 20 bbl • Total volume: 52.7 + 59.4 + 17.4 + 20 = 149.5 bbl 1. Contact Halliburton a week before the scheduled P&A date, to allow adequate time for pilot testing of the P&A cement design (Mark Dean, 907-275-2613). The job is designed for 149.5 bbls of Permafrost Cement. 2. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 3. RU HAL Cement Equipment and PT surface lines as required. Ensure that hardline is rigged up to pump down the tubing and take returns to a tank from both the 9 5/8" x 7" (OA) and 7" x 3 '/2" (IA) annuli independently. Also, ensure that there is a way to pump down the IA or OA in case the tubing pressures up. Rig up line to flush all surface lines of cement post-job. 4. Close the OA, open the IA, and pump 20 bbls of diesel down the tubing, taking returns to tank from the IA to confirm circulation. 5. Close the IA, open the OA, and pump 20 bbls of diesel down the tubing, taking returns to tank from the OA to confirm circulation. 6. After circulation to IA and OA is confirmed, batch up "Permafrost C" cement. 7. Line up to pump cement down the tubing, taking returns from the OA. 8. Follow Pump Schedule below: i. 5 bbls fresh water spacer ahead ii. 149.5 of "Permafrost C" cement (cement to surface in T/1/O, including 20 bbls excess) 9. After approximately 76.8 bbls of cement is pumped away, expect to see OA cement returns. Utilize mud balance to confirm good Permafrost cement to surface coming from the OA. Pump contingency cement if needed to obtain good cement to surface. 10. With good OA cement to surface, open the IA, close the OA, and line up to take IA returns to tanks. i his step must be performed efficiently as Permafrost -ernem is thixoiropic and will develop gel strength quickly when static. 11. After approximately 52.7 bbls of cement is pumped away, expect to see IA cement returns. Utilize mud balance to confirm good Permafrost Cement to surface coming from the OA. Pump contingency cement if needed to obtain good cement to surface. 12. After good OA and IA cement is seen at surface, shut down pumps and close in the IA and OA valves. 13. Close in the master valve, open the cement clean up line, and circulate to tanks to wash up tree and surface equipment. 14. RDMO JS • • DHD: Objective: DDT 1. WOC for 48 hr or until field blend UCA chart shows cement developed 1,500 psi compressive strength. 2. RU DHD and PT equipment. 3. Perform drawdown test on tubing, IA, and OA. Wellhead Excavation / Final P&A: 1. Remove the Well House (if still installed). 2. Bleed off T/I/O to 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 lose ground from falling into the excavation. 5. Cut off the wellhead and all casing strings at 4 feet below original ground level. 6. Perform Top Job and verify that cement is at surface in all strings. AOGCC witness and photo document required. 7. Send the casing head w/ stub to materials shop. Photo document.• 8. Weld %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 2K-21A PTD # 198-158 API # 50-103-20123-01 9. Remove Cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 10. Obtain site clearance approval from AOGCC. RDMO. 11. Report the Final P&A has been completed to the AOGCC, and any other agencies required. Photo document final location condition after all work is completed. • JS • • Schematic: �. KUP PROD 2K 21A 1[ csc+ l i!lips fillaY Angle 1 TO Sd IO2 224 *wt 4441. Iwwzcn..Wm )r z r. -... t� Xa et .u,..al;iahr�. �.�.1 24411 k.!'#%12£1 .'.?,i4l.F 1£1 F?C.;XS I X+:= "::445 3 i°Y3.= 44l l /4f 53*4 5.4I. iYFSaw lt44:441 :e)ltaS It'-. 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Js . . . . • • P&A Diagram: 2K-21A P&A PTD #: 198-158 Current Completion Proposed P&A Plug riC TCC Alli IIh 15' 2 #1-1-410 Ccniaetcr g-1 f'KB , thY94#54*54.14:..'43 0,,suface - 1*-r1,•M•T ;ilft W:WiAll • ,,-,V,N,,i.rt ,,,,,,, , 1 tiv4.5-..,404tot".i., 54 55* ,,,,,..-14,5,iiV.Qe,e.°141.0•,-1:4.1-i0 Ab*esh„..,,,i,..am....ax ?•wi-,--,=-1 - 'a,1.41 ..1,.:.i,,....,.•,gco;.,1„,„ vatk.: -4 :to. dlik:A.54.146,t0 cernet plug#1 Tcc gr,in'ae..•.1IP. 411',$.-t•V'Stgl 3 A VAII:,:f4M74.4ii Ad hi.£1-5.'Er 110J-5 t, Surface Casi ng g 3,Ei*@.3 KB AI 4.0AIN*s 4,9# .,m4t : 0 ‘ 41,5 .3 'z, , , 0 4;?41;?itetepe,,,,, !., 0,0,,,,N.,,;$,-,-• •• 0:117PA,Oiaii f16:".tiee;0,„ ,,,„,„m,%,,,x,4-.3,,,:-,4;::-• WV 031S)C0 2,880 V KB ,!•014:P4M1',44.1 GLM GLV) KB 5,7%8'KB 74:...44,.°.,.°4** t° 2',VMft ,. ..4 GLIM i,GIV)0 7.M4. KB KS .1041i •.,:xi -, all tai)©8.7D1 4'KB c,," ."..."24,•.•„0 io4iilli CiLM(MY)a 9.33g.d'r,B itb',.,,,A.i:44,44,4; 424,,:. '' 14Pit•P;I:Pi-,*14*- GLM 4CMY)la Gt.C4C.O'KB •,i Ni-,:il.'..,e -Hk', ..• Of '' ,,-A •• v vwf" Tng Punch 0.41 T-.g413"KB •.4',"..'4,,',". '44,,,giar ' •57,e'S;.>..,I',I', Cement Plug'MC a 6,,459'KB ng.i::::ef •Vi,';':',:;l' '4:44,-if -:".4,h,:i 1. k,•:,,^4,0rete &Z','ki'fAX • 1,17'..ttA:N. 4014 ,•f...--„','N4 i : ..7.%".-....i- ,?7,1,-:fifi'7. _ if UZI! 3-At'..2, J-f5... 0 litniat3"KB triSifi re4 r ,)s,s,:z:iv-* Woclaw A'13.,25-10,430'KB r:::::1:7-9-411441t'' 'relW 7'264J-55 Pircluvaan Caste a 101.75'.5'KB 0.1.x'.:a 2-3.1r 4.60 L-8C Slotted Liner 10,1358.2-1.2.318.45'KB ,4*.,,,,t Slots. 1a183.0'-12.289.07 KB ,s '441,`ii JS 7-20-2017 Js L KUP PD Ai 2K-21A •ConocoPhiflips -.44 Well Attribut Max Angleillib TD Alaska,lr+ Wellbore API/UWI Field Name Wellbore Status Inc!I) MD(ftKB) Act Btm(kKB) C0000oPh(lips"' 501032012301 KUPARUK RIVER UNIT PROD 94.30 12,449.02 12,579.0 """ Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2K-21A,7/26/2017 1 1 42 3 7 AM SSSV:LOCKED OUT 75 11/1/2014 Last WO: 39.99 1/18/1990 .... .;vam aso l hsnranc.(acmai) Annotation Depth(kKB) End Date Annotation Last Mod By End Date Last Tag 12,182.0 6/29/1999 Rev Reason:PERF and CEMENT pproven 7/20/2017 HANGER;31.1-gip Casing Strings n Casing Description OD(in) ID(in) Top(kKB) Set Depth(ftKB) Set Depth(ND)..Wt/Len(1.. Grade Top Thread CONDUCTOR 16 15.062 36.0 115.0 115.0 62.58 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(kKB) Set Depth(TVD)... tlLen(I...Grade Top Thread ' y„ae„„„, ,„0„,„, „„„, „„, li W :' Loy,SURFACE 9 5/8 8.921 35.0 3,919.3 2,923.3 36.00 J-55 BTC Casing Description PRODUCTION Casing Description WINDOW'A' OD(in) ID(in) Top(kKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread 7 6.276 33.1 10,757.5 6,335.0 26.00 J-55 BTC OD(in) ID(in) Top(BOB) Set Depth(ftKB) Set Depth(ND)...Wt/Len p...Grade Top Thread 6 5.000 10,425.0 10,430.0 6,297.2 Casing Description OD(in) ID(in) Top(kKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread SLOTTED LINER 2 3/8 1.995 10,068.2 12,316.6 6,381.6 4.60 L-80 FL4S M CONDUCTOR;36.0.115.0 rLiner Details Top(kKB) lop(ND)(kKB) Top Incl(°) Item Des Com Nominal ID(in) SAFETY VLV;1,810.0 .°5III 10,068.2 6,112.0 59.71 FISH NECK 3.5"'GS'FISH NECK 1.940 11 .rc 12,286.3 6,381.7 89.19 SEAL SEAL SUB 1.303 Tubing Strings Tubing Description Shing Ma...ID(in) Top(ftKB) Set Depth(k.. Set Depth(ND)I...Wt(Ib/ft) Grade Top Connection GAS LIFT;2,860.1 - TUBING 31121 2.9921 31.11 10239.61 6199.71 9.301 J-55 IEUE8rdABMOD Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des I Com (in) 31.1 31.1 0.05 HANGER FMC GEN IV TUBING HANGER 3.500 1,810.0 1,720.6 41.32 SAFETY VLV CAMCO TRDP-1A-ENC SAFETY VALVE(LOCKED OUT 2.812 SURFACE;350-3,919.3 9/27/96) 9,940.9 6,048.4 60.21 GASLIFT CAMCO MMG 2.867 GAS LIFT;5,799.8 4- 9,955.3 6,055.6 60.18 NIPPLE OTIS X SELECTIVE LANDING NIPPLE 2.813 9,986.9 6,071.3 60.11 PBR BAKER 80-40 PBR w/10'STROKE w/4"SEAL 3.000 GAS LIFT;7,644.5 = 10,000.6 6,078.1 60.08 PACKER BROWN HB RETRIEVABLE PACKER 2.890 < 10,188.9 6,173.6 58.96 PACKER BROWN HB RETRIEVABLE PACKER 2.890 GAS LIFT;8,701.4 r, - 10,227.5 6,193.5 59.01 NIPPLE OTIS 2.813"XN NIPPLE W/2.75"NO GO 2.750 1 10,238.8 6,199.3 59.06 SOS BAKER SHEAR OUT SUB 3.000 GAS LIFT;9,389.6 Perforations&Slots Shot APERF;9,411.0&,413.0 - Top(TVD) Btm(ND) Dens Top(kKB) Btm(BOB) (kKB (shots) (kKB) Zone Date k) Type Corn 9,411.0 9,413.0 5,790.8 5,791 8 A-5,A-4,2K- 7/2/2017 4.0 APERF 21 ° 10,183.0 12,286-0 6,170.6 6,381.7 9/26/1998 32.0 SLOTS GASLIFT;9,9409 Cement Squeezes Top(ND) Btm(ND) Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com NIPPLE,9,955.3 9,459.0 10,240.0 5,814.2 6,200.0 CMT PLUG 6/$/2017 10,240.0 10,430.0 6,200.0 6,2972 CMT PLUG 6/8/2017 10,068.0 12,317.0 6,112.0 6,381.6 CMT PLUG 6/S/2017 PBR,9986.9 10,430.0 12,317.0 6,297.2 6,381.6 CMT PLUG 6/8/2017 PACKER,10,000.6 '- Mandrel Inserts St ati on Top(ND)1 Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Madel OD(in) Sery Type Type (in) (psi) Run Date Corn 2,860.1 2,338.5 MERLA TMPD 1 GAS LIFT GLV BK 0.156 1,343.0 7/10/1999 2 5,799.8 3,903.6 MERLA TMPD 1 GAS LIFT GLV BK 0250 1,362.0 7/9/1999 0.250 1,454.0 7/9/1999 See 3 7,644.5 4,876.4 MERLA TMPD 1 GAS LIFT GLV BK Notes 4 8,701.4 5,433.4 MERLA TMPD 1 GAS LIFT OV BK 0.188 0.0 8/13/2013 I 5 9,389.6 5,780.5 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 9/26/1998 6 9,940.9 6,048.4 CAMCO MMG-2 1 1/2 GAS LIFT DMY BK 0.000 0.0 9/26/998 I Notes:General&Safety PACKER;10,188.9 End Date Annotation 111 9/26/1998 NOTE:WELL SIDEDTRACKED TO'A' 11/4/2010 NOTE:View Schematic w/Alaska Schematic9.0 NIPPLE,10,227.5 IL SOS;10,238.8 10/31/2015 NOTE:LEFT 4 pieces of 7/8"Grapple on GLV Qn 7645'RFB(-1.5"each) IL CEMENT In 31/7;9,459.0 BOB ' CEMENT in 7;10,2490 ft013 WINDOW'A',10,425.0-10,430.01 • PRODUCTION;33.1-10,757.5 I SLOTS;10,183.0-12,286.0----4 '. SLOTTED LINER;10,068.2- 12,316.6\ CEMENT in 2318"Liner, 10,088.0 kKB CEMENT 2 3V8"X 3117 OPEN HOLE;10,430.01KB • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a.Well Status: Oil❑ Gasp SPLUG❑ Other ❑ Abandoned ❑ Suspended Et 1 b.Well Class: 20AAC 25.105 20MC 25.110 Development 0' Exploratory❑ GINJ ❑ WINJ❑ WAG❑ WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test❑ 2.Operator Name: 6. Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska,Inc. Aband.: 7/2/2017 198-158/317-208 3.Address: 7. Date Spudded: 15.API Number: P.O.Box 100360 Anchorage,AK 99510-0360 9/16/1998 50-103-20123-01 4a. Location of Well(Governmental Section): 8.Date TD Reached: 16.Well Name and Number: Surface: 269'FNL,94'FEL,Sec 11,T1ON, R8E,UM V' 9/24/1998 KRU 2K-21A • Top of Productive Interval: 4„E 9. Ref Elevations: KB:" gq1 "- 17.Field/Pool(s): 1242'FNL,802'FWL,Sec 14,T1ON,R8E, UM GL: 114 BF: Kuparuk River Field/Kupark Oil Pool, Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 735'FNL, 1193'FEL,Sec 15,T1ON,R8E, UM 12317/6382 ADL 25604 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19.DNR Approval Number: Surface: x- 498311 y- 5938035 Zone- 4 12579/6369, ALK 2678 TPI: x- 497606 y- 5931783 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 491935 y- 5922294 Zone- 4 1810/1721 1600/1552 5.Directional or Inclination Survey: Yes ❑ (attached) No 2 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential, gamma ray,caliper, resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary RECEIVED N/A JUL 2 6 2017 23. CASING, LINER AND CEMENTING RECORD AOGCC WT. PER SETTING DEPTH MD SETTING DEPTH ND AMOUNT CASING GRADE HOLE SIZE CEMENTING RECORD FT TOP BOTTOM TOP BOTTOM PULLED 16 62.6 H-40 36 115 36 115 24 170 sx ASI I 9 5/8 36 J-55 35 3919 35 2923 12.25 850 sx AS III,400 sx CLASS G 7 26 J-55 33 10757 33 6335 8.5 400 SX Class G 2 3/8 4.6 L-80 10068 12317 6112 6382 2.75 Slotted Liner 24.Open to production or injection? Yes ❑ No El 25.TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/ND) Size and Number; Date Perfd): 3 1/2 10240 10001/6078 1 01 89/61 74 26.ACID, FRACTURE,CEMENT SQUEEZE,ETC. Was hydraulic fracturing used during completion? Yes❑ No 0 pp�� Per 20 AAC 25.283(i)(2)attach electronic and printed information SCANNED `� DEPTH INTERVAL(MD) AMOUNT AND'KIND OF MATERIAL USED 9459-12317 40 bbls 15.8 Class G 27_ PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A WEL SUSPENDED Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate/ >- Form 10-407 Revised 5/2017 �` r�� CONTINUED ON PAGE 2 RBDMS 1. - JUL 2 7 2017 Submit ORIGINIAL only • • • 28.CORE DATA Conventional Core(s): Yes ❑ No E Sidewall Cores: Yes ❑ No 2 If Yes, list formations and intervals cored(MD/TVD,From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips, photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No 0 Permafrost-Top Surface Surface If yes, list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1600 1552 Attach separate pages to this form,if needed,and submit detailed test Top of Productive Interval N/A N/A information, including reports,per 20 AAC 25.071. Formation @ TPI-Kuparuk C TD N/A N/A Formation at total depth: N/A ' 31. List of Attachments: Daily Operations Summary,Schematic Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, oaleontoloaical report.production or well test results,per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: G.L.Alvord Contact Name: Jill Simek Authorized Title Alaska Drillin_ Manager Contact Email: Jill.Simek• p_:?; .m. _ Authorized Contact Phone: 263-1431 Signature: Cts>A1-0ate: fife 12Z) 1 • INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item lb: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 19: Report the Division of Oil&Gas/Division of Mining Land and Water: Plan of Operations(LO/Region YY-123), Land Use Permit(LAS 12345), and/or Easement(ADL 123456)number. Item 20: Report measured depth and true vertical thickness of permafrost.Provide MD and ND for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results, including,but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only • S ConocoPhillips RECEIVED Alaska JUL 2 6 2Q17 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOGCC 13 July 2017 Commissioner, State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.performed Suspend operations on 2K-21A(PTD#: 198-158),commencing work on 8 June,2017 and completing work on 2 July,2017. Operations involved pumping 40 bbls of 15.8 ppg Class "G" cement down the tubing and slotted liner to isolate the formation from the wellbore. Top of Cement (TOC) was tagged at 9,459' KB and a passing MIT-T was obtained. The tubing was then perforated at 9,411' to 9,413' KB ,for future circulating/cementing operations. Suspend operations are now complete on 2K-21A and ConocoPhillips requests that the AOGCC well status be changed to"Supsended". Operations and testing summaries are included in the attached Well Work Summary,for your reference. If you have any questions or require any further information,please contact me at 263-4131. Sincerely, i J Simek ell Integrity Engineer CPAI Drilling and Wells • • 2K-21A Suspend - Work Summary Start Date Last 24hr Sum • • PERFORATE CIRCULATION HOLES AT 9411'TO 9413',2'4SPF 8 HOLES OF 1 11/16" RTG 0 PHASE WITH 7/2/2117 MAGNETIC DECENTRALIZER.IRS CONFIRMED 2 BPM CIRC RATE THROUGH HOLES. 6/20/2017 (SECURE) IA DDT TO 500 PSI PASS DRIFT&TAG TOC @ 9459' RKB(AOGCC WITNESSED) LRS PREFORMED PASSING MIT-T&DRAW DOWN TEST. NEXT STEP TO PUNCH HOLES. ****** NOTE:IT APPEARS IA IS STILL GAS PACKED,SUGGUST CIRCULATING 6/17/2017 GAS OUT WITH SEAWATER PRIR TO NEXT CEMENT STEP**** PUMPED 40 BBLS OF 15.8#CLASS G CEMENT(10 BBLS NEAT,30 BBLS WITH 1.2#/BBL POLYFLAKE LCM). DISPLACED CEMENT WITH 5" FOAM WIPER BALL,68 BBLS OF FRESH WATER,AND 17 BBLS OF DIESEL. ESTIMATE 11 BBLS SQUEEZED INTO SLOTTED LINER W/TOC @ APPROX 9,800' RKB. WELL LEFT WITH 1,860 PSI OF WHP. JOB COMPLETE. WOC FOR AT LEAST 24 HRS OR 1,500 PSI CS BEFORE RELAY TAG/TEST/TUBING 6/8/2017 PUNCH. KUP 1111FD 2K-21A • Conoc©Phithhps h Well Attribut Max Angle TD Al s1,,i,111t;. Wellbore API/UWI Field Name Wellbore Status ncl IN MD(ftKB) Act Btm(ftKB) Caany 8illips 501032012301 KUPARUK RIVER UNIT PROD 94.30 12,449.02 12,579.0 ."- �� Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2K-21A,7/25120179:27:07 AM SSSV:LOCKED OUT 75 11/1/2014 Last WO: 39.99 1/18/1990 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag; 12,182.0 6/29/1999 Rev Reason:PERF and CEMENT pproven 7/20/2017 1 r HANGER;31.1 . 1'' Casing Strings ,-..1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread II CONDUCTOR 16 15.062 36.0 115.0 115.0 62.58 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread .,,,,,„�,,,,nn,,,n,.,,n„•,,,,,,,,,,,u �_ wu.SURFACE 9 5/8 8.921 35.0 3,919.3 2,923.3 36.00 J-55 BTC • Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 33.1 10,757.5 6,335.0 26.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread WINDOW'A' 6 5.000 10,425.0 10,430.0 6,297.2 Casing Description 00(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SLOTTED LINER 2 3/8 1.995 10.068.2 12,316.6 6,381.6 4.60 L-80 FL4S -off-ti CONDUCTOR;38.0-115.0- , 1.- Liner Details Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Nominal ID Des Com (in) SAFETY VLV;1,810.0 10,068.2 6,112.0 59.71 FISH NECK 3.5"'GS'FISH NECK 1.940 SE 12,286.3 6,381.7 89.19 SEAL SEAL SUB 1.303 Tubing Strings II', Tubing Description String Ma...ID lin) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection GAS LIFT;2,860.1 - TUBING 1 31/21 2.9921 31.11 10,239.61 6.199.71 9.301J-55 I EUE8rdABMOD Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl B) Item Des Com lin) 31.1 31.1 0.05 HANGER FMC GEN IV TUBING HANGER 3.500 1,810.0 1,720.6 41.32 SAFETY VLV CAMCO TRDP-1A-ENC SAFETY VALVE(LOCKED OUT 2.812 SURFACE;35.D-3,919.3-+i 9/27/96) 9,940.9 6,048.4 60.21 GASLIFT CAMCO MMG 2.867 GAS LIFT;5,799.8 9,955.3 6,055.6 60.18 NIPPLE OTIS X SELECTIVE LANDING NIPPLE 2.813 9,986.9 6,071.3 60.11 PBR BAKER 80-40 PBR w/10'STROKE w/4"SEAL 3.000 GAS LIFT;7,644.5 - 10,000.6' 6,078.1 60.08 PACKER BROWN HB RETRIEVABLE PACKER 2.890 10,188.9 6,173.6 58.96 PACKER BROWN HB RETRIEVABLE PACKER 2.890 GAS LIFT;8,701.410,227.5° 6,193.5 59.01 NIPPLE OTIS 2.813"XN NIPPLE W/2.75"NO GO 2.750 10,238.8 6,199.3 59.06 SOS BAKER SHEAR OUT SUB 3.000 GAS LIFT;9,389.6 Perforations&Slots Shot Den APERF;9,411.0-9,413.0-.. I Top(ND) Btm(ND) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 9,411.0 9,413.0 5,790.8 5,791.8 A-5,A-4,2K- 7/2/2017 4.0 APERF 21 _ 10,183.0 12,286-0 6,170.6 6,3817 9/25/1998 32.0 SLOTS GASLIFT;9,9409 Cement Squeezes Top(ND) Btm(TVD) Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com NIPPLE,9,955.3 9,459.0 10,240.0 5,814.2 6,200.0 CMT PLUG 6/8/2017 10,240.0 10,430.0 6,200.0 6,297.2 CMT PLUG 6/8/2017 10,068.0 12,317.0 6,112.0 6,381.6 CMT PLUG 6/8/2017 FOR.9,9889 10,430.0 12,317.0 6,2972 6,381.6 CMT PLUG 6/8/2017 PACKER;10,000.6 Mandrel Inserts St ati N Top(ND) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sett/ Type Type (in) (psi) Run Date Com 1 2,860.1 2,338.5 MERLA TMPD 1 GAS LIFT GLV BK 0.156 1343 0 7/10/1999 2 5,799.8 3,903.6 MERLA TMPD 1 GAS LIFT GLV BK 0.250 1,362.0 7/9/1999 3 7,644.5 4,876.4 MERLA TMPD 1 GAS LIFT GLV BK 0250 1,454.0 7/9/1999 See Notes 4 8,701.4 5,433.4 MERLA TMPD 1 GAS LIFT OV BK 0.188 0.0 8/13/2013 ' I 5 9,389.6 5,780.5 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 9/26/1998 6 9,940.9 6,048.4 CAMCO MMG-2 1 1/2 GAS LIFT DMY BK / 0.000 0.0 9/26/1998 P I Notes:General&Safety PACKER;10,188.9 End Date Annotation ' ' 9/26/1998 NOTE:WELL SIDEDTRACKED TO'A' NIPPLE;10,22'7.5 ` i 11/4/2010 NOTE:View Schematic w/Alaska Schematic9.0 ` + 10/31/2015 'NOTE:LEFT 4 pieces of 7/8"Gropple on GLV @7645'RFB(-1.5"each) ll 1 sos;10,238.8 L J CEMENT in 31/7;9,459.0 ftKBIn MI a s' s` ,ung CEMENT in 7;10,240.0 ftl(B, Al WINDOW'A';10,425.0-10,430.0 I g II PRODUCTION;33.1-10,7575. SLOTS;10,183.0-12,288.0 . Mt MtI SLOTTED LINER;10,068 t2,31n 2,3166 '41 CEMENT in 23/8"Liner; Jul 10,068.0 ftKB CEMENT 2 3/8"X 31/7 OPEN HOLE;10,430.0 ftKB • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg / DATE: 6-17-17 P. I. Supervisor Off 7 FROM: Adam Earl SUBJECT: Plug Verification Petroleum Inspector KRU 2K-21A PTD 198-158; Sundry 317-208 June 17, 2017: I met ConocoPhillips representative Sidney Ferguson at well KRU 2K-21A today for a cement plug tag and pressure test as required by Sundry # 317-208. Using Halliburton slick line, they ran in the hole and verified solid cement at 9,432 ft measured depth (MD). Projected top of cement was 9,800 ft MD. Upon pulling and laying down slick line tools, the empty sample port assured me that there was good cement. Little Red Services then rigged up on the tubing and preformed a pressure test to verify integrity of the plug. The pressures (psi) were as follows: Tbg I/A 0/A PRE 890 1300 - 790 - INT. 1530 - 1300 - 790 - 15min. 1510 1300- 790 30 min. 1500 1300 800 BBLS pumped 0.25 BBLS returned 0.20 - sCANNED .JUL 1 7 201 20 17-06 1 7_Plug_Verification_KRU_2K-21 A_ae.docx 1 of 1 OF rpt • yy, � THE STATE Alaska Oil and Gas ��' '��•"-9� f LASI�:A Conservation Commission _ � OA 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 S Fax: 907.276.7542 www.aogcc.alaska.gov Jill Simek Staff Well Integrity Engineer �` N�� eta` (91111 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2K-21A Permit to Drill Number: 198-158 Sundry Number: 317-208 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, Cathy :. Foerster Chair DATED this day of May, 2017. RBDMS L-' L:1 3 0 2017 • • • ,9 . i STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 1,�' ` tl i' Z s/ Zsl17 APPLICATION FOR SUNDRY APPROVALS �: 20 AAC 25.280 _ 1.Type of Request: Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Repair Well 0 Operations shutdown❑ Suspend 0 . Perforate ❑ Other Stimulate 0 Pull Tubing ❑ Change Approved Program❑ Plug for Redrill 0 Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other:❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development 0• 198-158 ' 3.Address. Stratigraphic ❑ Service ❑ 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-103-20123-01 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A • KRU 2K-21A Will planned perforations require a spacing exception? Yes 0 No 0 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25604 • Kuparuk River Field/Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 12,579' 6,369' 12317 6192 2000psi NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 79' 16" 115' 115' Surface 3,884' 9.625 3,919' 2,923' Production 10,724' 7" 10,758' 6,335' Liner 2,249' 2.375 12,317' 6,382' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10183-1286 • 6171-6382 3.500" J-55 10,240' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER=BROWN HB RETRIEVABLE PACKER ` 10001 MD and 6978 TVD PACKER=BROWN HB RETRIEVABLE PACKER , 10189 MD and 6174 tvd SSSV: CAMCO TRDP-LOCKED OUT • 1810 MD and 1721 TVD 12.Attachments: Proposal Summary ® Wellbore schematic ' 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 0 + Service ❑ 14.Estimated Date for 5/25/2017 15.Well Status after proposed work: Commencing Operations: OIL 0 WINJ ❑ WDSPL ❑ Suspended El 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR 0 SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Jill Simek Contact Name: Jill Simek Authorized Title: Staff Well Integrity Engineer Contact Email: Jill.Simek@conocophillips.com Contact Phone: (907)263-4131 Authorized Signature: ♦ i � Date: 6-23-\`( N COMMISSION USE ONLY Conditions of approval: N Commission so that a representative may witness Sundry Number: S\7- ZQ Plug Integrity Ii BOP Test ❑ Mechanical Integrity Test 0 Location Clearance 0 Other: p /v ai1, of - bo.�-, clrrnv � ,r,r--►- ,wvw , 5t- bt ea , ! -�"tc by / 2/3f / 5cz 2e9, }-4CZ5, / t -- Post Initial Injection MIT Req'd? Yes ❑ No tr. 9 17 Spacing Exception Required? Yes ❑ No VSubsequent Form Required: / 2 4 U RBDMS �L- k201/ - ( J 0 /� APPROVED BY Approved by: 7', -99W--144".... COMMISSIONER THE COMMISSION Dates.2s-/ T qq. ..,„ O I Submit Form and Form 10-403 Revised 4/2017 R p o e a c tion is valid for 12 months from the date of approval. Attachments in Duplicate • • RECEIVED lov MAY 2 3 2017 ConocoPhillips Alaska AOGCC P.O.BOX 100360 ANCHORAGE,ALASKA 99510-0360 23 May 2017 Commissioner,State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby applies for an Application for Sundry Approval to suspend Kuparuk Producer 2K-21A(PTD#: 198-158). 2K-21A is a Kuparuk A sand producer drilled in 1998. In January 2016,while in the process of installing a gas lift design after a scale blast,slickline encountered a restriction in the tubing at approximately 734'KB. Subsequent drifts have indicated continuing subsidence;the last successful drift was for a 1.80"HEX plug. The well is a coil-tubing drilled sidetrack,exiting the motherbore from a 5'window cut at 10,425'KB in the 7"production casing. The sidetrack is completed with a 2-3/8"slotted liner to 12,316.6'KB,set in 3 V2"tubing at 10,068.2'KB. As the well continues to subside,the risk of losing wellbore access increases;thus,the well must be secured as soon as possible. After noticing the drift issues,well paths on nearby wells,2K-32 and 2K-30,were adjusted to sweep 2K- 2 A res•. - . ' ..itiona y,Shark oot expan • . sroots we is are planned for 2K. Since the ri lsrt3�e s m n fold is filled to capacity,and 2K-21A will no longer be providing any service,2K-21A has been identified for Slot Recovery Plug and Abandonment(P&A)./ Per this procedure, suspend operations will be performed by pumping 40 bbls of cement down the tubing and slotted liner to isolate the formation from the wellbore. Top of Cement (TOC) will be brought to approximately 9,800'KB. After a successful TOC tag,the well will be left suspended until 2K pad activity allows for full P&A activities. A separate Application for Sundry Approval for the P&A will be submitted at a later date. If you have any questions or require any further information,please contact me at 263-4131. sSinc rel i Ws 11 Integrity Engineer C AlDrilling and Wells . i • ConocoPhillips 2K-21A Suspend Procedure Permit to Drill #: 198-158 The objective of this procedure is to perform suspended well operations by pumping 40 bbls of cement down the tubing and slotted liner to isolate the formation from the wellbore. Top of Cement (TOC) will be brought to approximately 9,800' KB. After a successful TOC tag, the well will be left suspended until 2K pad activity allows for full Plug and Abandonment activities. Proposed Procedure: Cementing: Objective: Place a cement plug from liner bottom to 9,800' KB. 1. Ensure an approved sundry has been received from AOGCC. 2. Contact Cementers a week before the scheduled P&A date, to allow adequate time for pilot testing of the P&A cement design. The job is designed for 40 bbls of 15.8# Class "G" cement. 3. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 4. Ensure a 5"foam ball is loaded into the tree prior to the cement job. 5. RU Cementers. Pressure test surface equipment as required. 6. Follow pump schedule below: i. Pump 10 bbls fresh water spacer ii. Pump 10 bbls of 15.8 ppg Class "G" Cement iii. Add LCM "on the fly" and pump remaining 30 bbis Class "G" Cement iv. Drop 5" foam ball. v. Pump 85.2 bbls fresh water to displace cement to 9,800' KB. 7. Wash up cement pumps and clean up surface lines. 8. RDMO Digital Slickline/ Little Red: Objective: Tag TOC, punch tubing, injectivity test 1. WOC for 24 hrs or until field blend UCA chart shows cement developed 1,500 psi compressive strength. Notify the AOGCC Inspector of the timing of the cement plug tag and pressure testing. 2. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 3. RU DSL and PT Equipment as required. }� j 4. RIH and tag TOC @ approximately 9,800' KB. Record ResultsA TAG1VIUST BE AOGCC WITNESSED 5. RIH with slimhole tubing punch; reference 11/3/2015 schematic and tubing details for depth correlation. JS • • 6. Punch 30'-50' above TOC or as close to mid joint as possible. 7. Pump 20 bbls diesel through tubing holes to ensure adequate rate for future circ out/cementing (+/- 2 bpm <= 2,000psi). 8. If 2 bpm circ. rate is not achievable, RIH with a second tubing punch and punch holes 32' above the previous holes. 9. Report issues and results to Well Integrity Engineer. 10. RDMO JS • 0 2K-21A Suspend PTD #: 198-158 Current Completion Proposed Suspend .4144 1... 16 62.5#H-40 Conductor @ 115 KB AiJi fiii.„6. IP IP el 1 I i 9-5/8"36#J-55 Surface Casing @ 3,919.3'KB GLM(GLV)@ 2,860.1'KB GLM(GLV)@ 5,799.8'KB I i GLM(GLV)@ 7,644.5'KB li I GLM (OV)@ 8,701.4'KB I� GLM(DMY)@ 9,389.6'KB (` GLM(DMY)@ 9,940.9'KB I a I Cement Plug TOC @ I aa* aaa;se 9,800'KB raa II- , 10 l $ as +�, .1 raaaa'� %a raa < a 40 in 111 a ■ sus I .4‘ ; -a a a is a- 3-'/"9.3#J-55 @ 10,239.6'KB .6. i KUP PROD • 2K-21A ConocoPhillips �U4g#,'! ' Well Attributes Max Angle&MD TD • Alaska,Inc, Wellbore AMAMI Field Name Wellbore Status incl(') MD(ftKB) Act Btm(ftKB) crmeceahlaps 501032012301 KUPARUK RIVER UNFT PROD 94.30 12,449.02 12,579.0 ,.ma --- Comment 1128(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2K-21A,11/3/201512:56:56 PM SSSV:LOCKED OUT 75 11/1/2014 Last WO: 39.99 1/18/1990 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Loot Mod By End Date Last Tag: 12,182.0 6/29/1999 Rev Reason:GLV C/O Attempted/SUSPENDED pproven 11/3/2015 RANGER;311 �■• . I Casing Strings S' Casing Description OD(in) ID(in) Top(ftKB) Set Depth MKS) Set Depth(TVD)...Wt/Len(I...Grade Top Thread Q CONDUCTOR 16 15.062 360 115.0 115.0 62.58 H-40 WELDED I - I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(1...Grade Top Thread LSURFACE 9 5/8 8.921 35.0 3,919.3 2,923.3 36.00 J-55 BTC iy, -.u c.c.Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 33.1 10,757.5 6,335.0 26.00 J-55 BTC Casing Description OD(in) ID(in) Top(ft68) Set Depth(SKS) Set Depth(ND)...Wt/Len(I...Grade Top Thread I WINDOW'A' 6 5.000 10,425.0 10,430.0 6,297.2 j Casing Description 00(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...'Wt/Len(I...Grade Top Thread i SLOTTED LINER 23/8 1.995 10,068.2 12,316.6 6,381.6 4.60 L-80 FL4S Liner Details -A-NCONDUCTOR;36.0.115.0• /,l,-,-✓'` J■ Nominal lD Top(ftKB Top(TVD)IRKS) Top Ind(1 Item Des Com (in) 10,068.2' 6,112.0- 59.71 FISH NECK '3.5"'GS'FISH NECK 1.940 12,286.3 6,381.7' 89.19 SEAL SEAL SUB 1.303 SAFETYVLV;1,810.0 g11ll.' Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Oepth(ft..Set Depth(ND)(...Wt(ihi t) Grade Top Connection TUBING 3 1/2 2.992 31.1 10,239.6 6,199.7 9.30 J-55 EUESrdABMOD Completion Details GAS LIFT;2,8601 ` Nominal ID Top(ft(B) Top(TVD)(ftKB) Top Ind(') Item Des Corn (In) 1 31.1 31.1 0.05 HANGER FMC GEN IV TUBING WINGER 3.500 I1,810.0 1,720.6 41.32 SAFETY VLV CAMCO TRDP-IA-ENC SAFETY VALVE(LOCKED OUT 2.812 9/27/96) E9,940.9 6,048.4 80.21 GASLIFT CAMCO MMG 2.867 SURFACE;35.0-3,919.3-J 9.955.3 6,055.6 60.18 NIPPLE OTIS X SELECTIVE LANDING NIPPLE 2.813 9,986.9 6,071.3 80.11 PBR BAKER 80-40 PBR wl 10'STROKE w/4'SEAL 3.000 GAS LIFT;5,799.0 -, 19 10,000.6 6,078.1 60.08 PACKER BROWN HE RETRIEVABLE PACKER 2.890 10,188.9 6,173.6 58.96 PACKER BROWN HB RETRIEVABLE PACKER 2.890 GAS LIFT;7,644.5 10,227.5 6,193.5 59.01 NIPPLE OTIS 2.813"XN NIPPLE W/2.75"NO GO 2.750 10,238.8' 6,199.3 59.06 SOS BAKER SHEAR OUT SUB 3.000 PE-2: Perforations&Slot GAS LIFT;8,701.4 csms Shot • Dens -1► Top(NKB) etre(ftKB) Top(HKB)D) 8(ftKB)an ) (shots/6 Zone Dare t) , Type Corn GAS LIFT;9,389.6 s 10,183.0 12,286.0 6,170.6- 6,381.7 9/26/1998 ' 32.0 SLOTS Mandrel Inserts St ail GASLIFT;9,940_9 f on Top(TVD) 08190 Latch Port Sib TRO Run N Top(filth) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 2,860.1 2,338.5 MERLA TMPD 1 GAS LIFT GLV BK 0.158 1,343.0 7/10/1999 NIPPLE;9,9553 92 5,799.8 3,903.6 MERLA TMPD 1 GAS LIFT GLV BK 0.250 1,362.0 7/9/1999 3 7,644.5 4,876.4 MERLA TMPD 1 GAS LIFT GLV BK 0.250 1,454.0 7/9/1999 See Notes PBR;sass 4 8,701.4 5,433.4 MERLA TMPD 1 GAS LIFT OV 'BK 0.188 0.0 8/13/2013 2 5 9,389.6 5,780.5 MERLA TMPD 1 GAS LIFT DNAY BK 0.000 0.0 9/26/1998 PACKER;10,000.6 6 9,940.9 6,048.4 CAMCO MMG-2 1 1/2 GAS LIFT DMY BK 0.000 0.0 9/26/1998 Notes:General&Safety End Date Annotation 9/26/1998 NOTE:WELL SIDEDTRACKED TO'A' ill ) 11/4/2010 NOTE:View Schematic w/Alaska Schematic9.0 10/31/2015 -NOTE:LEFT 4 pieces of 7/8"Grapple on GLV©7645'RFB(-1.5"each) I I I I I I L PACKER;10,188.9 NIPPLE;10,227.5 -r-1.. 11 i 11 SOS;10,2388 ! i6 II lel 1 • I L WINDOW'A;10,425.0-10,430.0 A E • 11 ■ I'r ■ 111 PRODUCTION;33.1.10.757.5 • • SLOTS;10,183.0-12,288.0 -• C a SLOTTED LINER;10,0682- 12,316.6 • 111 Schematic: ,+^ I 7p ,,s.`'�`"`°, KJP PROD 2K-21A C{ QcoP tlhpss i} :wol Aargau-1st Max anis s MO TO 44*41•.n. i*41144*Crxcu 4*. 4,54.a 4Y 3'ee4a*Y, l..35:55 322 :. . >�attatt.9 451:.se .333 43.4.5,- C.Lt. 4..343, y14.4 . . , na �aa� 44 ..r_.n., n+.a...a.. at _AmaseXae 3.35 T<b: t 5454 ...ow ux Nae 314 35 dill. qq [@ .414.1t+G:. : S. 444°4*"PER: t.•<.9twx a_t>+.4,.•4534xaA4.55VEY 1.3' 5353..34533 ;X..'5 iliiCativo;Stings 'II +tis _. rs., ,- ,x, 4:1,..4 %11,13444. to ,^.34.533,, i.1t a C14A4,._M64..r;..W.. z- ,. 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KB SE T 0 /wow ,5¶ -12,3113.e t, Slots 10,183 T-12 28 0'KB JS 5-22-2017 Is • S Loepp, Victoria T (DOA) From: Simek,Jill <Jill.Simek@conocophillips.com> Sent: Wednesday, May 24,2017 10:20 AM To: Loepp,Victoria T(DOA) Subject: RE: KRU 2K-21A(PTD 198-158, Sundry 317-208) Suspend Attachments: Visio-2K-21A Suspend Schematic 22 May 2017.pdf;2K-21A Schematic.pdf Victoria, Rig activity is planned to be finished on 2K Pad by mid-July. We would plan to schedule the P&A activities between August and the 2017 Year End. Schematics attached. Thanks, Jill From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Wednesday, May 24,2017 8:52 AM To:Simek,Jill<Jill.Simek@conocophillips.com> Subject:[EXTERNAL]KRU 2K-21A(PTD 198-158,Sundry 317-208)Suspend Jill, Please comment on the timing and plans for the full P&A. The detailed WBS is unreadable. Please provide clear copy. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeppaalaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you ore 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.Loem@alaska.gov 1 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. / ~/- /~ File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original'- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Beverly Mildred D'amtha(~Lowell Date: ~si [] TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Daretha Nathan Lowell Date: Is~ 2.1%5 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. September 12, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 SCANNED JUN 0 9 20 RE: Gas Lift Survey: 2K-21A Run Date: 9/5/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline& Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2K-21A Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20123-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.wood@halliburton.com Date: V0123 i2. Signed: i �' • • ConocoPhillips ~~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 29, 2008 -~,~~ .AU ~ ~ <~ ~~1~~ i t~ ~ Mr. Tom Maunder "~~_ Alaska Oil & Gas Commission 333 West 7`" Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: 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 cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped June 30, July 4 and July 20, 2008. The corrosion inhibitor/sealant was pumped June 29, June 30, JulylO,and July 24, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, /" ~~~ '~ ~, M.J. Loveland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 7/29/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft a! 2K-01 1.88-122 SF NA 10" 6/30/2008 2 6/29/2008 2K-02 188-121 SF NA 10" 6/30/2008 2 6/29/2008 2K-03 188-120 24" NA 24" 6/30/2008 8.5 6/29/2008 2K-05 188-118 SF NA 10" NA 2.55 7/10/2008 2K-06 189-082 SF NA 15" NA 1.27 7/10/2008 3K-13 189-095 8'1" 1.00 25" 7/4/2008 6.38 7/10/2008 2K-15 189-089 SF NA 6" 6/30/2008 1 6/30/2008 2K-17 189-119 10" NA 10" 6/30/2008 23.8 6/30/2008 2K-18 189-108 SF NA 11" NA 2.12 .7/10!2008 2K-21A 198-158 20' 2.70 14" 7/4/2008 4.68 7/10/2008 2K-22 189-115 6" NA 6" 6/30/2008 5.1 6/30/2008 2K-25 190-012 SF NA 12" NA 2.55 7/10!2008 2K-26 190-015 SF NA 10" 6/30/2008 2 6/29/2008 2K-28 201-154 3'10" NA 3"10" 6/30/2008 23.8 6/30/2008 2M-04 192-093 SF NA 20" NA 3.4 7/10/2008 2M-27 192-071 9'9" 1.2 18" 7/4/2008 2.55 7/10/2008 26-07 184-024 20' 2.7 34" 7/4/2008 5.95 7/10/2008 2V-01 183-158 24" NA 24" NA 20.4 7/24/2008 2V-02 183-161 11" NA 11" NA 1.3 7/24/2008 2V-03 183-164 24' 6" 3.40 8" 7/20/2008 5.5 7/24/2008 2V-04 183-165 20' 4" 2.80 8" 7/20/2008 5.1 7/24/2008 2V-05 183-176 SF NA 4" NA 2.1 7/24/2008 2V-09 185-037 SF NA 4" NA 1.7 7/24/2008 2V-41 185-049 SF NA 4" NA 1.7 7/24/2008 2V-12 185-050 40' S.4 8" 7/20/2008 8.5 7/24/2008 2V-13 185-030 18" NA 18" NA 3.8 7/24/2008 2V-14 185-031 SF NA 4" NA 1.7 7/24/2008 2V-15 185-032 SF NA 4" NA 1.7 7/24/2008 W-ell Compliance Report File on Left side of folder 198-158-0 KUPARUK RIV UNIT Roll #1: Start: Stop Roll #2: MD 12579 TVD 06369 Completion Date: 2K-21A 50- 103-20123-01 PHILLIPS ALASKAINC Start Stop 9/25/98 Completed Status: 1-OIL Current: Name Interval D 9192 1 BHI GR REDO OH L GR-MD FINAL 10300-12577 OH L GR-MD FINAL 6181-6216 OH R SRVY LSTNG BHI 10400-12579. OH Daily Well Ops -" Are Dry Ditch Samples Required? yes Was the well cored? yes no Analysis Description Received? yes no Sent Received T/C/D 6/10/99 6/15/99 6/10/99 6/15/99 6/10/99 6/15/99 10/14/98 And Received? yes no Sample Set # Comments: ¥ Jv Wednesday, November 08, 2000 Page 1 of 1 AOGCC Lori Taylor 3010 Porcupine Drive Anchorage, AK 99510 Well Reference Data: Well No: 2K-2!A Field: Prudhoe Bay Unit County: North Slope State: Alaska Date: 07/26/99 API No: 501032012301 BHI Job~: 100860 Enclosed is the following data as listed below: Log Type Bluelines Navigamma USMPR ~DL/MNP DPR/MDL/MDP TOTALS: Log Type Navigamma USMPR MDL/MNP DPR/~DL/~DP Bluelines 2" + 5" Measured Depth Logs Folded Sepias Rolled Sepias 2" + 5" True Vertical Depth Logs Folded Sepias Rolled Sepias Mylar Film Mylar Film LAS Disks : Survey Listing ASCII Disks : LIS Tape Image File Disks LIS Verification Report & Listings :1 Depth Shift Monitor Plot : Upon Receipt, Please sign and fax to: Baker Hughes INTEQ Fax%: (907) 267-6621 Attn: Stuart Sutherland Received by: D~tm: ARCO Alaska, Inc. . Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 24, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2K-21A (Permit No. 98-158) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 2K-21A. If there are any questions, please call 263-4107. Sincerely, D. Hembling Drilling Engineer DH/skad , STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL [--~ GAS [~] SUSPENDED r'~ ABANDONED~ SERVICE 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 98-158 3 Address 8 APl Number P.O. Box 100360, Anchora~le, AK 99510-0360 50-103-20123-01 4 Location of well at sudace 9 Unit or Lease Name . ,, 269' FNL, 94' FEL, Sec. 11, T10N, R8E, UM.,Z,~ .,..,)~!,~~[ Kuparuk River Unit At Total Depth ~ 11 Field and Pool 735' FNL, 1193' FEL, Sec. 15, T10N, R8E, UM ~: KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) es'gnation and S~r~a~. ' ' -' Kuparuk River Oil Pool RKB 31', Pad 114' I ADL 25604 ALK 2678 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore 16 No. of Completions 16-Sep-98 24-Sep-98 25-Sep-98 NA feet MSL 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 12579' M D & 6369' TVD 12317' MD & 6192' TVD YES N NO U 1810' feet MD 1600' APPROX 22 Type Electric or Other Logs Run 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE VVT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.5# H-40 SURF. 115' 24" 170 sx AS II 9.625" 36.0# J-55 SURF. 3919' 12.25" 850 sx AS III, 400 sx Class G 7" 26.0# J-55 SURF. 10756' 8.5" 400 sx Class G 2.375" 4.6# L-80 10068' 12317' 2.75" slotted liner 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) N/A 26 ACID, FRACTURE, CEMEF N/A DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27 PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 10/2/98I Gas Lift Date of Test Hours Tested PRODUCTION FO'OILoBBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 10/26/98 18 TEST PERIOI: 205 592 ]7] 176I 905 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBLJ OIL GRAVITY-APl (corr) Press. 229 ] 254 24-HOU R RATE: 24~ 223 228 18° 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. VOV Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 10369' 6266' Bottom Kuparuk C 10379' 6271' Top Kuparuk A 10410' 6287' Bottom Kuparuk A 12570' 6369' Annulus left open - freeze protected with diesel. 31. LIST OF ATI'ACHMENTS Summary of Daily Drilling Reports, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,/,j--,,~ // Signed "i.~ j.~' '~ ~ .<.~" (//.,, ,~. Title ~"'r~i~','~' DATE ijj,;~t-/i ~'~' -, v - '~ Prepared l~y Nam'e/Number Sharon AIIsup-Dr~ke/2'63-46~ 2 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 CTD: Daily Summary of Sidetrack Operations Kuparuk 2K-21 Date Report Number Depth Daily Summary 09/06/98 1 0 09/07/98 2 0 O9/O8/98 3 0 09/09/98 4 0 09/10/98 5 10674 09/11/98 6 10355 09/12/98 09/13/98 7 1O383 8 10425 09/14/98 9 10424 09/15/98 10 10426 09/16/98 11 '~,'10435 09/17/98 09/18/98 09/19/98 09/20/98 09/21/98 09/22/98 09/23/98 O9/24/98 09/25/98 09/26/98 12 10523 13 10700 14 11261 15 11538 16 11660 17 12O20 18 12410 19 12578 20 12578 21 12578 Rig move. MIRU. Continue to RU. Continue to RU. MIRU CTU #4 Continue to RU. Work on BOPS. Test BOPE. Load well. Set cement kick-off plug in 7' liner. Wait on cement. Wait on cement. RIH. Mill nipple. Trip for MWD. Check injector. Log GR tie-in log. Log gr tie-in. Mill pilot hole. Trip for MWD failure. MU & test MWD. RIH. Log tie in. Mill pilot hole. .POOH. Un-deploy. Re-deploy. RIH. Mill pilot hole. Displace well. POOH for window mill. POOH. RIH w/window mill assy. Orient. Time mill window. 'POOH. MU 2nd window BHA. Replace pipe/slip inserts. Deploy BHA. RIH. RIH w/2nd window assy. Log tie-in. Complete milling window. FIT. Displace well to rio-pro. POOH. RIH. Orient. Begin drilling. Drill to 10444', POH for MWD failure, RIH and att. to drill,Motor failure,POH and replace motor (Bad transmission) RIH tie in GR and drill from 10444' to 10523' (ROP at 35 fph) Drlg. from 10445' to 10700' and landed build section,POH and LD BHA #8,Test BOPE and choke skids,PU BHA #9,Rih maintaining 1000 psi on well head. (whp 1000 to 650 psi while SI.) Drlg. from 10700' to 11261', Avg. ROP about 50 FPH., 1.5 bpm at 3200 psi. LD bha #10 and pu bha #11 ,drill from 11275' to 11538',average ROP 35-45 FPH. Drlg. from 11538' to 11652',POH to c/o motor(Bearings worn),replace washed out bleed sub. PU BHA #12 w/.75 dg. motor, RIH,drlg from 11650' to 11660'. Change out mud system, short trip to window 2x to clean hole and increase ROP. Drill from 11669' to 12020'. Drlg. from 12020' to 12410', hard time getting mwd to work properly,charge up pulsation dampner on rig pump.Better data from mwd. Drill f/12410' to 12578' (TD). Prep hole for liner. Displace well to 12.5 ppg mud. POOH for liner. Run 2-3/8" liner, work pipe f/11950'-12340', Pull liner back OOH, after finding problem with coil, LD 4 Jts of Liner assy, PU 30 Jts 1-1/4" CS Hydrii to keep bad spot in coil covered on the Reel. MU 1-1/4" CSH. RIH and release from liner. POOH. RIH. Displace well to sea water & diesel. RDMO CT unit. 09/27/98 22 12578 RDMO Nabors 3S. ARCO Alaska, Inc. Structure · Pad 2K Well · 21 Field ' Kuparuk River Unit Location ' North Slope, Alaska <- West (feet) 6900 6750 6600 6450 6300 6150 6000 5850 5700 5550 5400 5250 5100 4950 4800 4650 4500 4550 4200 4050 5900 5750 t I I I I I I I I I I I I I I I I I I I ~ I I I I I I [ I I t I I I I I I I I I I I 5400 555O T.D. - 6215.67 Tvd, 57¢1.67 S, 6573.70 W .5700 5700 t" 5850 6000 0 ,,-I-- ~ 6150 ~ 6300- 645o 2K-21ehs Tie on - 6128.12 Tvd, 6270.96 S, 4-59¢.42 W Kick off Point RECEiVFD_ 0CT 1 4 ORIGINAL Ancher~e ie on - 58.78 Inc, 10400.00 Md, 6128.12 Tvd, 3199.92 Vs ~~ff Point 2K-21 ehs T.D. - 92.07 Inc, 1257g.00 Md, 6215.1g Tvd, 5242 Vs I i I I I I I i I I i I I [ I i I '-T--- I I ' I I I -J I I I I I I I I I i I I I I I I I I I 2550 2700 2850 5000 5150 5500 5450 3600 5750 5900 4.050 4200 4350 4500 4650 4800 4950 5100 5250 5400 5550 5700 Vertical Section (feet) -> Azimuth 280.32 with reference 0.00 N, 0.00 E from slot #21 5850 0 6000 '-~ 6150 6~oo I V 6450 6600 6750 69OO ARCO Alaska, Inc. Pad 2K 2K-21 slot #21 Kuparuk River Unit North Slope, Alaska SURVEY LISTING by Baker Hughes I NTEQ Your ref : 2K-21A Our ref : sw/231 License :API 501032012301 Date printed : 28-Sep-98 Date created : 18-Sep-98 Last revised : 28-Sep-98 Field is centred on nTO 16 18.576,w150 5 56.536 Structure is centred on n70 14 33.600,w150 0 46.386 Slot location is n70 14 30.954,w150 0 49.148 Slot Grid coordinates are N 5938034.416, E 498309.546 Slot local coordinates are 269.00 S 95.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ARCO Alaska, Inc, Pad 2K~2K-21 Kuparuk River Unit~North Slope~ Alaska SURVEY LISTING Page 1 Your ref : 2K-21A Last revised : 28-Sep-98 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C 0 0 R D S Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOft Sect Easting Northing 10400.00 58.78 218.08 6128.12 6270.96S 4394,42W 2.39 3199.92 493914.23 5931765.01 10420.00 58.53 218.24 6138.53 6284.39S 4404.98W 1.43 3207.90 493903.68 5931751.59 10428.00 64.50 218.50 6142.34 6289.90S 4409.34W 74.68 3211.20 493899.31 5931746.08 10489.00 76.70 223.60 6162.58 6333,13S 4447.11~ 21.49 3240.62 493861.54 5931702.86 10512.00 81.50 229.20 6166.93 6348,69S 4463.46~ 31.73 3253.92 493845.19 5931687.31 10545.00 85.30 234.30 6170.72 6368.97S 4489.20~ 19.19 3275.60 493819.45 5931667.04 10579.00 85.50 242.90 6173.45 6386,61S 4518.10W 25.22 3300.87 493790.55 5931649.41 10606.00 85.40 249.20 6175.60 6397.53S 4542.68W 23.26 3323.10 493765.97 5931638.49 10640.00 84.90 257.40 6178.48 6407.25S 4575.10W 24.08 3353.26 4~3733.55 5931628.77 10672.00 87.40 264.90 6180.63 6412.16S 4606.63~ 24.65 3383.39 493702.02 5931623.87 10704.00 90.20 271.00 6181.30 6413,30S 4638.58W 20.97 3414.62 493670.07 5931622.74 10728.00 90.70 272.40 6181.11 6412.59S 4662.57W 6.19 3438.35 493646.09 5931623.45 10760.00 89.40 273.70 6181.08 6410,89S 4694.52W 5.75 3470.09 493614.14 5931625.16 10790.00 87.20 276.40 6181.97 6408,25S 4724.39W 11.61 3499.95 493584.28 5931627.81 10822.00 88.60 280.80 6183.15 6403,47S 4756.00W 14.42 3531.90 493552.67 5931632.60 10853.00 89.70 281.50 6183.61 6397.47S 4786.41~ 4.21 3562.90 493522.26 5931638.60 10878.00 89.90 285.70 6183.69 6391,60S 4810.70W 16.82 3587.85 493497.97 5931644.48 10915.00 88.00 289.90 6184.37 6380,29S 4845.91~ 12.46 3624.52 493462.77 5931655.79 10947.00 87.60 292.40 6185.60 6368.75S 4875.73~ 7.91 3655.92 493432.95 5931667.33 10981.00 89.50 291.90 6186.46 6355.94S 4907.21~ 5.78 3689.19 493401.48 5931680.15 11017.00 91.40 290.00 6186.18 6343.07S 4940.83W 7,46 3724.57 493367.87 5931693.03 11054.00 90.50 287.10 6185.56 6331.30S 4975.90~ 8.21 3761.18 493332.81 5931704.80 11086.00 87.30 284.50 6186.18 6322.59S 5006.68~ 12.88 3793.02 493302.03 5931713.52 11117.00 88.20 281.30 6187.40 6315.68S 5036.871~ 10.72 3823.96 493271.85 5931720.44 11150.00 89.50 279.90 6188.06 6309.61S 5069.30W 5.79 3856.95 493239.42 5931726.51 11189.00 90.70 281.90 6187.99 6302.23S 5107.59~ 5.98 3895.94 493201.13 5931733.89 11227.00 90.00 284.80 6187.76 6293.46S 5144.56W 7.85 3933.89 493164.17 5931742.67 11259.00 88.70 289.70 6188.12 6283.98S 5175.11~ 15.84 3965.64 493133.63 5931752.16 11287.00 86.80 291.10 6189.22 6274.22S 5201.33~ 8.43 3993.18 493107.41 5931761.92 11320.00 87.00 289.70 6191.01 6262.74S 5232.21W 4.28 4025.63 493076.53 5931773.41 11355.00 90.30 290.60 6191.83 6250.69S 5265.06W 9.77 4060.10 493043.69 5931785.47 11386.00 89.20 287.90 6191.97 6240,47S 5294.32W 9.40 4090.72 493014.43 5931795.69 11415.00 90.30 287.60 6192.09 6231.63S 5321.94W 3.93 4119.47 492986.82 5931804.54 11444.00 93.10 289.00 6191.23 6222.53S 5349.46~ 10.79 4148.18 492959.31 5931813.64 11486.00 94.20 291.60 6188.56 6207.99S 5388.76W 6.71 4189.45 492920.01 5931828.19 11516.00 91.40 293.10 6187.09 6196.59S 5416.47W 10.59 4218.76 492892.30 5931839.59 11545.00 88.70 292.90 6187.07 6185.26S 5443.171fl 9.34 4247.05 492865.62 5931850.92 11578.00 86.90 291.50 6188.33 6172.80S 5473.70W 6.91 4279.31 492835.09 5931863.39 11612.00 86.60 293.50 6190.26 6159.82S 5505.06W 5.94 4312.49 492803.74 5931876.38 11649.00 89.00 292.50 6191.68 6145.37S 5539.09~ 7.03 4348.56 492769.71 5931890.83 11689.00 88.30 293.20 6192.62 6129.84S 5575.94W 2.47 4387.60 492732.87 5931906.37 11719.00 86.80 290.60 6193.91 6118.66S 5603.74~ 10.00 4416.96 492705.07 5931917.55 11749.00 87.40 291.60 6195.42 6107.88S 5631.69~ 3.88 4446.39 492677.12 5931928.34 11780.00 86.60 293.50 6197.05 6096.01S 5660.28W 6.64 4476.64 492648.54 5931940.22 11809.00 84.90 295.60 6199.20 6083.99S 5686.59~ 9.30 4504.67 492622,24 5931952.24 11839.00 86.90 297.30 6201.34 6070.66S 5713.38~ 8.74 4533.41 492595.46 5931965.57 11869.00 87.80 299.80 6202.73 6056.34S 5739.70~ 8.85 4561.88 492569.14 5931979.89 11910.00 88.50 300.90 6204.05 6035.64S 5775.06~ 3.18 4600.38 492533.79 5932000.60 11946.00 86.60 300.50 6205.59 6017.28S 5805,98~ 5.39 4634.09 492502.87 5932018.97 11979.00 87.20 300.50 6207.38 6000.55S 5834.38W 1.82 4665.02 492474.48 5932035.70 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #21 and TVD from MSL - rkb = 154 ft. Bottom hole distance is 8578.51 on azimuth 227.99 degrees from wellhead. Vertical section is from wellhead on azimuth 280.32 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 2K,2K-21 Kuparuk River Unit,North Slope, Alaska SURVEY LISTING Page 2 Your ref : 2K-21A Last revised : 28-Sep-98 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C 0 0 R D S Depth Degrees Degrees Depth C 0 0 R O ! N A T E S Deg/lOOft Sect Easting Northing 12006.00 86.70 299.40 6208.81 5987.09S 5857.74W 4.47 4690.41 492451.13 5932049.16 12042.00 85.20 297.90 6211.35 5969.87S 5889.25W 5.89 4724.50 492419.62 5932066.38 12077.00 85.50 296.40 6214.19 5953.96S 5920.29W 4.36 4757.89 492388.59 5932082.31 12107.00 84.30 295.20 6216.86 5940.95S 5947.19W 5.65 4786.68 492361.69 5932095.32 12135.00 84.60 293.90 6219.57 5929.37S 5972.54W 4.74 4813.70 492336.35 5932106.90 12185.00 87.10 292.60 6223.19 5909.69S 6018.35~ 5.63 4862.30 492290.54 5932126.59 12214.00 86.70 289.90 6224.75 5899.20S 6045.34~ 9.40 4890.73 492263.56 5932137.09 12244.00 87.30 290.70 6226.32 5888.80S 6073.44~ 3.33 4920.23 492235.47 5932147.49 1227/.00 88.50 292.50 6227.53 5876.66S 6304.10W 6.55 4952.57 492204.82 5932159.63 12308.00 90.80 293.50 6227.72 5864.55S 6132.63W 8.09 4982.81 492176.29 5932171.75 12338.00 92.20 295.40 6226.94 5852.14S 6759.93W 7.87 5011.89 492149.00 5932184.17 12366.00 92.30 297.80 6225.84 5839.61S 6184.94W 8.57 5038.75 492123.98 5932196.70 12396.00 93.90 297.00 6224.22 5825.83S 6211.54W 5.96 5067.38 492097.40 5932210.49 12422.00 92.50 298.90 6222.76 5813.66S 6234.47W 9.07 5092.12 492074.47 5932222.66 12449.00 94.30 299.00 6221.16 5800.61S 6258.05W 6.68 5117.66 492050.89 5932235.71 12483.00 94.20 297.50 6218.64 5784.57S 6287.92~ 4.41 5149.92 492021.03 5932251.76 12511.00 92.90 297.10 6216.91 57/1.75S 6312.75W 4.86 5176.64 491996.20 5932264.58 12540.00 91.00 296.60 6215.92 5758.66S 6338.61W 6.77 5204.43 491970.35 593227-/.67 12554.00 90.50 295.50 6215.74 5752.51S 6351.19W 8.63 5217.90 491957.78 5932283.82 12579.00 92.07 295.92 6215.18 5741.67S 6373.70W 6.50 5242.00 491935.26 5932294.67 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #21 and TV[) from MSL - rkb = 154 ft. Bottom hole distance is 8578.51 on azimuth 227.99 degrees from wellhead. Vertical section is from wellhead on azimuth 280.32 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET arid con~auted using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ INTEQ AOGCC Lod Taylor 3010 Porcupine Drive Anchorage, Alaska 99501 7260 Homer Drive, Anchorage, AK 99518 July 26, 1999 Dear Ms. Taylor: ~p.~,~)O This letter is intended to correct the remarks of the comment section for a Gamma Ray log distributed recently. The Gamma Ray in question was logged by Baker Hughes INTEQ' MWD on Well 2K-21A, Kuparuk River Unit, North Slope, Alaska for ARCO Alaska, Inc. This log was acquired on 23 September 1998. The remarks in the comment section indicated that the PDC used was "Sperry Sun's MCNL Gamma Ray data". Enclosed you will find a disk with a revised tape file which corrects the comment to "Sperry Sun's open hole Gamma Ray data". Thank you. Sincerely, Rahul Madarapu MWD Specialist MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Joh .n~, DATE' Chairman September 17, 1998 THRU: Blair Wondzell, ~,,¢,e-~ FILE NO: P. I. Supervisor ~[~3)~ ab91iqfe.doc Confidential: Yes No X FROM: John Spaulding~.~ SUBJECT: Petroleum Ins¢ BOPE Test Nabors 3S / Doweil ARCO / Kuparuk / 2K-21A PTD 98-158 September 17, 1998:1 traveled to ARCO Alaska's Kuparuk River Field to witness the BOPE on the Nabors 3S / Schlumberger Dowell Coiled Tubing Drilling Unit. The AOGCC BOPE test report is attached for reference. As noted on the test report no failures were observed. The crew was quite competent and the equipment was found to be in good condition. This well is somewhat of a science project as it being drilling slightly under balanced or very near balance. This type of drilling has been attempted in the Prudhoe Field with very limited succcess. The Kuparuk formation may be a much better candidate for under balanced drilling. At this time the drilling is going quite well. Summary: I witnessed the BOPE test on; Nabors 3S / Dowell CTD unit, 9/17/98, Test time 4 hrs., 0 failures Attachments: ab91iqfe.xis STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION Coil Tubing Unit BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial Workover: Nabors 3S / Dowefl Rig No. ARCO Kuparuk 2K-2?A Set @ X Weekly Other 3S PTD # Rep.: Rig Rep.: Location: Sec. TEST DATA ,: DATE: 9/17/98 98-?58 Rig Ph.# 659-7?82 Mike Reynolds Jimmy Fritts 17 T. ?ON R. SE Meridian Umiat BOP STACK: Coil Tubing Unit: Pipe/Slip Rams Pipe/Slip Rams -Blind Rams Reel Isolation Valve Deployment: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Test Quart. Pressure P/F 250/4000 P 250/4000 P 250/4000 P 1 1 1 250/2500 1 250/4000 1 250/4000 1 250/4000 1 250/4000 1 250/4000 2 250/4000 CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Quan. Pressure P/F 20 250/4000 P 65 P 2 P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 4 @ 2200 avg. Functioned Functioned VIUD SYSTEM: Visual Alarm MISC. INSPECTIONS: Trip Tank ok ok Location Gen.: ok Pit Level Indicators ok ok Housekeeping: ok Meth Gas Detector ok ok Permit to drill: ok H2S Gas Detector ok ok Standing Order Posted 2, 750 I P 1,950 I P minutes 18 sec. minutes 42 sec. Remote: X' Psig. yes Well Sign yes Drl. Rig ok Hazard Sec. yes TESTRESULTS .... Number of Failures: 0 ,Test Time: 4.0 Hours. Number of valves tested 29 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Distribution: orig-Well File c- Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X' NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: John H. Spaulding Form Revised 2/20/97 L.G. Ab91iqfe.xls 9/23/98 TONY KNOWLE$, GOVERNOR ALASI A OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 August 31, 1998 Drew Hembling Drill Site Development Supv ARCO Alaska Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 2K-2 lA ARCO Alaska Inc. Permit No. 98-158 Sur. Loc. 269'FNL, 94'FEL. Sec. 11, T10N, R8E? UM Btmnhole Loc. 880'FNL, 1298'FEL, Sec. 15, T10N, R8E, UM Dear Mr. Hembling: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice max' be given by ~oleum field inspector on the North Slope pager at 659-3607. i Chairman BY ORDER OF THE COMMISSION dlffEnclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALA~ OIL AND GAS CONSERVATION coMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Ddll X Reddll C~ lb Type of Well Exploratory F' StratigraphicTest E~ Development Oil X Re-Entry [--' Deepen r~ Service E Development Gas ~-' Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 31', Pad 114' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25604, ALK 2678 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 269' FNL, 94' FEL, Sec. 11, T10N, R8E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1498' FNL, 452' FWL, Sec. 14, T10N, R8E, UM 2K-21A #U-630610 At total depth 9. Approximate spud date Amount 880' FNL, 1298' FEL, Sec. 15, T10N, R8E, UM September 1998 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 12707' MD 452' @ Target feet 2K-20 at 1780' at 10400' MD feet 2560 6349' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 10423' feet Maximum hole angle o Maximum surface 3930 psig At total depth (TVD) 6335 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) 2.75" 2.375" 4.6# L-80 FL4S 2507' 10200' 6180' 12707' 6349' 15 bbls 19. To be completed for Redrill, Re-entry, and Deepen Operations. /'& U 'O Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet jl~aSk~ 0il & Gas Cons. Commission Anchorage Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production Perf°rati°:i;;;th: truemeasuredvertical 0 R i G ! l~J A L 20. Attachments Filing fee X Property plat F~ BOP Sketch X Diverter Sketch E Ddlling program X Drilling fluid program F' Time vs depth plot F~ Refraction analysis [~ Seabed report [~ 20 AAC 25.050 requirements 21. I hereby certify that the foregoing issue and corr. ect to the best of my knowledge Sign e ~~__~__~,.,~ ,~~~~~'/ Title Drill Site Develop. Supv. Date ~. I APl number Approval date See cover letter for Permit Nu --//,~",~ 50-/'4:~3 - / ~ ,~ '"' ~ / -~-¢,~/' other requirements Conditions of approval Samples required F' Yes J~ No Mud logrequired r'~ Yes ~" No Hydrogen sulfidemeasures ,~ Yes [~ No Directional survey required ~ Yes [~ No Required working pressure for BOPE [~ 2M [~ 3M [~ 5M [-' 10M [~ 15M Other: Original Signea ~,,,~ by order of Approved bY David W..Johnston Commissioner the commission Date .......... Form 10-401 Rev. 7-24-89 Submit in triplicate STATE OF ALASKA "-~ · ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Ddll X Reddll ~' lb Type of Well Exploratory E~ StratigraphicTest r-' Development Oil X Re-Entry E Deepen [=- Service E Development Gas E Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 31', Pad 114' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25604, ALK 2678 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 2O AAC 25.O25) 269' FNL, 94' FEL, Sec. 11, T10N, RSE, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1498' FNL, 452' FVVL, Sec. 14, T10N, RSE, UM 2K-21A #U-630610 At total depth 9. Approximate spud date Amount 880' FNL, 1298' FEL, Sec. 15, T10N, RSE, UM September 1998 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and 'I'VD) property line 12707' MD 452' @ Target feet 2K-20 at 1780' at 10400' MD feet 2560 6349' '1'VD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 10423' feet Maximum hole angle o Maximum surface 3930 psig At total depth (TVD) 6335 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD T'VD (include stage data) 2.75" 2.375" 4.6# L-80 FL4S 2507' 10200' 6180' 12707' 6349' 15 bbls 19. To bc c;.:~.p!ci~d for Reddll, Re-entry, and Deepen Operations. summary ~,'? C, ~; Present well condition Total depth: measured feet Plugs (measured) /~, U ".~ true vertical feet Effective depth: measured feet Junk (measured) A~$ka 0i~ & Gas C0[llS· true vertical feet Anchorage Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production Perforatio~i~;ith: measuredE)UjDLI true vertical 20. Attachments Filing fee X Property plat r- BoP Sketch X Diverter Sketch E~ Drilling program X Drilling fluid program E~ Timevs depth plot [--' Refraction analysis E~ Seabed report ~' 20 AAC 25.050 requirements r-~ 21. i hereby certify that the foregoing is J,rue and correct to the best of my knowledge Signe~~__~__~.,,~ ~.~/ Title Drill Site Develop. Supv. Date ,c~1~J5,~3~/ ~ ...... ~/ Commission Use Only Permit,_,Number , I APl number ~ .... I Approval date ~ _,~/ ,/;,,~ I See cover letter for ~'~ -//,.~ ~ [ 50- ,//'<::::::7,,~ -" ~-'-'~ O ,/~__ ..~-' O / I ~-'-,=2--/--~"~'~ I other requirements Conditions of approval Samples required ~ Yes .~ No Uudlogrequired [-- Yes '~ No Hydrogen sulfidemeasures ~ Yes r- No Directional surveyrequired ~' Yes [~ No Required working pressure for BOPE ['- 2M [-= 3M ~' 5M [--" 10M ~' 15M Other:. Ol'Jgir~a, SJgRe(~ ~/ byordero, ~ ~ Approved by 0avid W. J011rlstr)n Commissioner the commission Date '"' Form 10-401 Rev. 7-24-89 Submit in triplicate Kuparuk 2K-21A CT Sidetrack and Completion Intended Procedure Objective: Plugback e~sting wellbore with 17 ppg cement. Mill window in 7" casing. Directionally drill a horizontal well from the existing wellbore. Complete with 2-3/8" cemented liner. Perforate appropriate intervals. Intended Procedure: Cement squeeze the existing perforations with 17 ppg cement. Leave top of cement @ ~ 10390' md to act as a cement whipstock. Mill window in 7" liner at 10423' md. Drill 10' of formation and perform leak off test to 0.5 ppg above the highest anticipated mud weight. Plans are to drill at near balanced bottom hole pressure conditions. Directionally drill 2-3/4" x ~1800' horizontal well to access Kuparuk A4 reserves. · Run 2-3/8" blank liner to TD, cement in place. · Perforate, place on production. July 27, 1998 Kuparuk 2K-21A Potential Drilling Hazards POST ON RIG No H2S production is anticipated. BHP: 3930 psi @ 6180' ss (12.2 ppg EMW) based on SBHPS 7/26/98. Reservoir frac gradient is -0.8 psi/ft or 15.4 EMW. Plans are to drill near balanced reservoir pressure conditions. Monitor return line flow rate and pit volume continuously. Maximum anticipated WHP w/full colunm of gas: -3300 psi. No gas saturated intervals are expected. July 27, 1998 KRU 2K-21A Proposed CT Sidetrack Horizontal 3-1/2" 3-1/2" Camco TRDP SSSV Packers 10001' 10189' XN Nipple 1 Sqz Perfs 10120'- 122' Tbg Tail 10,240' Top of 2-3/8" Liner in 3-1/2" Tbg. tail. Initial Perfs- 1200' 7" Casing shoe @ 1 Window cut in 7" at -10420'-10425' ----~ 2-3/4" Open hole Current perforations to be cement squeezed 2-3/8" liner TD @ - 127O7' C T Drilling Wellhead Detail Methanol Injection Otis 7" WLA Quick Connect ~ CT Injector Head I ~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure .-- 7" Riser I I Annular BOP (Hydril),7-1/16" ID 5000 psi WP Alignment Guide Flange 7-1/16", 5M Ram Type Dual Gate BOPE Flanged Fire Resistant Man Kelly Hose to Dual HCR Choke Manifold \ Cutters or Combination CuttedBlinds Slip/Pipe Rams Manual Valves Drilling spool 7-1/16", 5M by 7-1/16", 5M Manual over Hydraulic Ram Type Dual Gate BOPE 7-1/16" ID with Pipe/Slip Rams 2" Pump-In Manual Master Valve 0.458' (5.5") Hanger Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold 9-5/8" Annulus 13-3/8" Annulus Mu~ Tanks 60/40I I TrplxI I Plre Ext. Shop Fuel Boilers Water Pump Fire Ext. Fire Ext. ,~Pipe rack Dowell Drilling Equipment Trailer Preferred Major Equipment Layout for CT Drilling ARCO Alaska, Inc. Structure · Slot' 2K-21 Field · Kuparuk River Unit Location · Nodh Slope, Alaska West (feet) 6600 6500 6400 6300 6200 6100 6000 5900 5800 5700 5600 5500 5400 5300 5200 5100 5000 4900 4800 4700 4600 4500 4400 4300 I I I I I I I I I I I I I t I I I I I I I I I I I I I I I I [ I I I I I I I I I I I I I I I ] I I.D. & End of Drop - 6195.00 Tvd, 5886.38 $, 6478.95 W 2K- 5700 - 5800 5900 6000 61oo f5800 5900 6000 Tie on - 6128.14 Tvd, 6270.94 S, 4394.40 6200 6300 6100 0 .-,,i- 6200 6300 I v 6400 6500 6600 .6700 fie on - 58.78 Inc, 10400.00 Md, 6128.14 Tvd, 0.00 Vs ~ Point 4 5 2K-21bhs 'r.D. & End of Drop/Turn - 89.59 Inc, 12707.,51 Md, 6195.00 Tvd, 2119.72 Vs ,, I ! I I I I I I I I I I O0 0 1 O0 200 300 400 500 2K-21 I I I i I I I I I ! I I I iI i I I i i i i I i I ii i i i i I I I 600 700 ~oo soo 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 ~200 Verficol Secfion (feet) -> Azimuth 280.32 with reference 6270.94 S, 4394.40 W from 2K-21 Company: Well: Calculation Method: Vertical Sect. Plane: Vertical Secl. Plane: Measured Depth from: True Vertical l)eplh: Proposal Calculations Coordinates provided in' TRUE and GRID relative to Wellhead and AI.ASKA STATE PI.AN ARC() Alaskat Inc. 2K-21 Minimum Curvature 280.320 TRUE 280.310 GRil) RKB Sea level Rig: Field: Mag. Declination: (;rid Correction: Total Correction: RKB Height: Nabors 3s/CTU #4 Prudhoe Ba}~? Alaska 27.090 0.010 27.{ 80 0 Coords. - GRID Coords. TRUE Coords.- ASP N(+)/S(-) N(+)/S(-) E(+)/W(-) Lat. (Y) I.at. (Y) Dcp. (X) -6270.94 -4394.40 5931765.01 493914.23 -6286.38 -4406.54 5931749.57 -6287.72 -4407.60 5931748.23 -6304.95 -4421.19 5931731.00 -6322.91 -4435.39 5931713.03 -6341.48 -4450.10 5931694.46 -6360.52 -4465.19 5931675.42 -6379.87 -4480.55 5931656.06 -6399.40 -4496.07 5931636.54 -6399.79 -4496.39 5931636.15 -6418.27 -4512.45 5931617.66 -6435.63 -4530.43 -6451.32 -4549.87 -6465.24 -4570.63 -6477.26 -4592.54 -6487.30 -4615.42 -6495.27 -4639.11 N(+)/S(-) E(+)/W(-) i~t.(Y) -6269.41 -4395.32 493902.10 -6284.85 -4407.45 493901.04 -6286.19 -4408.51 493887.45 -6303.42 -4422.10 493873.24 493858.54 493843.46 493828.09 493812.58 493812.27 493796.21 5931600.30 493778.23 5931584.60 493758.79 5931570.68 493738.04 5931558.65 493716.13 5931548.61 493693.25 5931540.64 493669.56 -6501.12 -4663.40 5931534.78 -6504.79 -4688.12 5931531.11 -6506.27 -4713.07 5931529.63 -6506.07 -4728.64 5931529.83 -6505.53 -4738.05 5931530.36 -6502.61 -4762.87 5931533.27 -6501.95 -4766.80 5931533.93 -6498.26 -4787.49 5931537.62 -6493.77 -4812.08 5931542.11 -6489.16 -4836.66 -6484.43 -4861.21 5931551.44 -6479.59 -4885.73 5931556.27 -6474.64 -4910.24 5931561.22 -6469.57 -4934.72 5931566.21 -6464.39 -4959.17 5931571.4~ -6459.10 -4983.61 5931576.75 -6453.69 -5008.01 5931582.16 -6448.16 -5032.40 5931587.68 493645.27 -6321.38 -4436.30 -6339.96 -4451.00 -6358.99 -4466.09 -6378.35 -4481.45 -6397.88 -4496.97 -6398.27 -4497.28 -6416.76 -4513.34 -6434.12 -4531.31 -6449.82 -4550.75 -6463.74 -4571.51 -6475.76 -4593.42 -6485.80 -4616.30 -6493.78 -4639.98 -6499.63 -4664.28 493620.55 -6503.31 -4689.00 493595.60 -6504.79 -4713.95 493580.03 -6504.59 -4729.51 493570.62 -6504.06 -4738.93 493545.80 -6501.14 -4763.75 493541.87 -6500.48 -4767.67 493521.18 -6496.80 -4788.37 493496.58 -6492.31 -4812.96 493472.01 -6487.70 -4837.53 493447.46 -6482.98 -4862.08 493422.93 -6478.15 -4886.61 -6473.20 -4911.12 493373.95 -6468.13 -4935.60 493349.49 -6462.96 -4960.06 493325.06 -6457.66 -4984.49 493300.65 -6452.26 -5008.90 493276.27 -6446.74 -5033.28 Job No: AFE No: Bill Rep: Job Start Date: Job End Date: DI.S (~/!00 ft): 0 IOO.00 Comments Tie in Point Kick off Point 3 4: 2K-21bhs 5 Meas. lnci. TRUE GRID Subsea Coords. - TRUE Coords. - ASP Coords. - GRID Dogleg Tool Face Vertical Build Turn Depth Angle AzL Azi. TVD N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) Section Comments (deg) (de~) (deg) (it) l~t. (Y) Dep. (X) I.at. (Y) l)ep. (X) Lat. (Y) Dep. (X) (°/IiX)fi) (from TIPI (°/llX)l't) ('710011) 1'i i 75.00 89.76 283.17 283.16 6186.23 -6442.52 -5056.75 5931593.31 493251.91 -644 i. i i -5057.64 1.07 90.00 620.92 -0.04 1.08 i 1200.00 89.76 283.43 283.42 6186.33 -6436.77 -5081.08 5931599.06 493227.58 -6435.36 -5081.97 1.07 90.00 645.89 0.00 1.04 I 1225.00 89.76 283.70 283.69 6186.44 -6430.91 -5105.38 5931604.92 493203.27 -6429.50 -5106.27 1.07 90.00 670.85 0.00 1.08 I 1250.00 89.75 283.97 283.96 6186.55 -6424.93 -5129.66 5931610.89 493179.00 -6423.53 -5 ! 30.55 1.07 90.00 695.80 -0.04 1.08 11275.00 89.75 284.23 284.22 6186.65 -6418.84 -5153.90 5931616.98 493154,75 -6417.44 -5154.79 1.07 90.00 720.74 0.00 I.I14 Il300.00 89.75 284.50 284.49 6186.76 -6412.64 -5178.12 5931623.17 493130.53 -6411.24 -5179.01 1.07 90.00 745.68 0.00 1.08 ! 1325.00 89.74 284.77 284.76 6186.88 -6406.32 -5202.31 5931629.49 493106.34 -6404.93 -5203.20 1.07 90.00 770.61 -0.04 1.08 1i350.00 89.74 285.04 285.03, 6186.99 -6399.89 -5226.47 5931635.91 493082.18 -6398.50 -5227.36 1.07 90.00 795.53 0.00 1.08 I 1375.00 89.74 285.30 285.29 6187.10 -6393.35 -5250.60 5931642.45 493058.05 -6391.96 -5251.49 1.07 90.00 820.44 0.(g) 1.04 11400.00 89.74 285.57 285.561 6187.22 -6386.70 -5274.70 5931649.10 493033.95 -6385.32 -5275.59 1.07 90.00 845.34 0.00 1.08 11425.00 89.73 285.84 285.83 6187.33 -6379.93 -5298.76 5931655.86 4931109.89 -6378.55 -5299.66 1.07 90.00 870.23 -0.04 1.08 11450.00 89.73 286.1 286.10 6187.45 -6373.05 -5322.80 5931662.74 492985.85 -6371.68 -5323.69 1.07 90.00 895.11 0.00 1.08 11475.00 89.73 286.37 286.36 6187.57 -6366.06 -5346.80 5931669.73 492961.85 -6364.69 -5347.70 1.07 90.011 919.97 0.00 1.04 11500.00 89.72 286.64 286.63 6187.69 -6358.95 -5370.77 5931676.82 492937.88 -6357.59 -5371.67 1.07 90.011 944.83 -0.114 1.08 11525.00 89.72 286.91 286.90 6187.8 -6351.74 -5394.~} 5931684.04 492913.94 -6350.38 -5395.61 1.07 90.00 969.67 0.00 1.08 11550.00 89.72 287.18 287.17 6187.93 -6344.41 -5418.61 5931691.36 492890.04 -6343.06 -5419.51 1.07 90.011 994.50 0.00 1.118 , , il575.00 89.7 287.44 287.43 6188.06 -6336.97 -5442.47 5931698.79 492866.17 -6335.62 -5443.38 1.07 90.011 1019.31 -0.04 1.04 11600.00 89.71 287.71 287.70 6188.18 -6329.42 -5466.31 5931706.34 492842.33 -6328.08 -5467.21 1.07 90.00 1044.1 I 0.00 1.08 11625.00 89.71 287.98 287.47 6188.31 -6321.76 -5490.10 5931714.00 492818.54 -6320.42 -5491.01 1.07 ~}~.00 1068.89: 0.00 !.08 11650.00 89.71 288.24 288.23 6188.43 -6313.99 -5513.86 5931721.76 492794.77 -6312.65 -5514.77 !.071 90.00 1093.66 0.00 1.04 11675.00 89.70 288.51 288.50 6 ! 88.56 -6306. I I -5537.59 5931729.64 492771.05 -6304.78 -5538.50 1.07 90.00 I I 18.41 -0.04 1.08 ll700.00 89.70 288.78 288.77 6188.69 -6298.12 -5561.28 5931737.63 492747.36 -6296.79 -5562.19 i.07 90.00 ll43.15 0.00 1.08 I 1725.00 89.70 289.05 289.04 6 i 88.83 -6290.02 -5584.93 5931745.73 492723.7 -6288.69 -5585.84 1.07 90.00 I 167.87 0.00 1.08 i 1750.00 89.69 289.31 289.30 6188.96 -6281.80 -5608.54 5931753.94 492700.09 -6280.48 -5609.45 1.07 90.(}0 I 192.57 -0.04 1.04 i'i 775.00 89.69 289.58 289.57 6 i 89.09 -6273.48 -5632. I I 5931762.25 492676.52 -6272.16 -5633.03 1.07 90.00 'i 217.25 0.00 i.118 11800.00 89.69' 289.85 289.84 6189.23 -6265.05 -5655.65 5931770.68 492652.98 -6263.73 -5656.56 1.07 90.00 1241.92 0.00 I.II8 I 1825.00 89.68' 290.12 290. I I 6189.37 -6256.50 -5679.14 5931779.22 492629.49 -6255.19 -5680.06 1.07 90.00 1266.56 -0.04 1.08 I 1850.00 89.68 290.38 290.37 6189.51 -6247.85 -5702.59 5931787.87 492606.03 -6246.54 -5703.5 i 1.07 90.00 129 I. 19 0.00 1.04 I 1875.00 89.68 290.65 290.64 6189.65 -6239.09 -5726.01 5931796.63 492582.62 -6237.79 -5726.93 1.07 90.00 1315.79 0.00 1.08 i 1900.00 89.68 290.92 290.91 6189.79 -6230.22 -5749.38 5931805.50 492559.24 -6228.92 -5750.30 1.07 90.(10 1340.37 0.00 1.08 11925.00 89.67 291.19 291.18 6189.93 ~-6221.23 -5772.71 5931814.47 492535.91 -6219.94 -5773.64 1.07 90.00 1364.94 -0.04 I.I18 , ,, 11950.00 89.67 291.45 291.44 6190.07 -6212.15 -5796.00 5931823.56 492512.62 -6210.86 -5796.93 1.07 90.00 1389.48 0.00 I.II4 ,,, 11975.00 89.67 291.72 291.71 6190.22 -6202.95 -5819.25 5931832.75 492489.37 -6201.66 -5820.17 1.07 90.00 1413.99 0.00 1.08 12000.00 89.66 291.99 291.98 6190.36 -6193.64 -5842.45 5931842.05 492466.17 -6192.36 -5843.38 1.07 90.00 1438,49 -0.(}4 1.08 12025.00 89.66 292.25 292.24 6190.51 -6184.23 -5865.61 5931851.46 492443.01 -6182.95 -5866.54 1.07 90.00 1462.96 0.011 1.04 12050.00 89.66 292.52, 292.51 6190.66 -6174.71 -5888.73 5931860.98 492419.89 -6173.44 -5889.66 1.07 90.011 1487.4 0.(10 1.08 ,, ,,, 12075.00 89.66 292.79 292.78 6190.81 -6165.08 -5911.80 5931870.61 492396.82 -6163.81 -5912.73 1.07 90.00 1511.83 0.00 1.08 12100.00 89.65 293.06 293.05 6190.96 -6155.34 -5934.82 5931880.34 492373.79 -6 i 54.08 -5935.76 1.07 90.011 1536.22 -0.04 1.118 12125.00 89.65 293'.~2 293.3 6191.11 -6145.50 -5957.80 5931890.18 492350.81 -6144.24 -5958.74 1.07 90.110 1560.60 0.00 1.04 ,,, 12 ! 50.00 89.65 293.59 293.58 6191.26 -6135.55 -5980.73 5931900.13 492327.87 -6134.29 -5981.67 1.07 90.00 1584.94 0.011 1.08 12 ! 75.00 89.641 293.86 293.85 6191.42 -6125.49 -6003.62 5931910.18 492304.98 -6124.23 -6004.56 1.07 90.(10 1609.26 -0.04 1.08' 12200.00 89.64 294.13 294.12 6191.57 -6115.32 -6026.46 5931920.34 492282,14 -6114.07 -'6027.40 1.07 90.00 1633.55 0.(10 1.08 ,, 12225.00 89.64 294.39 294.38 6191.73 -6105.05 -6049.25 5931930.61 492259.35 -6103.80 -6050.20 1.07 90.00 1657.8 11.00 1.04 12250.00 89.64 294.66 294.65 6191.89 -6094.67 -6072.00 5931940.98 492236.60 -6093.43 -6072.94 1.07 90.00 1682.05 0.00 1.08 12275.00 89.63 294.93 294.92 6192.05 -6i)84.19 -6094.69 5931951.46 492213.91 -6082.95 -6095.64 1.07 90.00 1706.25 -0.04 i .08 12300.00 89.63 295.20 295.19 6192.2 ! -6073.60 -6117.34 5931962.05 492191.26 -6072.36 -6118.29 1.07 90.00 1730.43 0.00 1.08 12325.00 89.63 295.46 295.45 6192.37 -6062.90 -6139.93 59~ 1972.74 492168.66 -6061.67 -6140.88 1.07 90.110 1754.57 0.00 I .'64 i ~350.00 89.62 295.73 295.72 6192.53 -6052. l0 -6162.48 5931983.54 492146. I -6050.88 -6163.43 1.07 90.00 'l '/78.69 -0.04 ! .08 i ~75.00 89.62 296.00 295.99 6192.70 -604 1.20 -6184.97 5931994.44 492123.62 -6039.97 -6 i 85.93 1.07 90.00 1802.77 0.00 I ~8 12400.00 89.62 296.26 296.25, 6192.87 -6030.19 -6207.42 5932005.45 492101.17 -6028.97 -6208.38 1.07 90.00 1826.83 0.00 1.04 , , Kuparuk 2K-21A CT Sidetrack and Completion Intended Procedure Objective: Plugback existing wellbore with 17 ppg cement. Mill window in 7" casing. Dh'ectionally drill a horizontal well from the existing wellbore. Complete with 2-3/8" cemented liner. Perforate appropriate intervals. Intended Procedure: Cement squeeze the existing perforations with 17 ppg cement. Leave top of cement @ ~10390' md to act as a cement whipstock. Mill window in 7" liner at 10423' md. Drill 10' of formation and perform leak off test to 0.5 ppg above the highest anticipated mud weight. Plans are to drill at near balanced bottom hole pressure conditions. Directionally drill 2-3/4" x ~1800' horizontal well to access Kuparuk A4 reserves. · Run 2-3/8" blank liner to TD, cement in place. · Perforate, place on production. July 27, 1998 Kuparuk 2K-21A Potential Drilling Hazards POST ON RIG No H2S production is anticipated. BHP: 3930 psi @ 6180' ss (12.2 ppg EMW) based on SBHPS 7/26/98. Reservoir frac gradient is -0.8 psi/ft or 15.4 EMW. Plans are to drill near balanced reservoir pressure conditions. Monitor return line flow rate and pit volume continuously. Maximum anticipated WHP w/full column of gas: -3300 psi. No gas saturated intervals are expected. July 27, 1998 KRU 2K-21A Proposed CT Sidetrack Horizontal 3-1/2" Tu 3-1/2" Camco TRDP SSSV Packers 10001' 10189' Sqz Perfs 10120'- 122' XN Nipple 1 Tbg Tail 10,240' Top of 2-3/8" Liner in 3-1/2" Tbg. tail. Initial Perfs~ 1200' 7" Casing shoe @ 1 Window cut in 7" at ~10420'-10425' 2-3/4" Open hole Current perforations to be cement squeezed 2-3/8" liner TD @ ~ 12707' Drilling Wellhead Detail Methanol Injection Otis 7" WLA Quick Connect - Alignment Guide Flange 7-1/16", 5M Ram Type Dual Gate BOPE Flanged Fire Resistant Kelly Hose to Dual HCR Choke Manifold Man ~ CT Injector Head ~ I ~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure -- -- 7" Riser ! -'~ Annular BOP (Hydril),7-1/16" ID 5000 psi WP Cutters or Combination Cutter/Blinds Slip/Pipe Rams Manual Valves Drilling spool 7-1/16", 5M by 7-1/16", 5M Manual over Hydraulic Ram Type Dual Gate BOPE 7-1/16" ID with Pipe/Slip Rams Manual Master Valve 0.458' (5.5") 2" Pump-In Hanger ri Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold 9-5/8" Annulus 13-3/8" Annulus Mu~ Tanks 60/401 I TrplxI hire Ext. Fuel Shop Boilers Water Pump Fire Ext. Fire Ext. Pipe rac/~ Dowell Drilling Equipment Trailer Preferred Major Equipment Layout for CT Drilling ARCO Alaska, Inc. Field · Kuporuk River Unit Location · Nor"th Slope, Alaska <- Wesf (feel) 6600 6500 6400 6300 6200 6100 6000 5900 5800 5700 5600 5500 5400 5300 5200 5100 5000 4900 4800 4700 4600 4500 4400 4300 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 I I I I I I I I I I I I T.D. & End of Drop - 6195.00 Tvd, 5886.38 S, 6478.95 W 2K- A 5700 - ,-I,-. ~-~ 5800 5900 Tie on - 6128.14 Tvd, 6270.94 S, 4394.40 W/ K~ck ~ 0 6000 > 6~oo I-- 6200 I v 6500 580O 5900 6000 6100 6200 6300 6400 6500 66OO 67OO ~Tie on - 58.78 Inc, 104-00.00 Md, 6128.14 Tvd, 0.00 Vs f Point 4 5 = 2K-21bhs T.D. & End of Drop/Turn - 89.59 Inc, 12707.31 Md, 6195.00 Tvd, 2119.72 Vs 2K-21 i i i i I I i I I t I I i i i I I I I I I I I II I II I t I I I I I I I I I i i I I I I I I O0 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 Vertical Section (feel) -> Azimuth 280.32 wHh reference 6270.94 S, 4394.40 W from 2K-21 Company: Well: Calculation Method: Vertical Sect. Plane: Vertical Sect. Plane: Measured Depth from: el'rue Vertical Depth: Proposal Calculations Coordinates provided in' TRUE and GRID relative to Wellhead and ALASKA STATE PLAN ARC() Alaska~ Inc. 2K-21 Minimum Curvature 280.320 TRUE 280.310 GRID RKB Sea level Rig: Field: Mag. Declination: Grid Correction: Total Correction: RKB Height: Nabors 3s/CTU #4 Prudhoe Bay~ Alaska 27.090 0.010 27.080 0 Coords. - GRID Coords. - TRUE N(+)/S(-) FA+)/W(-) Lat. (Y) -6270.94 -4394.40 -6286.38 -4406.54 -6287.72 -4407.60 -6304.95 -4421.19 -6322.91 -4435.39 -6341.48 -4450.10 -6360.52 -4465.19 -6379.87 -4480.55 -6399.40 -4496.07 -6399.79 -4496.39 -6418.27 -4512.45 -6435.63 -4530.43 -6451.32 -4549.87 ~6465.24 -4570.63 -6477.26 -4592.54 -6487.30 -4615.42 -6495.27 -4639.11 -6501.12 -4663.40 Coords.- ASP n(+)/S(-) E(+)/W(-) Lat.(Y) Dep.(X) 5931765.01 493914.23 5931749.57 493902.10 5931 493901.04 5931731.00 493887.45 5931713.03 493873.24 5931694.46 493858.54 5931675.42 493843.46 5931656.06 493828.09 5931636.54 493812.58 5931636.15 493812.27 5931617.66 493796.21 5931600.30 493778.23 5931584.60 493758.79 5931570.68 493738.04 5931558.65 493716.13 5931548.61 493693.25 5931540.64 493669.56 5931534.78 493645.27 -6504.79 -4688.12 5931531.11 -6506.27 -4713.07 5931529.63 -6506.07 -4728.64 5931529.83 -6505.53 -4738.05 5931530.36 -6502.61 -4762.87 5931533.27 -6501.95 -4766.80 5931533.93 -6498.26 -4787.49 5931537.62 -6493.77 -4812.08 5931542.1 -6489.16 -4836.66 5931546.72 -6484.43 -4861.21 -6479.59 -4885.73 -6474.64 -4910.24 -6469.57 -4934.72 -6464.39 -4959.17 -6459.10 -4983.61 -6453.69 -5008.01 -6448.16 -5032.40 593 551.44 593 593 593 566.28 593 571.46 593 576,75 593 582.16 593 587.68 N(+)/S(-) FA+)/W(-) Lat.(Y) -6269.41 -4395.32 -6284.85 -4407.45 -6286.19 -4408.51 -6303.42 -4422.10 -6321.38 -4436.30 -6339.96 -4451.00 -6358.99 -4466.09 -6378.35 -4481.45 -6397.88 -4496.97 -6398.27 -4497.28 -6416.76 -4513.34 -6434.12 -4531.31 -6449.82 -4550.75 -6463.74 -4571.51 -6475.76 -4593.42 -6485.80 -4616.30 -6493.78 -4639.98 -6499.63 -4664.28 493620.55 -6503.31 -4689.00 493595.60 -6504.79 -4713.95 493580.03 -6504.59 -4729.51 493570.62 -6504.06 -4738.93 493545.80 -6501.14 -4763.75 493541.87 -6500.48 -4767.67 -6496.80 -4788.37 -6492.31 -4812.96 493472.01 -6487.70 -4837.53 493447.46 -6482.98 -4862.08 493422.93 -6478.15 -4886.61 493398.43 -6473.20 -4911.12 493373.95 -6468.13 -4935.60 493349.49 -6462.96 -4960.06 493325.{)6 -6457.66 -4984.49 493300.65 -6452.26 -5008.90 493276.27 -6446.74 -5033.28 Job No: AFE No: BHI Rep: Job Start Date: Job End Date: DLS (°/100 ft): 0 100.00 Comments Tie in Point Kick off Point 3 .I 4: 2K-21bhs 5 Meas. incl. TRUE GRID Subsea Coords. - TRUE Coords. - ASP Coords. - GRID Dogleg Tod Face Ve~ical Build Turn Depth Angle Azi. Azi. TVD N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) Section Commen~ (deg) {deg) (deli) (~) Lat. (Y) Dep. (X) Lat. (Y) Dep. (X) Lat. (Y) Dep. (X) (°/100't) /from TIP) (°/100ft) (°/10Oft) l1175.00 89.76 283.17 283.16 6186.23 -6442.52 -5056.75 5931593.31 493251.91 -6441.11 -5057.64 1.07' 90.00 620.92 -0.04 1.08 11200.00 89.76 283.43 283.42 6186.33 -6436.77 -5081.08 5931599.06 493227.58 -6435.36 -5081.97 1.07 90.00 645.89 0.~) 1.04 ,=. 11225.00 89.76 283.70 283.69 6186.44 -6430.91 -5105.38 5931604.92 493203.27 -6429.50 -5106.27 1.07 90.00 670.85 0.130 1.08 11250.00 89.75 283.97 283.96 6186.55 -6424.93 -5129.66 5931610.89 493179.00 -6423.53 -5130.55 1.07 90.00 695.80 -0.04 1.08 11275.00 89.75 284.23 284.22 6186.65 -6418.84 -5153.90 5931616.98 493154.75 -6417.44 -5154.79 1.07 90.00 720.74 0.00 1.(/4 11300.00 89.75 284.50 284.49 6186.76 -6412.64 -5178.12 5931623.17 493130.53 -6411.24 -5179.01 1.07 90.00 745.68 0.00 1.08 11325.00 89.74 284.77 284.76 6186.88 -6406.32 -5202.31 5931629.49 493106.34 -6404.93 -5203.20 1.07 90.00 770.61 -0.04 1.08 11350.00 89.74 285.04 285.03 6186.99 -6399.89 -5226.47 5931635.91 493082.18 -6398.50 -5227.36 1.07 90.00 795.53 0.(~ 1.08~ 11375.00 89.74 285.30 285.29 6187.10 -6393.35 -5250.60 5931642.45 493058.05 -6391.96 -5251.49 1.07 90.00 820.44 0.(~ 1.04 11400.00 89.74' 285.57 285.56 6187.22' -6386.70 -5274.70 5931649.10 493033.95 -6385.32 -5275.59 i.07 90.00 845.34 0.00 1.08 11425.00 89.73 285.84 285.83 6187.33 -6379.93 -5298.76 5931655.86 493009.89 -6378.55 -5299.66 1.07 90.00, 870.23 -0.04 1.08 11450.00 89.73 286.1 I 286. l0 6187.45 -6373.05 -5322.80 5931662.74 492985.85 -6371.68 -5323.69 1.07 90.00 895. I I 0.00 1.08 11475.00 89.73 286.37 286.36 6187.57 -6366.06 -5346.80 5931669.73 492961.85 -6364.69 -5347.70 !.07 90.00 919.97 0.00 1.04 Il500.00 89.72 286.64 286.63 6187.69 -6358.95 -5370.77 5931676.82 492937.88 -6357.59 -5371.67 1.07 90.00 944.83 -0.04 1.08 il525.00 89.72 286.9 286.90 6187.81 -6351.74 -5394.70 5931684.04 492913.94 -6350.38 -5395.61 1.07 90.00 969.67 0.00 1.08 11550.00 89.72 287.18 287.17 6187.93 -6344.41 -5418.61 5931691.36 492890.04 -6343.06 -5419.51 1.07 90.00 994.50 0.00 1.08 11575.00 89.71 287.44 287.43' 6188.06 -6336.97 -5442.47 5931698.79 492866.17 -6335.62 -5443.38 1.07 90.00 1019.31 -0.04 11600.00 89.71 287.7 287.70 6188.18 -6329.42 -5466.31 5931706.34 492842.33 -6328.08 -5467.21 1.07 90.00 1044.1 0.00 1.08 11625.00 89.71 287.98 287.97 6188.31 -6321.76 -5490.10 5931714.00 492818.54 -6320.42 -5491.01 1.07 90.00 1068.89 0.00 1.08 !!650.00 89.71 288.24 288.23 6188.43 -6313.99 -5513.86 5931721.76, 492794.77 -6312.65 -5514.77 !.07 90.00 1093.66 0.00 1.04 11675.00 89.70 288.51 288.50 6188.56 -6306.11 -5537.59 5931729.64 492771.05 -6304.78 -5538.50 1.07 90.00 1118.4 -0.04 1.08 11700.00 89.70 288.78 288.77 6188.69 -6298.12 -5561.28 5931737.63 492747.36 -6296.79 -5562.19 1.07 90.00 1143.15 0.00 1.08 11725.00 89.70 289.05 289.04 6188.83 -6290.02 -5584.93 5931745.73 492723.71 -6288.69 -5585.84 1.07 90.00 il67.87 0.00 1.08 11750.00 89.69 289.31 289.30 6188.96 -6281.80 -5608.54 5931753.94 492700.09 -6280.48 -5609.45 1.07 90.00 1192.57 -0.04 1.04 11775.00 89.69 289.58 289.57 6189.09 -6273.48 -5632.11 5931762.25 492676.52 -6272.16 -5633.03 1.07 90.00 1217.25 0.00, 1.08 Ii800.00 89.69 289.85 289.84 6189.23 -6265.05 -5655.65 5931770.68 492652.98 -6263.73 -5656.56 1.07' 90.00 1241.92 0.001 1.08 11825.00 89.68 290.12 290.11 6189.37 -6256.50 -5679.14 5931779.22 492629.49 -6255.19 -5680.06 1.07 90.00 1266.56 -0.04 i.08 11850.00 89.68 290.38 290.37 6189.51 -6247.85 -5702.59 5931787.87 492606.(13 -6246.54 -5703.51 1.07 90.00 1291.19 0.00 1.04 11875.00 89.68 290.65 290.64 6189.65 -6239.09 -5726.01 5931796.63 492582.62 -6237.79 -5726.93 1.07 90.00 1315.79 0.00 1.08 11900.00 89.68 290.92 290.9 6189.79 -6230.22 -5749.38 5931805.50 492559.24 -6228.92 -5750.30 1.07 90.00 1340.37 0.00 1.08 11925.00 89.67 291.19 291.18 6189.93 '-6221.23 .-5772.71 5931814.47 492535.9 -6219.94 -5773.64 1.07 90.00 1364.94 -0.{)4 1.08 11950.00 89.67 291.45 291.44 6190.07 -6212.15 -5796.00 5931823.56 492512.62 -6210.86 -5796.93 1.07 90.00 1389.48: 0.00 i.04 11975.00 89.67 291.72 291.71 6190.22 -6202.95 -5819.25 5931832.75 492489.37 -6201.66 -5820.17 1.07 90.00 1413.99 0.00 1.08 12000.00! 89.66 291.99 291.98 6190.36 -6193.64 -5842.45 5931842.05 492466.17 -6192.36 -5843.38 1.07 90.00 1438.49 -0.04 1.08 12025.00 89.66 292.25 292.24 6190.51 -6184.23 -5865.61 5931851.46 492443.01 -6182.95 -5866.54 1.07 90.00 1462.96 0.(~ 1.04 12050.00 89.66 292.52 292.51, 6190.66 -6174.71 -5888.73 5931860.98 492419.89 -6173.44 -5889.66 1.07 90.00 1487.41 0.~) 1.08 12075.00 89.66 292.79 292.78 6190.81 -6165.08 -5911.80 5931870.6 492396.82 -6163.81 -5912.73 1.07 90.00 1511.83 0.00 1.08 12100.00 89.65 293.06 293.05 6190.96 -6155.34 -5934.82 5931880.34 492373.79 -6154.08 -5935.76 i.07 90.00 , 1536.22 -0.04 1.08 12125.00 89.65 293.32 293.31 6191.11 -6145.50 -5957.80 5931890.18 492350.81 -6144.24 -5958.74 1.07 90.00 1560.60 0.00 1.04 12150.00 89.65 293.59 293.58 6191.26 -6135.55 -5980.73 5931900.13 492327.87 -6134.29 -5981.67 1.07 90.00 1584.94 0.~) 1.08 12175.00 89.64 293.86' 293.85 6191.42 -6125.49 -6003.62 5931910.18 492304.98 -6124.23 -6004.56 1.07 90.00 1609.26 -0.04 1.08 12200.00 89.64 294.13 294.12 6191.57 -6115.32 -6026.46 5931920.34 492282.14 -6114.07 ~6027.40 1.07 90.00 1633.55 0.00 1.08 12225.00 89.64 294.39 294.38 6191.73 -6105.05 -6049.25 5931930.61 492259.35 -6103.80 -6050.20 1.07 90.00, 1657.81 0.¢~ 1.04 12250.00 89.64 294.66 294.65 6191.89 -6094.67 -6072.00 5931940.98 492236.60 -6093.43 -6072.94 1.07 90.00 1682.05 0.00 1.08 12275.00 89.63 294.93 294.92 6192.05 -6~84.19 -6094.69 5931951.46 492213.91 -6082.95 -6095.64 1.07 90.00! 1706.25 -0.04 1.08 12300.00 89.63 295.20 295.19 6192.21 -6073.60 -6117.34 5931962.05 492191.26 -6072.36 -6118.29 1.07 90.00 1730.43 0.00 1.08 12325.00 89.63 295.46 295.45 6192.37 -6062.90 -6139.93 5931972.74 492168.66 -6061.67 -6140.88 1.07 90.00 1754.57 0.00 1.04 12350.00 89.62 295.73 295.72 6192.53 -6052.10 -6162.48 5931983.54 492146.11 -6050.88 -6163.43 1.07 90.00 1778.69 -0.04 1.08 12375.00 89.62 296.00 295.99 6192.70 -6041.20 -6184.97 5931994.44 492123.62 -6039.97 -6185.93 1.07 90.(}0 1802.77 0.00 i.08 12400.00 89.62 296.26 296.25 6192.87 -6030.19 -6207.42 5932005.45 492101.17 -6028.97 -6208.38 !.07 90.00 1826.83 0.00 1.04 .l . STATE OF ALASKA t A,zASKA OIL AND GAS CONSERVATION L~__~.,MISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of R~J[lueJ ,t: Abandon X Suspend _ Operation Shutdown __ Re-enter suspended well _ Alter casing Repair well _ Plugging Time extension Stimulate _ ~ 5. Type of Well: ~. Datum elevation (DF or KB) O~-~¢'~-torperu Change app~ved program Pull tubing- Variance _ P~-rforate _ Other i2. Name of Development X ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 269' FNL, 94' FEL, Sec. 11, T10N, RSE, UM At top of productive interval 1240' FNL, 809' FVVL, Sec. 14, T10N, RSE, UM At effective depth At total depth 1519' FNL, 581' FWL, Sec. 14, T10N, RSE, UM Exploratory _ Stratigraphic _ Service -- 154' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 2K-21 9. Permit number 90-4 10. APl number 50-103-20123 11. Field/Pool Kuparuk River 12. Present well condition summary Total Depth: measured true vertical 10800 feet 6502 feet Plugs (measured) None feet Effective depth: measured true vertical 10670 feet Junk (measured) None 6428 feet Casing Length Structural Conductor 80' Surface 3884' Intermediate Production 10725; Liner Size Cemented 16" 170 sx AS II 9.625" 850 sx AS III & 400 sx Class G 7" 400 sx Class G Measured depth 115' 3919' 10756' True vertical depth 115' 2923' 6477' Perforation depth: measured 10120'-10122', 10368'-10378', 10432'-10452', 10486'-10526' true vertical 6138'-6139', 6266'-6271 ', 6299'-6309', 6327'-6349' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 10240' Packers and SSSV (type and measured depth) Baker 'HB' Pkr @ 10001' & 10189' MD, Camco TRDP-1A-ENC SSSV @ 1810' MD 13. Attachments Description summary of proposal X Detailed operation program __ BOP sketch X 14. Estimated date for commencing operation September 1998 Oil X 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby certify that the foreg~in~is true a~orrect to the best of my knowledge. Signed k~_,,,,')~-,_~,~'' ~',¢,'"/'~~-~ Title Area Drilling Engineer / ' - __~2'~,.--- FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so'representative may witness Plug integrity _ BOP Test _ Location clearance __ Mechanical Integrity Test_ Subsequent form require 10-__ Original Signed By Approved by the order of the Commission David W. Johnston Form 10-403 Rev 06/15/88 15. Status of well classification as: Gas _ Suspended_ Date Commissioner IApprov_aLN.q. __ __ SUBMIT IN TRIPLICATE RECEIVED Alaska Oil & Gas Cons. C0mr isst0r Anchorage · WELL PERMIT CHECKLIST COMPANY FIELD & POOL INIT CLASS ~)~_~z-/ ~/'z::~., 7 WELL NAME ,~,,~'~. 2,'/~' --.2_/,,~ PROGRAM: exp [] dev'~ redrll~serv [] wellbore seg[I ann. disposal para req[I GEOLAREA _,:~',:~ UNIT# /]/~'~ ON/OFF SHORE ~ ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING APPR DATE 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~5'"O OO psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. N N N N N N N N N N N N N ~ N N N N N C N ~ N (~N ~N ~)N GEOLOGY Permit can be issued w/o hydrogen sulfide measures ..... Y '_ Data presented on potential overpressure zones ....... ~,~, ,/~, Seismic analysis of shallow gas zones ............. Seabed condition survey (if off-shore) ............. Con, tact.nam, e/phon,e .for weekly progress reports ....... lexplora~ory only] 30. 31. 32. 33. 34. ANNULAR DISPOSAL 35. APPR DATE With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: JDH RNC co Comments/Instructions: M:chel;,list rev 05/29/98 dlf:C:\msoffice\wordian\diana\checklist 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. Tape Subfile 1 is type: LIS **** REEL HEADER MWD 99/ 7/26 BHI 01 LIS Customer Format Tape . **'' TAPE HEADER MWD 99/ 7/26 100860 01 1 3/4" NaviGarnma, Gamma Ray data LIS COMMENT RECORD(s): ~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~ ___ !! !! ! ! ! ! ! ! ! ! ! !! !! ! ! Remark File Version 1.000 ! ! ! ! ! ! ! ! ! !! ! ! ! ! ! ! !! Extract File: Header.las ~Version Information VERS. 1.20: WRAP. NO: ~Well Information Block #MNEM.UNIT Data Type STRT STOP oiEP NULL COMP WELL ELD LOC CNTY STAT SRVC TOOL REF DATE API CWLS log ASCii Standard -~RSiON 1.20 One line per frame Information 10250.0000: Starting Depth 12600.0000: Ending Depth 0.S000: Level Spacing -999.2500: ~sent ~,~ ~, tv. ARCO ' ' ' . WELL: 2k-2iA YieLD: ~ ..... -'~ 9iver Unit LOCATION: 269' FNL COUNTY: North Slope STATE: Alaska SERVICE COMP~LNY: Baker Hughes INTEQ TOOL NAME & TYPE: 1 3/4" NaviGamma - Gamma Ray JOB REFERENCE: 100860 LOG DATE: 23 Sop 98 API NUMBER: 501032012301 ~Parameter Information Block #HNEM.UNiT Value Description FL 94' FEL : Field Location SECT. ii : Section TO~,~.N i0N : Township ~%NG. 8E : Range PDAT. M.S.L. : Permanent Datum EPD .M 154' : Elevation Of Perm. Datum LMF ~ : Log ~======= From FAPD. F 154 : Feet ,~c:ove Perm. Datum DMF . KB : Drilling Measured From EKB .F 154' : Elevation Of Kelly Bushing EDF .F N/A : Elevation Of Derrick Floor EGL ........... F N/A : ~=,,~ ~=~'~ Ground Level c~c? ....... v in"~3,~.= : Casing Depth OSi . DiRECTiONAL : Other Services Line 1 -Remarks (1) Ail depths are Measured Depths (MD) unless otherwise noted. (2) Ail depths are Bit Depths unless otherwise noted. (3) Ail Gamma Ray data (GRAX) presented is realtime data. (4) Well 2K-21A is represented by runs 9, 10, 11 and 12 which are all Directional with Gamma Ray. ('5) Well 2K-21A was initially kicked off @ 10423' MD (6141' TVD), from the wellbore originally drilled for Well 2K-21. (6) The interval from 12548' MD (6215' TVD) to 12570' MD (6215' TVD) was not logged due to the sensor to bit offset. (7) Well 2K-21A was drilled to 12570' MD (6215' TVD) on Run 12. A post run tie-in resulted in a 7' depth adjustment which resulted in a TD of 12577' MD (6215' TVD). (8) A Gamma Ray log of the original Well 2K-21 provided by ARCO Alaska, Inc. was used to tie-in with 2K-21A. The Gamma Ray-log preceding the KOP of Well 2K-21A was used for depth shifting, with the base log as 2K-21. 19) A Magnetic Declination correction of 27.09 degrees has been applied to the Directional Surveys. ~Mnemonics -> GRAX = Gamma Ray MWD-A?I [MIND] (MWD-API units) -> ROPS = Rate of Penetration (ft/hr) -> TVD = True Vertical Depth (feet) ~Sensor Offsets RUN GAMMA DIRECTION 9 15.85' 23.40' 10 15.67' 23.22' 11 15.83' 23.38' 12 15.30' 22.85' Tape Subfiie: i 71 records... Minimum record length: Maximum record length: Tape Subfile 2 is type: LIS 14 bytes 132 bytes FILE HEADER MWD .001 1024 INFORMATION TABLE: CONS MNEM VALU ----_ LCC 150 CN ARCO Alaska, Inc. WN 2K-21A FN Prudhoe Bay Unit COUN North Slope STAT Alaska LIS COMMENT RECORD(s): ~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~ !! ! ! ! ! !! ! ! ! !! ! ! ! ! !! Remark File Version 1.000 1. The data presented here has been edited from the field raw data. 2. The data has been depth shifted to match the PDC supplied by ARCO Alaska, Inc. 3. The PDC used is the Sperry Sun's open hole Gamma Ray data, dated January 1990. INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP i ~9R GgPIX 0.0 2 ROP ROPS 0.0 FORMAT RECORD (TYPE# 64 Entry Type 1) Size 1 Data record type is: Entry Type 2) Size 1 Datum Specification Block Entry Type 3) Size 2 Datum Frame Size is: Entry Type 4) Size 1 Logging direction is down Entry Type 5) Size 1 Repcode 66) 0 Repcode 66) Type is: 0 Repcode 79) 12 bytes Repcode( 66) (value= 255) Repcode( 66) Optical Log Depth Scale Units: Feet Entry Type 8) Size 4 Repcode( 68) Frame spacing: 0.500000 Entry Type 9) Size 4 Repcode(65) Frame spacing units: [F ] fndun c [F ] 1.00000000 3 Entry Type( 11) Size( 4) Repcode( 68) Number of frames per record is: 84 Entry Type( 13) Size( 1) Repcode( 66) One depth per frame (value= 0) Entry Type(16) Size( 1) Repcode(66) Danum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 1 1 1 1 1 0 0 1 1 0 1 0 1 0 0 1 Rep Code Count Bytes 68 2 8 Sum: 2 8 fndun a [F ] 1.00000000 [] FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size API API API API Log Crv Crv Length Typ Typ Cls Mod 1 GR MWD 68 1 API 4 2 ROP ?~D 68 i 4 4 99 995 99 1 4 99 995 99 i DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 55 Tape File Start Depth = 10290.000000 Tape File End Depth = 12575.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet FILE TRAILER LIS representation code decoding summary: Rep Code: 66 1 datum Rep Code: 68 13717 datums Rep Code: 79 2 datums Tape Subfile: 2 62 records... Minimum record length: 54 bytes Maximum record length: 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER NWD .001 1024 INFORMATION TABLE: CONS MNEM VALU LCC 150 CN ARCO Alaska, Inc. WN 2K-21A FN Prudhoe Bay Unit COUN North Slope STAT Alaska LIS COMMENT RECORD(s): ~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~~23456789~ !!!!!! !!!!!!!!!!!!! Remark File Version 1.000 1. The data presented here is the unedited field raw data. INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP i G~< Gk~< 0.0 =o ROPS ROPS 0.0 FORMAT RECORD (TYPE~ 64 Entry Type 1) Size 1 Data record type is: Entry Type 2) Size 1 Datum Specification Block Entry Type 3) Size 2 Datum Frame Size is: Entry Type 4) Size 1 Logging direction is down Entry Type 5) Size 1 Repcode(66) 0 Repcode( 66) Type is: 0 Repcode(79) 12 bytes Repcode( 66) (value= 255) Repcode(66) Optical Log Depth Scale Units: Feet Entry Type 8) Size 4 Repcode(68) Frame spacing: 0.500000 Entry Type 9) Size( 4 Repcode(65) Frame spacing units: [F ] fndun c [F ] 1.00000000 3 Entry Type( 11) Size( 4) Repcode( 68) Number of frames per record is: 84 Entry Type( 13) Size( 1) Repcode(66) One depth per frame (value= 0) Entry Type( 16) Size( 1) Repcode( 66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: · t 2 3 4 5 1 1 1 1 1 Rep Code Count 68 2 Sum: 2 fndun a IF ] FRAME SPACE = ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: 7 8 9 10 11 12 13 14 15 16 0 1 1 0 1 0 1 0 0 1 Bytes 8 8 8 1.00000000 3 0. 500 * F . Name Tool Code Samples Units Size i G~d< MT'~D 68 i 4 2 ROPS ~,f.,~ D 68 i 4 DATA RECORD (TYPE# 0) Total Data Records: 55 1014 BYTES Tape File Start Depth = 10290.000000 Tape File End Depth = 12575.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER LIS representation code decoding summary: Rep Code: 66 1 datum Rep Code: 68 13717 datums Rep Code: 79 2 datums Tape Subfile: 3 6,2 records... Minimum record length: 54 bytes Maximum record length: 1014 bytes [] Tape Subfile 4 is type: LIS **** TAPE TRAILER **** MWD 99/ 7/26 100860 01 API API API API Log Crv Crv Length Typ T~vp Cls Mod 4 99 995 99 i 4 99 995 99 i **** REEL TRAILER **** MWD 99/ 7/26 BHI 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Mon 26 JLY 99 2:41p Elapsed execution time = 1.48 seconds. SYSTEM RETURN CODE = 0 Tape Tape Subfile 1 Subfile 2 is type: is t !;pe: LIS LIS 10290.0000 10290.5000 10300.0000 10400.0000 10500.0000 10600.0000 10700.0000 10800.0000 10900.0000 11000.0000 11100 0000 11200 0000 11300 0000 11400 0000 11500 0000 11600 0000 11700 0000 11800 0000 11900.0000 12000.0000 12100 0000 12200 0000 12300 0000 12400 0000 12500 0000 12575 0000 -999.2500 -999.2500 -999 2500 79 5600 164 3000, 57 6990 66 6500 77 5000 52 7000 83 9360 78 6680 66 6500 59 9750 80.6000 99.2000 122.4500 52.7000 63.2350 66.3540 54.6390 93.2330 127.0000 106.9500 124.7750 55.3980 -999.2500 Tape Tape Tape Tape Tape Subfi File Start Depth = File End Depth = File Level Spacing = File Depth Units = le 3 is type: LIS DEPTH 10290 10290 10300 10400 10500 10600 10700. 10800. 10900. 11000. 11100. 11200. 11300. 11400. 11500. 11600. 11700. 11800 11900 12000 12100 12200 12300 12400 12500 12575 0000 5000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 GRAX -999. 2500 -999. 2500 -999.2500 76.5000 164.3000 57.6990 66.6500 77.5000 52.7000 83 9360 78 6680 66 6500 59 9750 80 6000 99 2000 122 4500 52 7OOO 63 2350 66 3540 54 6390 93 2330 127 0000 106 9500 124 7750 55.3980 -999.2500 -999 2500 -999 2500 -999 2500 -999 2500 73 4000 62 0000 65 4000 83 7000 53 4710 52 1000 42 8000 54.8790 59.0910 49.7560 29.3840 32.2530 61.0000 80.0000 87.8O00 88.7140 -999.2500 69.2000 49.3000 37.1000 27.2140 -999.2500 10290.000000 12575.000000 0.500000 Feet ROPS -999.2500 -999.2500 -999.2500 -999.2500 73.4000 62.0000 65.4000 83.7000 53.4710 52.1000 42.8000 54.8790 59.0910 49.7560 29.3840 32.2530 61.0000 80.0000 87.8000 88.7140 -999.2500 69.2000 49.3000 37.1000 27.2140 -999.2500 Tape File Start Depth = Tape File End Depth = Tape File Level Spacing = Tape File Depth Units = 10290.000000 12575.000000 0.500000 Feet
