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184-121
RECEIVED • NOV 102016 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT An209_ la.Well Status: Oil❑ Gas❑ SPLUG❑ Other ❑ Abandoned 111, Suspended❑ 1b.Well Class: 20AAC 25.105 20aac 25.110 Development❑ Exploratory❑ GINJ ❑ WINJ❑ WAGE WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test❑ 2.Operator Name: 6.Date Comp.,Susp.,or 14.Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 10/14/2016 184-121/316-337/ • 3.Address: 7. Date Spudded: 15.API Number: P.O. Box 100360 Anchorage,AK 99510-0360 8/3/1984 50-029-21153-00 • 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 487'FSL,44'FEL,Sec 31,T11N, R9E, UM 8/8/1984 KRU 2G-02 - Top of Productive Interval: 9. Ref Elevations: KB:139 17. Field/Pool(s): 1193'FSL,884'FEL,Sec 31,T11N R9E, UM GL: BF: Kupurak River Field/Kuparuk Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18.Property Designation: 1350'FSL, 1068'FEL,Sec 31,T11N, R9E, UM Surface ADL 25656 . 4b.Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 508650 y- 5944074 Zone- 4 6675/6258 2582 TPI: x- 507807 y- 5944780 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 507623 y- 5944936 Zone- 4 N/A 1465/1465 5. Directional or Inclination Survey: Yes ❑ (attached) No 0 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) I 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 N/A ,i70 APR 2 5 201% 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH ND AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16 62.5 H-40 38 116 38 116 24 200 sx Cold Set II 9 5/8 36 J-55 37 2719 37 2719 12.25 770 sx Permafrost E 370sx Permafrost C 7 26 J-55 1852 6631 1852 6231 8.5 350 sx Class G,250 sx Permafrost C 24.Open to production or injection? Yes ❑ No 0 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom;Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3.5 6268 6241/5975 Perforations Plugged: 0,AnliOONe-19 6376-6396 MD 6067-6081 ND -= ,1, 26.ACID,FRACTURE,CEMENT SQUEEZE,ETC. 6414-6458 MD 6093-6121 TVD Was hydraulic fracturing used during completion? Yes❑ No 0 ./°//t{ 6V) Per 20 AAC 25.283(i)(2)attach electronic and printed information '.'''''2.'-:''a, DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED L Surface to 2020'SLM 163 bbls 15.7 Arctic Set 1 cement 2020'SLM 4740'rkb 70 bbls 15.8 ppg on top of WRP 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period .► Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate Form 10-407 Revised 11 015 l/- 47a 4/ CONTINUED ON PAGE 2 Submit ORIGINIAL only ill-3 411251/ - ,lam 7j /'/7 RBDMS L4-- NOV 1 6 2016 • • 28.CORE DATA Conventional Core(s): Yes ❑ No 2 Sidewall Cores: Yes ❑ No 0 If Yes, list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips, photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD ND Well tested? Yes ❑ No 0 Permafrost-Top Surface Surface If yes, list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1465 1465 Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval N/A N/A information, including reports,per 20 AAC 25.071. Formation at total depth: N/A N/A 31. List of Attachments: Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report.production or well test results.Der 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jill Simek @ 263,.43?4f/3t Email: Jill.Simek@cop.com Printed Name: G.L.Alvord Title: Alaska Drilling Manager / i(2Signature: 4_6_0kPhone: 265-6120 Date: ,t(I ''(6 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 1b: 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 2G-02 Plug and Abandonment October 18, 2016 ConocoPhillips Alaska, Inc. performed Plug and Abandonment operations on 2G-02, commencing operations on September 26, 2016 and completing the Plug and Abandonment on October 17, 2016. Operations involved placing 70 bbls of Class "G" cement on top of the existing 5-1/2"plug at 4,740' KB. Top of Cement (TOC) was tagged at 2,020' SL and a passing MIT-T obtained. 163 bbls of ArcticSet 1 cement was then placed from TOC of Plug#1 to near-surface. The well was then excavated and wellhead and cellar removed. TOC of Plug#2 was determined to be at 21'6". A 2 bbl top job was performed to bring cement to surface. The State Inspector determined that cement was in good condition and the well was capped and excavation backfilled. Pictures below show cement to surface in all annuli, marker plate installed, and final site condition after backfill. The field Well Service Report is attached. q a �F,g s;-� �� $ �, M a Y � u • • IIIlulliJiI ttns u u 4'7''.;!''':::','''';;:•z','':;.:,lt,•.!:z;*'°:.;:;:'''''' *'''"'' ''.',, -,k,:;,'P:''''',:;:':°:;:°;'i':'4;','A,, 1,',,''''''.4 s � dam '.. 'a z '-,-,e,".'••:-., ems '!",,;,..,:0~-.... Ash,•. * • � z •' 4 �' std ,�, �,r� ° '-., w '+x �. ;.. ,.. q'.'''.1 a .'. g ... f , r , #� ito �� $ \�� � �� of � '�. • r f ,„, ,, "Copyright 2• proviiatoto �,� fa„is permission to copy for i45• -N. ,a€ arty other purpose or by fiery• . ''` prohibited without the azpr.` ' : r a , ' ConocoPhillipsAlaska,lnc F c b ,_.7.11.7'.'t!:-:—''''''''',7'.',..' — '` i•, ay;a •,,,„, _ re s t y. ;:+�' " . fl" .- tea ,'.'�+ �L�y;' .� ,.�,. -..��?. 4;�' i£. • • EVENT_DATE EVENT_TEXT 9/26/2016 RIH AND PULL 7" WRP AT 2329' RKB. LAY IN 70 BBLS 15.8PPG UNISLURRY CEMENT ON TOP OF 5 1/2" WRP AT 4740'WITH ESTIMATED CEMENT TOP AT 2165'. LEFT WELL FREEZE PROTECTED. READY FOR S/L STATE WITNESSED TAG AND TEST IN 48 HRS (PLUG 1 OF 2 FOR 9/30/2016 TAGGED TOP OF CEMENT @ 2020' SLM (hard sticky bottom, no sample recovered) MIT CEMENT TO 1650 PSI, PASSED. STATE WITNESSED (JOHNNY HILL) READY FOR COIL CEMENT PLUG #2 TO SURFACE. LRS PUMP 4.3 BBLS TO PRESSURE UP TO 1650 PSI, AFTER 1ST 15 MIN., LRS LOST 100 PSI AFTER 2ND 15 MIN., LRS LOST 25 PSI, FOR A PASSING MIT WITNESSED BY STATE 10/5/2016 TAG CEMENT PLUG #1 AT 2030' CTMD, LAY IN 163 BBLS OF 15.7#ARCTIC SET 1 CEMENT FROM TAG TO SURFACE, CONTAMINATE DOWN TO 10' (TBG HANGER) USING POWER-VIS GEL,WASH ALL SURFACE LINES WITH CONTAMINATE AND CHASE WITH DIESEL, READY FOR LRS P/T AFTER 48 HOURS,JOB COMPLETE. 10/7/2016 P&A PREP - NO FLOW TEST(PASS), MITT(FAIL) Initial T/I/0 =Vac/Vac/Vac Opened needle valve on IA valve to release vac on surface casing. Let breath for 30 min. SI to monitor for BUR: 15 min =0/0/0 30 min =0/0/0 Rigged up triplex to tree cap for MITT. Initial FL @ 23.5' (1.8 bbl fill up) Pressured up to 1500 psi multiple times and would not hold test pressure. Observed several small drops come from down spout in conductor while attempting MITT. Bled tree to 0 psi and removed fluid from tree through the OA needle valve to bleed trailer (FL @8' 10")for future tee removal. Final T/I/O=0/0/0 10/8/2016 P&A PREP Initial T/I/0 = 3/3/3 Bled pressure to 0 psi in 15 sec (gas). Let breath for 4 hours. Rigged up boom truck to tree and removed from wellhead. Vac'ed out fluid from tubing. TOC= 34' (from top of well head). Installed tree cap to wellhead. Final T/I/O=0/0/0 10/10/2016 Sent email to AOGCC to witness "top off" with 15.7 PPG cement • • • 10/11/2016 Initial T/I/0= N/A P&A PREP; Removed shoring box (prior standing plate removal job), Vac'ed out hole, Continued excavation, Set sump, Set shoring box, Dug egress, Set stairs. Dug to ^'4-5' below tundra level. Total excavation depth is—12-13' deep. Final T/I/0= N/A 10/12/2016 P&A Initial T/I/0= N/A Welded Thread-O-Lets onto conductor, attached valve and drilled through to verify; no pressure,fluid or atmospheric hazards. Cut windows Repeated Thread-O-Let process on casing Cut windows Finished cutting casing and conductor 4' below original ground level. Removed wellhead with crane T-TOC is 21'6" Final T/I/0= N/A 10/13/2016 Initial T/I/0= N/A (SW) Chuck Sheve witnessed initial cement level and 2 BBL 15.7 PPG Arcticrete 1 cement surface casing fill up to surface. He took pictures of marker plate and wavied witness of welding plate. Final T/I/0= N/A 10/14/2016 Initial T/I/0= N/A P&A;Jose from GBR welded the marker plate on. Removed shoring box, sump& stairs. Began backfill Final T/I/0= N/A 10/17/2016 Took final P&A pictures of well buried and sent info to town engineer Jill Simek. KUP PROD 2G-02 ConocoPhillips 4; KUP Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(EKE) Act Otto(ftKB) crnou;atvatpr 500292115300 KUPARUK RIVER UNIT PROD 50.90 6,500.00 6,675.0 ... Comment N2S(ppm) Date Annotation End Date KB-Grd(ft) `Rig Release Date 2G-02,11/8/2016 3.40:32 PM SSSV:NONE 0 12/30/2012 Last WO: 4/13/2015 40.41 8/9/1984 Vemcal schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 6,364.0 10/13/2012 Rev Reason:P&A WELL pproven 10/31/2016 ILi 1 Casing Strings ✓t.A.,CONDUCTOR;44.4-116.0- Casing Description OD(in) ID(in) Top(ftKB) Set Depth(CAB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 44.4 116.0 116.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 9 5/8 8.921 44.4 2,719.4 2,719.4 36.00 J-55 BTC Cement;444 ftKB Casing Description OD(in) ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION-CUT 7 6.276 1,852.0 6,631.6 6,230.8 26.00 J-55 BTC 2015 WO Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CEMENTED CASING- 51/2 4.950 2,797.7 6,153.4 5,912.5 15.50 L-80 BTCM 2015 WO-5.5"x5" @6075 x 3.5" SURFACE;44.4-2,719.4-A Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/nt) Grade Top Connection TUBING-WO-2015 31/2 2.992 6,152.3 6,226.3 5,964.8 9.30 L-80 EUE 8rd Mod • Completion Details Cement;2,020.0 ftKB Nominal ID Retdeva5e Bridge Plug;4,740.0 Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 6,152.3 5,911.7 43.51 PACKER BAKER 85-40 F-1 PERMANENT PRODUCTION 3.990 PACKER 6,200.8 5,946.7 44.39 NIPPLE DS NIPPLE W/CA-2 PLUG INSTALLED 2,813 2 7/8 HT PAC drill pipe;4,792.0 6,218.6 5,959.3 44.78 OVERSHOT BAKER POORBOY OVERSHOT W/PACKOFF 3.610 Cement;5,380.0 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..l Sot Depth(TVD)(...Wt(Ib/fl) Grade Top Connection • • TUBING-ORIGINAL 31/2 2.992 6,220.0 6,267.9 5,994.0 9.30 L-80 EUE8RDMOD Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB)_Top Incl(°)... Item Des Com (in) 6,241.2 5,975.2 45.28 PACKER BAKER SAB-2 PERMANENT PACKER w/K22 ANCHOR 3.250 Production Casing Cement; ( SEALASSEMBLY 3,290.0 ftKB 1 6,257.9 5,987.0 45.65 NIPPLE CAMCO D NIPPLE w/2.75"NO GO PROFILE 2.750 6,267,0 5,993.3' 45.85 SOS 'BAKER SHEAR OUT SUB PINNED FOR 3500 PSI, 2.937 ELMD 6289'FROM SWS BHP OF 6/30/2005 III Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) V I Top(TVD) Top Incl Top(ftKB) (ftKB) Des Corn Run Date ID(in) 4,740.0 4,708.8 18.8.90 Retrievable COE 4743 "5/11/2015 Bridge Plug 4,782.0 4,748.5 19.30 27/8 HT PAC Cemented in-TOC 5360 inside °5/1/2015 2.151 drill pipe / t --_ 5,360.0 5,277.0 29.77 Cement TOC 2 7/8 x 5.5 5360' 5/1/2015 0.000 TOC 5.5"X 7"3280' 6,181.5 5,932.8 44.04 Junk Catcher Junk Catcher(10.3') 4/21/2015 CEMENTED CASING-2015 I - Wo-5.5°z 5°©6075 z 3.5-; EI 6,191.8 5,940.2 44.22 Sand Plug 9'Sand Plug 4/21/2015 2,797.7-8,153.4 3 'J ' PACKER;8,152.3 6,200.8 5,946.6 44.39 CA-2 Plug 2.812"CA-2 Plug '4/21/2015 I 311 I 6,220.0' 5,960.3 44.81 CUT TUBING CHEM CUT 3/22/2015 6,253.0 5,983.6 45.54 CATCHER CATCHER 3/14/2015 6,258.0 5,987.1 45.65 PLUG 2.75"CA-2 PLUG 10/14/2012 0.000 Junk Catcher;6,181.5 I�� Perforations&Slots Shot Send Plug;5,191.8 Dens CA-2 Plug;6,200.1 p Top(TVD) elm(ND) (shots/f NIPPLE;8,200.8, Top(ftKB) Bim(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 6,376.0 6,396.0 6,067.5 6,080.8 A-5,2G-02 9/16/1984 4.0 (PERF 90 deg.Phasing;4" of Sclumberger 16,414.0 6,458.0 6,092.6 6,121.1 A-4,2G-02 9)16/1984 4.0 (PERF 90 deg.Phasing;4" Sclumberger Cement Squeezes _ Top(TVD) Btm(TVD) T ) Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com ' 2,020.0 4,740.0 2,019.9 4,708.8 PLUG1 9/26/2016 70 bb(s Class"G"cement on top of 5-1/2"plug at CUT TUBING;6,220.0 '.. 4,740'KB.TOC tagged at 2,020 SLM OVERSHOT;8,218.8 i a 44.4 2,020.0 44.4 2,019.9 PLUG 2 10/5/2016 163 bbls ArcticSet 1 cement placed from 2,020'SLM to surface. 2 bbl"top job"performed. Notes:General&Safety End Date Annotation PACKER;6,241.2 4/5/2004 NOTE:LEAK PARTIALLY(2 BARRIERS)REPAIRED WITH SEALANT 10/19/2010 NOTE:View Schematic w/Alaska Schematic-9.0 CATCHER;6,253.0 9/24/2011 NOTE:LEAK IN 7"LOCATED AT 3988'RKB USING TECWEL LDL TOOL NIPPLE;6,257.9, 10/13/2016 NOTE:After cementing,the wellhead,casing,and conductor were cut off 4'below orig ground level PLUG;6,258.0 10/14/2016 NOTE:WELDED MARKER PLATE 10/14/2016 NOTE:FINAL P8A COMPLETED SOS;6,287.0 IPERF;8,378.0-8,396.0 IPERF;6,414.0-6,458.0-. PRODUCTION-CUT 2015 WO; do 1,852M-6,831.8 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 1 i01 i 7 II`� DATE: 9/30/2016 P. I. Supervisor FROM: Johnnie Hill SUBJECT: Plug Verification Petroleum Inspector KRU 2G-02 ConocoPhillips Alaska Inc. PTD 1841210 - September 30, 2016: I arrived out at location, met with the CPAI representative and went over the procedure. Witnessed tag of cement at 2020 ft. Next, Little Red Well Services rigged up to do a pressure test. The well was pressured up to 1650 psi; dropped to 1550 psi after the first 15 min and 1525 ' after 30 minutes. Summary: I witnessed a good tag on cement plug and passing pressure test— KRU 2G-02. - Attachments: none - %ARMED 1'i 0 t7, 201 2016-0930_Plug_Verification KRU 2G-02_jh.docx Page 1 of 1 + L OF 7 • \ I%%.,, THE STATE Alaska Oil and Gas 41 -1•s �, of LAsKA Conservation Commission A 333 West Seventh Avenue C GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 SY' Fax: 907.276.7542 www.aogcc.alaska.gov Jill Simek SEWED JAN 1 7 2017 Staff Well Integrity Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2G-02 Permit to Drill Number: 184-121 Sundry Number: 316-337 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 P. oerster Chair DATED this/CJ day of August, 2016. RBDMS W AUG 1 2 2016 • 0 STATE OF ALASKA 0 RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION JUN 1 7 2010 APPLICATION FOR SUNDRY APPROVALS Pers Flfig /1=. 20 AAC 25.280 AOG V 1.Type of Request: Abandon F Plug Perforations 1'. Fracture Stimulate E Repair Well E Operations Shutdown E Suspend E Perforate E Other Stimulate r Pull Tubing E Change Approved Program I- Plug for Red rill r Perforate New Pool[ Re-enter Susp Well E Alter Casing E Other: Plug&Abandon F 2.Operator Name: .4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory `" Development F 184-121 3.Address: 6.API Number: E P.O.Box 100360,Anchorage,Alaska 99510 Stratigraphic I- Service 50-029-21153-00 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 r' No FKRU 2G-02 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25656 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): 6,675' 6,258' 2329 2329 0 2329,4740,6192,6201, 6258 Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 16" 116' 116' Surface 2,682' 9 5/8 2,719' 2,719' Intermediate Production 4,780' 7" 6,632' 6,631' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 72k6376-6458,666 6067-6081,6093-6121 3.5 L-80 6,268' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-BAKER 85-40 F-1 PERMANENT PRODUCTION PACKER MD=6152 TVD=5912 12.Attachments: Proposal Summary El Wellbore schematic ID 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch D Exploratory E Stratigraphic E Development F Service r 14.Estimated Date for 7/15/2016 15.Well Status after proposed work: Commencing Operations: OIL r WINJ r WDSPL E Suspended 16.Verbal Approval: Date: GAS E WAG E GSTOR E SPLUG E Commission Representative: GINJ E Op Shutdown " Abandoned F 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Jill Simek Email Jill.Simekacop.com Printed Name Jill Simek@263-4131 Title Staff Well Integrity Engineer ,-if Signature 5--1/.4.- Phone 263-4131 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance It17- Other: 4 0 L2 L'C W t✓I t 5 5 1-1, 4 -e 5 at-if I C t of i n r y o c t d yr>° , z4- kvi vi.- i-,ce lid . Post Initial Injection MIT Req'd? Yes ❑ No ice' RBDMS V AU� 2 2��6 Spacing Exception Required? Yes ❑ No i Subsequent Form Required: /P — ft 7, 4>e Win' APPROVED BY Q //aa /� Approved by: f9S/tA444---- COMMISSIONER THE COMMISSION Date: D -L U'!4_j Submit orm and Form 10-403 Rev ed 11/2015 0 IAGOlerAti n is valid. monthsjrom the date of approval. Attachments in Duplicate • RErEWED • •Iry JUN 172016 ConocoPhillips Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 16 June 2016 Commissioner,State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby applies for an Application for Sundry Approval to plug and abandon Kuparuk Producer 2G-02(PTD#: 184-121). Well 2G-02 was drilled,completed,and fracture stimulated in 1984 as an A-Sand only single completion. The well was worked over in 1993 for tubing replacement and 1997 for packer and tubing replacement. In November 2003 the well failed a mechanical integrity test of the outer annulus,was taken off gas lift and a leak was detected near 32'RKB in the 9-5/8"surface casing. Between 2004 and 2005 attempts to repair the hole in the surface casing with Seal-Tite and cement were unsuccessful.The well remained on production without gas lift with an internal waiver. In June 2011,the well failed a mechanical integrity test of the inner annulus and was shut-in and secured with a plug in the tubing. Diagnostics identified leaks in the 7"production casing at 3988'RKB and between 5250'and 5500'RKB. The well remained shut-in until-a rig workover was scheduled for 2015. During the 2015 workover,drillpipe was inadvertently cemented in hole during the casing operation. After pumping cement to the backside of the 5-1/2" casing, a port collar was inadvertently opened allowing cement back inside the 5-1/2" casing which cemented the lower portion of the drillpipe in hole. The workover was deemed no longer economically feasible and the well was suspended. The well is currently suspended with 2 mechanical plus and approximately 800'of cement inside the 5-1/2" casing,drillpipe,and 5-1/2"x 7"annulus. Evaluations conducted indicate the wellbore and well location does not have any remaining utility for the Kuparuk River Unit. The remaining Kuparuk A resource is to be recovered from sidetrack drilling at offset location 2G-15. Per this procedure,a P&A will be performed to place a second cement plug from the Wireline Retrievable Plug at 2,329.4' RKB, across the 7" casing stub at 1,852.0' RKB, and top of cement brought to surface. Surface excavation for removal of wellhead and final P&A operations will follow. If you have any questions or require any further information,please contact me at 263-4131. Sincerely, Jill Simek Well Integrity Engineer CPAI Drilling and Wells • 4111/ ConocoPh i l l i ps 2G-02 P&A Permit to Drill #: 184-121 The objective of the proposed 2G-02 P&A is to place a cement plug from the Wireline Retrievable Plug at 2,329.4' KB, across the 7" casing stub at 1,852.0' KB, and top of cement brought to surface. Surface excavation for removal of wellhead and final P&A operations will follow. Proposed P&A: Schlumberger Coiled Tubing/Cementing: Objective: Plug #1 —Fill the wellbore with cement from the Retrievable Bridge Plug (WRP) at 2,329.4' KB to surface. Cement Volume Calculations: • Volume inside 7" casing from WRP to casing stub: (2329.4'-1,852.0') x 0.0382627 bbl/ft= 18.3 bbl • Volume inside the 9 5/8" casing to surface: (1,852.0'-0) x 0.0773102 bbl/ft= 143.2 bbl • Excess: 10 bbl • Total volume: 18.3 + 143.2 + 10 = 171.5 bbl 1. Ensure an approved sundry has been received from AOGCC. 2. Contact Schlumberger a week before the scheduled P&A date, to allow adequate time for pilot testing of the P&A cement design. (Lucas Skinner Fred Kitterman @ 659-6121 or 659-2434). The job is designed for 171.5 bbls of 15.7#ARCTICSET 1 (AS1) cement. 3. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 4. RU Coil Tubing Unit and Cementers. PT Surface Equipment as required. 5. Reference 5/20/2015 schematic for depth correlation. 6. RIH with coil tubing and tag 7"WRP at 2,329.4' KB. 7. Pump 10 bbls fresh water spacer 8. Pump 171.5 bbls of 15.7 ppg ARCTICSET* I (AS1) Cement 9. Pump 10 bbls fresh water spacer behind 10.With approximately 50' of cement out of the nozzle, begin to pull out of hole, laying in cement, taking 1 for 1 returns up the coil tubing backside. 11. Continue to take cement returns from coil tubing x casing annulus until good quality 15.7#AS1 cement is weighed and confirmed at surface. 12. Wash up surface equipment. RDMO. Rv- _ Little Red: 1. WOC 48 hrs. 2. RU LRS and PT Equipment. JS • ConocoPh i l l i ps 2G-02 P&A Permit to Drill #: 184-121 The objective of the proposed 2G-02 P&A is to pull the 7" Wireline Retrievable Plug (WRP) and place a cement plug from the 5-1/2" WRP, at 4,740' KB, to surface. Surface excavation for removal of wellhead and final P&A operations will follow. Proposed P&A: Slickline: Objective: Pull 7"WRP at 2,329.4' KB 1. Ensure an approved sundry has been received from AOGCC. 2. Inspect pad and work area for hazards. Complete pre-job safety meeting. RU Slickline unit and support equipment. PT lubricator and surface lines as required. 3. RIH and pull 7" WRP at 2,329.4' KB. 4. RDMO Schlumberger Coiled Tubing/Cementinq: Objective: Plug #1 —Fill the wellbore with cement from the Wireline Retrievable Bridge Plug (WRP)at 4,740' KB to approximately 2,330' KB. 1. Ensure an approved sundry has been received from AOGCC. 2. Contact Schlumberger a week before the scheduled P&A date, to allow adequate time for pilot testing of the P&A cement design. (Lucas Skinner Fred Kitterman @ 659-6121 or 659-2434). The job is designed for 69.1 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. RU Coil Tubing Unit and Cementers. PT Surface Equipment as required. 5. Reference 5/20/2015 schematic for depth correlation. 6. RIH with coil tubing and tag 5-1/2" WRP at 4,740' KB. 7. Pump 10 bbls fresh water spacer 8. Pump 69.1 bbls of 15.8 ppg Class "G" Cement 9. Pump 10 bbls fresh water spacer behind 10.With approximately 50' of cement out of the nozzle, begin to pull out of hole, laying in cement, taking 1 for 1 returns up the coil tubing backside. 11. Wash up surface equipment. RDMO. Slickline/ Little Red (or DHD): Objective: Tag TOC, MIT, DDT 1. WOC for 48 hr or until field blend UCA chart shows cement developed 1,500 psi compressive strength. JS • 2. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 3. RU SL and PT Equipment as required. 4. RIH and tag TOC @ approximately 2,330' KB. Record results and report tag depth to Well Integrity Engineer. 5. RU LRS and PT Surface Equipment as required. 6. Perform MIT to 1,500 psi. Record results. 7. Perform DDT. Record results. 8. Report issues & results to Well Integrity Engineer. 9. RDMO Schlumberger Coiled Tubing/Cementing: Objective: Plug #2—Fill the wellbore with cement from Plug #1 Top of Cement to surface. 1. Ensure an approved sundry has been received from AOGCC. 2. Contact Schlumberger a week before the scheduled P&A date, to allow adequate time for pilot testing of the P&A cement design. (Lucas Skinner Fred Kitterman @ 659-6121 or 659-2434). The job is designed for 163.5 bbls of 15.7#ARCTICSET 1 (AS1) cement. Note that cement volumes could change depending on Plug #1 Top of Cement. Recalculate cement volumes based on tag depth. 3. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 4. RU Coil Tubing Unit and Cementers. PT Surface Equipment as required. 5. Reference 5/20/2015 schematic for depth correlation. 6. RIH with coil tubing and tag TOC. 7. Pump 10 bbls fresh water spacer 8. Pump 163.5 bbls of 15.7 ppg ARCTICSET* I (AS1) Cement 9. Pump 10 bbls fresh water spacer behind 10. With approximately 50' of cement out of the nozzle, begin to pull out of hole, laying in cement, taking 1 for 1 returns up the coil tubing backside. 11. Continue to take cement returns from coil tubing x casing annulus until good quality 15.7#AS1 cement is weighed and confirmed at surface. 12.Wash up surface equipment. RDMO. Little Red (or DHD): 1. WOC 48 hrs. 2. RU LRS and PT Equipment. 3. MIT with diesel to 1,500 psi. Record Results 4. Perform drawdown test. Js • Wellhead Excavation/Final P&A: 1. Remove the Well House (if still installed). 2. Bleed off well to ensure all pressure is bled off the system. 3. Remove the production tree, in preparation for the excavation and casing cut. 4. If shallow thaw conditions are found, have shoring box installed during the excavation activity to prevent loose ground from falling into the excavation. 5. Cut off the wellhead and all casing strings at 4 feet below original ground level. 6. Perform Top Job and verify that cement is at surface. kOGCC witness and photo 7. Send the casing head w/stub to materials shop. Photo document. 8. Weld IA"thick cover plate (16" O.D.) over all casing strings with the following information bead welded into the top. 'hoto document. AOGCC Witness Required. ConocoPhillips 2G-02 PTD#: 184-121 API #: 50-029-21153-00 9. Remove Cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 10. Obtain site clearance approval from AOGCC. RDMO. 11. Report the Final P&A has been completed to the AOGCC, and any other agencies required. Photo document final location condition after all work is completed. JS • • Wellbore Schematic: A- KUP PROD 2G-02 ConocoPhillips Well 100.X0109 'prim Angle >o l�Ai :e Hawx neN0we SM. 0111/ YU I4MUS Ar 1 Ut , el wJ 9 3`00 1 KUPARL4KRivER 4610 1PROD r°00901 6.000.00 0676.01 ••• Nxl1104 Dm A..ei44. UGdtle aq 4.2140+. 3330 NONE I 0I 12130'2012 11144040 151°,72., j 40411 09)1901 IU.pI,11111.01 L.O. Moat n. t »14.001 UMr Iasi Tag611.116,364.0 10:132012 Re':Reason 0401EKMtER js*s lh tM512012615 1 I M� Ei Casing 04401( I C' i nStrin1 on, Inr imp Irn1 YI4144 P 1.1nrM n 41662,66 wx T P 360 . 610610.15700 '5052 380 116 itb H�0 WELDED M1401.10V44O4.3tt11111.• AMI/(M"v180.. 1H 441 010141 119 PORI 441 Minalain) [#Mn RMI nn4 en It lop 14144 to 440 �yU1thA(* I 95,8 8.921 l/4 2./194 1,1, 4 3D-W 467 010. L..00.040. CO nn1 10 PTO 1M 44101 Y.1 OT94.1e4411 4a OTOS 11004-181.4 11...1.0444 104141(.4 PRODUCTION-CUT 7 6.276 1.8520 6.6316 6,2308 26.004-55 BTC 2016 WO { R.awaw Pain SM.=Ex.. 0"40 C..qt olF0CAS f00IMI 101141 )Tna 1'(0 .1 0.10.1010 Sri 1.410 RMI.--Seol es IL.0040 Top TMS. 205 WCe I)1:14.4041, AIfr 4SA(1 111011 51414 441:'4 IS 1111 WI 41(;44 y 2015 WO-55'15' Tubing Strings , ` .i 1 111"b'1,16"01.1) .M Y 0 o 4141, 4 ny MS...IT Too Ktl .1 by I n 1461 14001 ITV.",.411)1'0'. . 6,41 -1., a 1 1144)0 W') '4 1 1'+. � ry e,1149 4 111 II 411 .Lirxlo Completion Details I ( Top I011P. 171406411..00, 1,61;01, went tx• ,'.nm i i 6.11.231 ;.91)1 a3 il'.PACNCR DAKCR 3-..-to r-,PEP/ANENT PROGUCI)04 1 055560101 3990 .........s.....07.1...-----.10.4PACKS 11 6,200.8 5,9.467 44391NAPLE DS NIPPLE WI0A-216.00.INSTALLED 2813 E i 4'.240T 5,909 3 u 7810VERSHOT 'BA01R POORBOT 001814)01 W,PACKOEr 3 610 • t.0.e Il..op. I,. Itlnng Y.,.-10 pm Toa I*00, en 0.9.104..xn T1.On 11404 t...1.14.TO 7.1.10 Twp 7(010400* �t.a.a.4 PIG: -11 i TUBING-ORIGD4AL I 3 12 2 992, 6,220.0 6,267 91 5.994.0930 L-60 iEuE8R04400 Completion Details Nona.TO 1.p144e1 Top(MD)41100 Toy SM 01 km.Dm Can 1 , 6.211.2 59792 4528'PACK}R 90Ktf900.20ERMA4ENT 06.C.K}R.K22 ANCHOR 3250 SCAT 11),9141010 6.261.8 5.807.0 4,.65 HIPPIE CAMCO D NPPLC 4..2 70-NO 003 PROFILE 2 7501 4741101 1 40:)3 1',Mi i NOS NAKFH SF&N1()111 SIM 4114114)/1-41,4 AS4104,847!tit '.--1' F'MI1.14,0 1-14,1419414 1.10F a 144,.111.AM. Other In Hole(Wireline retrievable plugs,valves.pumps,'fish.etc.) ',Miro Tnowe 1 O/ (p M14K4'1 xn U) 1Own 0.M. Wnal 4,(100 4,1089 1990'RdnlmeaIk• 1):(x-4141 51417Jnii 8009,'P100 ' 4.782.0 4.746.5 19.30 3 1)8 HT PAC Cemented in-TOO 5360't de 0120110 2.151 did pp.• S Via 474/0 34 J/13....,.1 1111:31,,.)).0100: 4117110 0M TOC 5 5'07'3280' y-=4 6,161.5 5.7328 4443 Junk Cache Annl Garner 110.31 4202015 w4wnrtD usMc.c-11116.191.0 69402 14.22 Sand 8149 9Sarin Pop 4(2100)6 yen: 4.. w1�y1y( - 11.200 11 1.9466 4419 el.)Plug 7917'CVJPloq 61147015 1® F 7300 59603 4451(:11111411(4 I:NFM CM V.'.?IItf 6,263.0 5.963.6 48 St CATCHER CATCHER 3x14.2015 1-e.. 6.258.0 1967 1' 45.614 PLUG 2 75'CA.2 PLUy. 110r1A10.12 0 000' Perforations&Slots r• • e.,1 � “.„;1717-.:.:Yr 2X.114'4 E� 1(p Melo M M,.04' 4ytt.4:o:.� (p 144M IIx OMIT 0101)0 Mrul La.m type Top 6119ti 1439%0 91411- 1401/00 AS.4007 10/611411: 40 PH* WO dog Pho41q,4- Srlomis.wpN 64140, 6.4580 60326• 6.;211 2.4 213.62 9116/1984 40 84EBF 90408 Mains!' i l ScF beger Notes:General&Safety i EM Dm MnOxan, 4152004 ;4.1.70 E1',.PARTIALL31,2 BARR6RS,REPAd1EO 441TH S EAI ANT 10114010 61117E`'44 0)1.0)101 A:6I6416 Sc5e9,4009.0 .51166100 4,44 9242041 1610TE.LEAK Pi 7'LOCATED AT 9988'11X8 USING TECWEL LDL TOOL ) 1- 110.114/1.1114; - 110.4-444'.: PN1Wa*.(451.4 41400,47 .4ua 4x01- SDs 4x014 6.6 +tor Ona o a.e+.-- I ri 110004 0077 -407x01.4I .14x44... JS ID • P&A Diagram: 2G-02 P&A PTD#: 184-121 SmaratittimmIgn proposed P&A I 7%7;92 a Staface1 15.7#AtxUcScl r 9-X'Casing Leak @ 32'KB 1 ._i_ 16.62.5#,14-40 Conductor @ 116'KB 4- 7"269 J-55 CUT@ 1852'KB '..', rt`) i' _. TOC PIug1@2,330'KB .• . .`® 15.9#Class"G 7"WRP Pkg @ 23294'KB 1.7p;. 1 9-518"36#,J-55 Surface Casing @ 2719.4'KB 1,' 5.35"15.5#,L-80 CUT @ 2797 T KB TOC Mslde 5.5"x7"Annulus:3280'KB �1 1ir d it j h ' 7"Casing Leak @ 3988'KB 'l It cI j fl 5-'n NRP Plug @ 4740 KB Irmo'ij II l 2-'4"HT-PAC Dnllpipe.Top @ 4782'KB 'I 1 TOC Inside DriHpipe and 2-7/f x 5.5"Annulus-5360'KB :.i TAM Combo Tool(BTM @ 5956') .I , 4-Si TAM 5"Cement Port Collar @ 6100'KB i i 3-14"z 5-/°Crossover d - - Baker Model F Permanent Packer @ 6152.3'KB i 1 2.813"DS Nipple with CA-2 Plug Set @ 6200.8'KB 3-'h'Tubing Cut Baker Poor-Boy Overshot EL Baker SAB-3 Permanent Packer @ 6241'KB 2 75•Camra D Nipple with CA-2 Plug Set @ 6258'KB M Baker SOS @ 6267'KB — 7"269,J-55 Production Casing @ 6631.6'KB Js • • 3. MIT with diesel to 1,500 psi. Record Results 4. Perform drawdown test. 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 production tree, in preparation for the excavation and casing cut. 4. If shallow thaw conditions are found, have shoring box installed during the excavation activity to prevent loose ground from falling into the excavation. 5. Cut off the wellhead and all casing strings at 4 feet below original ground level. 6. Perform Top Job and verify that cement is at surface. AOGCC witness aria photo document required _ ho f, A-oc cG *-a v'/fi 'rss 1 p job / -ac td L- 7. Send the casing head w/stub to materials shop. Photo document. 8. Weld 1/4"thick cover plate (16" O.D.) over all casing strings with the following information bead welded into the top. noto document. AOGCC Witness Required. ConocoPhillips 2G-02 PTD #: 184-121 API #: 50-029-21153-00 9. Remove Cellar. Back fill cellar withr v I g a e/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. ._.:-,�»... �.'.._.'•".mow.,.+---++ra-,....,- JS M • Loepp, Victoria T (DOA) From: Simek,Jill <Jill.Simek@conocophillips.com> Sent: Tuesday,July 19, 2016 11:20 AM To: Loepp,Victoria T(DOA) Subject: RE: KRU 2G-02(PTD 184-121, Sundry 316-337) P&A Sundry Attachments: FW_2G-02 (PTD 184-121, Sundry 315-058).pdf Follow Up Flag: Follow up Flag Status: Completed Hi Victoria, The TOC at 5360' RKB was tagged but not pressure tested. Per attached,the intention was to utilize the two sets of packer/plug combinations with the 800ft of cement as abandonment plug for the Kuparuk. Passing drawdown test and MITT to 2500psi were performed on the 6258' RKB plug on 3/14/2015. The 6200' RKB CA-2 plug was tested to 1500psi 4/21/2015. Thanks, Jill From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Friday,July 01,2016 9:32 AM To:Simek,Jill<JiII.Simek@conocophillips.com> Subject: [EXTERNAL]KRU 2G-02(PTD 184-121,Sundry 316-337) P&A Sundry Jill, Was the reservoir plug with TOC at 5360' MD pressure tested and charted? 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.Loepp@alaska.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 are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov 1 • • From: Smith.Travis T To: Simek,Jill Subject: FW:2G-02(PTD 184-121,Sundry 315-058) Date: Tuesday,July 19,2016 8:38:21 AM From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Thursday, May 07, 2015 3:34 PM To:Smith,Travis T<Travis.T.Smith@conocophillips.com> Subject: [EXTERNAL]RE: 2G-02 (PTD 184-121,Sundry 315-058) Travis, The 2 sets of packer/plug combinations with the 800' of cement as outlined below are adequate for the abandonment of the Kuparuk sands. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp@alaska.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 are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loeoo@alaska.gov From: Smith,Travis T[mailto:Travis.T.Smitl-aconocophillips.com] Sent:Tuesday, May 05, 2015 5:40 PM To: Loepp, Victoria T(DOA) Subject: RE: 2G-02 (PTD 184-121, Sundry 315-058) Hello Victoria— Per our conversation today, our current status is pulling out of hole with the 2%S" drill pipe after severing free from the drill pipe section that is cemented in hole. Because we are free from the stuck drill pipe,we will not need to get an extension to the BOP testing. . 40 s Wellbore Schematic: KUP PROD 26-02 f,,,,... 44,2.2.I ConocoPhillips Will Attributes Max Angie&MD TD 7;; r,r srr<maure ra r.uie1w a R ,.4?.8'Ki. w a 1uw1` 56111>d9Yspr1 (aUPflR�17S Ki4�CR%„1011 4'14516 605@ W6W 00 6.57;.4 I109 m1 �94* in.....3. ODar. 1W 4Iq -1170-1131a;55-5-0-56 .. O �'i14.2.194*a $.„25, n5WPC . o„�b012330@22)2 4ua1 AC, j W 4H352015 1 4*151j 01,5aaM*.. w7544 4444,,,,,,,,,,,,,, 0M51W740x* 0[4040 P Atai 001 Sw4+ I*0091 w * 0./.10,01 MO 21-446.3W 0 10£8532012 R Re xrt'xn+.En 1411 1:t.4m>*9rh .'22111 1, i 1 NUM Fn .ms s. 1, 0 M Er<9n 1)9 SM3 ISS 4) 04 e'SMS*+:x400) 014 09)10)140) 01 (4918' Y B lnm10 C00411)21(90 16 /5052 5801 1154 1162 62 55**40 WELDED ....V404404700 40)0 3^010 ..v 49*190)1 iSn*', OA 0). 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I i 65555 1-351 1 6.162.0 4 746 5 1470 275 HT 741; +,.15000174 51..7005380 011600 51)251; 2153 41;p5 TOc55'x7'3280' _ 6.1625= 5013181 4405 Junk 05l53,6, '2*.k Cotheri G.l`t 4))21@C1, 604410,04*40404 10'6 6,14441-' 64402 44.22"a aro,4 RW 01 ro4 S ,.9' 9 Rkep 41250011; S/41 Sots./* 1 " 4 60455' 42134 i'.A�Rau) tat}5,4,1040 g 633•30 05 1. 000600,[9.0)..[.93 a 1-Yhl'U .,9'�0 Y.,,»d.4..6, 1 44 A1�3 L.IS 030043 Grit M Gil ,k`.7a/1611i��� II , 6,2535; 5353 6 4554 62752425 C{TG15055 ^9)4110'05 6254 0.....54571'45.65 Pox i515.75'1.7-2 7'0200 1652416012 0660, iIYNC.I*.e1^_,®8415•••• - .„.,...,.... .._...__...... Perforations 3.Stan 4144010,00004 3 1 044 :a31'w'M tl4�, £9900031 1?+.1£aMW 001 144!i 01x'1* itW li*p4 5,3166 .... 6.9866 6,8B6fib fiOma AS 000'117 ?i1iS4 ,_•5"L914'1EiTF Wi Maq 5^-155.15151—:4'_...__ 150.5555,155 4,4 14 51 8..54.01 010§36 6.521 1 62 200.02 3115(1544 ' 46 0 0100 06 deg 994.590 4 ii 1 ,1.,51.x199 Nowt•Ca*weat a safety _.. , .. ol0,4 Esse 1 40,0555505 1'520(34 NOTE'E AKPARTIALLY,�6A*50505}5EP0115 0447405206005 i 53.1"01'.0193 Nii3`E'Vte✓<S0)I'131001Alaska54Aae•4*040'0 .. Al ,,.*,,, 9F2.4; 11 04015:LEAK 04 r.065TEG AT 1068'5356 14490 TEC4553.LG:TOOL • .4.444..,.. 0 I I ,..—E......SSM £ 9i7X .1343+* 90,1:*318.4 AYu..0.x a ..40.•—. M1e44T1094•CVT 7414010: ,a L .43.99.4400 4 Js • 1111 P&A Diagram: uyd 20-02 P&A t \I PTD#: 184.121 t k € Pr000sed PtiAlk :3 1/ Current Susvension, /// 4762°Casing Leak 9 37 KB 'e • /QC 631 Staleme 11 1 e 8 • 1 1 1._ 16762 9t,1440 Conductor 9 116°47D 1 • • • 1 1 , i 1 i E I , 1 ! E 1 A ': 74 2781e J SS 6419 16,67 KA , Li ' 1 r 1,47R14 Pityg 4.g..212.J 4"KS , ','Sv.tortAfti, 1 411, A Eile'MO.i CS Sof pg.CAsstIpt 28 8/1A 4°KO —, 4=7 4., 1054 L830 Su/**111707T rAS € , i 1 [ roc tamela a 8"x r Arta644e4 92119 Kle - i 44, A „, I e4 8 10...it- n CI-b 11 4 1 i 6 t 11 0:41 50c MP Mag 0 474a•KO 1 , x 1, 1, r51 2-78°keT-PAS Deakeepe Tap 9 4782'KB 11 , 41 1 • TOC 1111148 066494 sod 2-767 x 6 6"/4646488 6160'KB 81 8;.`, f Ill ;4 e ake Combo 1464 Mem 041418787/ ,69" : 40) 7,4Mv Ceieeket 496 COIKK 9 810tr Kee f • .i. „ ..,x,,wertasaver V,,.,....:4 '441F-LIP , ill Oak.,Model F Pennonent Packe4 9 F163 TKO 2 613 88 Neapee Kate CA,2 Ms Sat 9 6200 Ce KB .7..4—, ---- c r '.. ' -S-7,---- r,tl'u4d a "i 41 ae. 1 W/Kama Set 4,, ,L Baker Poor Soy Overshot 1.t ..a ' aaket SA$a Paereanerle Pate/48 94 KA I"KA. -r-' C e ,..CAmo r Noon won t",10 Pul Slot a(2061.8 71111 ; 01-(e ilm onm. Dakar 0)5 6,6267°XIS 101 , P74 2104 4 74;Natt.otton Comm gt Oral r KA ill IMII JS 1-21 16 JS • • Loepp, Victoria T (DOA) From: Simek,Jill <Jill.Simek@conocophillips.com> Sent: Friday,August 05, 2016 10:23 AM To: Loepp,Victoria T(DOA) Subject: RE: [EXTERNAL]RE: KRU 2G-02(PTD 184-121, Sundry 316-337) P&A Sundry Attachments: 2G-02 PandA Application for Sundry Approval js REVISION1.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, The modified procedure for 2G-02 P&A is attached. Note that I opted to bring cement to—2330' KB on the first cement plug. This eliminates an e-line run to reset the 7" plug and should ensure a competent bottom plug and passing MIT. Let me know if you have further questions or requests for procedure modification. Jill From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Monday,August 01,2016 10:33 AM To:Simek,Jill<Jill.Simek@conocophillips.com> Subject: RE: [EXTERNAL]RE: KRU 2G-02(PTD 184-121,Sundry 316-337) P&A Sundry No,just email me the new procedure- From: Simek,Jill [mailto:Jill.SimekOconocophillips.com] Sent: Monday, August 01, 2016 9:37 AM To: Loepp, Victoria T(DOA) Subject: RE: [EXTERNAL]RE: KRU 2G-02(PTD 184-121, Sundry 316-337) P&A Sundry Thanks Victoria. I will make the changes. Should I resubmit 10-403 with modified procedure? Jill Sent with Good(www.good.com) From: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Sent: Friday,July 29,2016 1:45:20 PM To:Simek,Jill Subject: [EXTERNAL]RE: KRU 2G-02(PTD 184-121,Sundry 316-337) P&A Sundry Jill, Thanx for the additional information. A pressure test will be needed on the plug at 4740' MD. Please modify the procedure to pull the 7" plug at 2320' MD, spot 75'of cement on plug at 4740' MD and pressure test this plug to 1500 psig. 1 • • w 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 are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victorialoem@alaska.gov From: Simek,Jill [mailto:Jill.Simek©conocophillips.com] Sent:Tuesday, July 19, 2016 11:20 AM To: Loepp, Victoria T(DOA) Subject: RE: KRU 2G-02(PTD 184-121, Sundry 316-337) P&A Sundry Hi Victoria, The TOC at 5360' RKB was tagged but not pressure tested. Per attached,the intention was to utilize the two sets of packer/plug combinations with the 800ft of cement as abandonment plug for the Kuparuk. Passing drawdown test and MITT to 2500psi were performed on the 6258' RKB plug on 3/14/2015. The 6200' RKB CA-2 plug was tested to 1500psi 4/21/2015. Thanks, Jill From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Friday,July 01,2016 9:32 AM To:Simek,Jill<JiII.Simek@conocophillips.com> Subject: [EXTERNAL]KRU 2G-02(PTD 184-121,Sundry 316-337) P&A Sundry Jill, Was the reservoir plug with TOC at 5360' MD pressure tested and charted? 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.Loeop aC ialaska.gov n CONF►DENTIALRY NOTICE:This e-mail message,includingany attachments,contains information from the Alaska Oil and Gas Conservation rvation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended 2 STATE OF ALASKA AI KA OIL AND GAS CONSERVATION COM ISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing l Operations shutdown Performed. Suspend r Perforate r Other Stimulate r Alter Casing rChange Approved Program Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other:Susp Well lnsp d- 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory r 184-121 3.Address: 6.API Number: Stratigraphic " Service r P. O. Box 100360,Anchorage,Alaska 99510 50-029-21153-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025656 KRU 2G-02 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 6675 feet Plugs(measured) None true vertical 6258 feet Junk(measured) None Effective Depth measured 2329 feet Packer(measured) 6152 true vertical 2329 feet (true vertical) 5912 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 116 116 1640 630 SURFACE 2682 9-5/8 2719 2719 3520 2020 PRODUCTION 4780 7 6632 6231 4980 4330 LINER 3355 5-1/2 6153 5913 7000 4990 t` Perforation depth: Measured depth: 6376'-6458' da� i N0 '' 1 1 201 True Vertical Depth: 6067'-6121' sober AUGRECE IVED 12 2015 Tubing(size,grade,MD,and TVD) 3.5, L-80,6267 MD, 5993 TVD AOGCC Packers&SSSVt e,MD,and TVD)) PACKER=BAKER 85-40 F-1 @ 6152 MD and 5912 TVD SSSV=NONE 12.Stimulation or cement squeeze summary: NA Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Exploratory r Development J' Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r VVDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r VVINJ r WAG r GINJ r SUSP SPLUG h 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: NA Contact MJ Loveland/Martin Walters Email n1878@conocophillips.com Printed Name Martin Walters/�ltTitle Well Integrity Supervisor Signature Rika--.77(/tl/��.� Phone:659-7043 Date:Aug 7, 2015 v TL-- /z//.5-- RBDMSd alit; 1 4 2015 Form 10-404 Revised 5/2015 Submit Original Only • • RECEWED AUG 122015 ✓ . . ACC ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 August 7, 2015 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Suspended Well Inspection 10-404 Sundry Kuparuk River Unit 2G-02 (PTD 184-121) Dear Commissioner Foerster: Enclosed please find the quinquennial suspended well inspection documentation as required by 20 AAC 25.110 for ConocoPhillips Alaska, Inc. Kuparuk River Unit well 2G-02 (PTD 184-121). The following documents are attached: - 10-404 Sundry - Suspended Well Check List - Wellbore Schematic - Location Plot Plan - Photographs Please call MJ Loveland or me at 659-7043 if you have any questions. Sincerely, l'Adt771-) Martin Walters ConocoPhillips Well Integrity Projects Supervisor • • Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: KUPARUK RIV UNIT 2G-02 Field/Pool: KUPARUK RIVER Permit#(PTD): 184-121 Sundry 315-058&315-274 API Number: 50-029-21153-00-000 Operator: ConocoPhillips Alaska, Inc. Date Suspended: 5/1/2015 Surface Location: 487' FSL, 44' FEL Section: 31 Township: 11N Range: 9E Nearest active pad or road: KRU DS2G Meridian: UMIAT Take to Location Digital camera Map showing well location/Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Good Pad or location surface: Good Location cleanup needed: None Pits condition: NA Surrounding area condition: Good Water/fluids on pad: Normal Discoloration, Sheens on pad, pits or water: None Samples taken: None Access road condition: Good Photographs taken (#and description): None Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2)well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: Good Cellar description, condition, fluids: Good Rat Hole: NA Wellhouse or protective barriers: Removed for summer Well identification sign: No sign Tubing Pressure (or casing if no tubing): 0 Annulus pressures: 0/0 Wellhead Photos taken (#and description): 2 of wellhead and cellar Work Required: Install well identification sign �/f Operator Rep (name and signature): Martin Walters /'i( %C / [ al ���i""m AOGCC Inspector: Johnnie Hill Other Observers: Will Lomer Inspection Date: 8/7/2015 AOGCC Notice Date: 8/3/2015 Time of arrival: 10:50 AM Time of Departure: 11:00 AM Site access method: Passenger Truck KUP PROD • 2G-02 ConocoPhillips ® Well Attributes Max Angle&MD TD A,,_Iti"I ,i�., Wellbore API/UWI Field Name Wellbore Status net(°) MD(ftKB) Act Ban(ftKB) mvevitiayups 500292115300 KUPARUK RIVER UNIT PROD 50.90 6,500.00 6,675.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 20-02,6/520158:4423 AM SSSV:NONE 0 12/30/2012 Last WO: 4/13/2015 40.41 8/9/1984 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 6,364.0 10/13/2012 Rev Reason:WORKOVER smsmith 5/20/2015 • Casing Strings . ""'""""""""' alfa,Casing Description OD(in) ID(in) Top(ftKB) Set Depth(10M) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 38.0 116.0 116.0 62.50 H-40 WELDED .0A1CONDUCTOR;38.0-116.0 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE 9 5/8 8.921 37.4 2,719.4 2,719.4 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WVLen(I...Grade Top Thread PRODUCTION-CUT 7 6.276 1,852.0 6,631.6 6,230.8 26.00 J-55 BTC 2015 WO Retrievable Bridge Plug;2,329.4 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WVLen(I...Grade Top Thread CEMENTED CASING- 51/2 4.950 2,797.7 6,153.4 5,912.5 15.50 L-80 BTCM 2015 WO-5.5"x5" @6075 x 3.5" Tubing Strings Tubing Description 'String Ma...I ID(in) I Top(ftKB) I Set Depth(ft...ISet Depth(TVD)(...I Wt(Ib/fl) (Grade !Top Connection TUBING-WO-2015 31/2 2.992 6,152.3 6,226.3 5,964.8 9.30 L-80 EUE 8rd Mod SURFACE;37.4-2,719.4-+ • Completion Details Nominal ID I Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 6,152.3 5,911.7 43.51 PACKER BAKER 85-40 F-1 PERMANENT PRODUCTION 3.990 Retrievable Bridge Plug:4,740 0- .4PACKER 6,200.8 5,946.7 44.39 NIPPLE DS NIPPLE W/CA-2 PLUG INSTALLED 2.813 ? 6,218.6 5,959.3 44.78 OVERSHOT BAKER POORBOY OVERSHOT WI PACKOFF 3.610 2 7/8 HT PAC drill pipe,4,782.0 j ) Tubing Description !String Mo...'ID(in) I Top(ftKB) ret Depth(ft..I Set Depth(ND)(...I Wt(Ib/ft) 'Grade 'Top Connection Cement;5,3600 TUBING-ORIGINAL 31/2 2.992 6,220.01 6,2679 5,9940 9.30 L-80 EUESRDMOD Completion Details Nominal ID Top(ftKB) Top(ND)(NKB) Top Incl(°) Item Des Com (in) 6,241.2 5,975.2 45.28 PACKER BAKER SAB-2 PERMANENT PACKER w/K22 ANCHOR 3.250 SEAL ASSEMBLY 6,257.9 5,987.0 45.65 NIPPLE CAMCO D NIPPLE w/2.75"NO GO PROFILE 2.750 6,267.0 5,993.3 45.85 SOS BAKER SHEAR OUT SUB PINNED FOR 3500 PSI, 2.937 II ELMD 6289'FROM SWS BHP OF 6/30/2005 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) W TopTop Incl Top(ftKB) (ftKB) Dec Com Run Date ID(in) 4,740.0 4,708.8 18.8.90 Retrievable COE 4743 5/11/2015 la Bridge Plug 4,782.0 4,748.5 19.30 27/8 HT PAC Cemented in-TOC 5360 inside 5/1/2015 2.151 drill pipe LA 5,360.0 5,277.0 29.77 Cement TOC 2 7/8 x 5.5 5360' 5/1/2015 0.000 TOC 5.5"X r 3280' 6,181.5 5,932.8 44.04 Junk Catcher Junk Catcher(10.3') 4/21/2015 CEMENTED CASING-2015 6,191.8 5,940.2 44.22 Sand Plug 9'Sand Plug 4/202015 2,797.7-6,153.4 6,200.8 5,946.6 44.39 CA-2 Plug '2.812"CA-2 Plug 4/21/2015 PACKER;6,152.3 I ¢9 I 6,220.0 5,960.3 44.81 CUT TUBING CHEM CUT 3/22/2015 6,253.0 5,983.6 45.54 CATCHER CATCHER 3/14/2015 6,258.0 5,987.1 45.65 PLUG 2.75"CA-2 PLUG 10/14/2012 0.000 Junk Catcher;8,181.5 Perforations&Slots Shot Sand Plug;6,191.8 Dens C Plug;6,200.8, - To ftKB Btm(ftKB) Top ftKB D) Blot D) Zone Date (shots/f TypeCom NIPPLE;6,200.6 a® P(ftKB) ) ( I (ftKB) ) 1 t 6,376.0 6,396.0 6,067.5 6,080.8 A-5,2G-02 9/16/1984 4.0 IPERF 90 deg.Phasing;4" Sclumberger 6,414.0 6,458.0' 6,092.6 6,121.1 A-4,20-02 9/16/1984 4.0 IPERF 90 deg.Phasing;4" Sclumberger • Notes:General&Safety 1 End Dale Annotation 4/5/2004 NOTE:LEAK PARTIALLY(2 BARRIERS)REPAIRED WITH SEALANT CUT TUBING;6,220.0 �elI 10/19/2010 NOTE:View Schematic w/Alaska Schematic9.0 OVERSHOT;6,218.6 9/24/2011 NOTE:LEAK IN 7"LOCATED AT 3988'RKB USING TECWEL LDL TOOL PACKER;6,241.2 1 ,m CATCHER;6,253.0 AIii. NIPPLE;6,258.0 PLUG ��i PLUG;8,256.0 SOS;6,267.0 IPERF;6,378.0-6,396.0 (PERF;6,4140-6,458.0 PRODUCTION-CUT 2015 WO; g ,*a 1,852.0-6,831.6 • ! N p c. 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''',.„ °fi-A4,,, -4,,,,--*Nv• A!'-'-',4N-,`,H N-,-... ,-- - 414 - -4...t *, --, ,,,,;:st*tor ...' 4/ ';.x _ ' 1.- , ' W, ' ''k - , - •„.- , -- •• • . ., •, . . j''''''.. :...'s, ,'''''''' !.........,?i.,''':'''''11`g.,1,1%,,,,,„ ...'1%,,t:mir.,^1.4^i',. ..„1 :#0.k...t.,1,,,A.,. ,........t•-, 7.:14 ,.. ic,t ',` ' ,, • '..,. ),:f,,..it.; . ''''Ati,„*„.."..;.^,1,40,74-4 .-4,4,,,,,"t„,,i-P-- -., • ,_ - — .; ,..TV '.- '-'.,... • . . . ,... '.,. , • . .„, ... - 2G-02PTE) 184-121 ,,,. • .• „.• . r - 0Conocoe411,11ips Alaska, Inc. 4, .. • . .,,,- ,,„,„„4, ,..- ..„ 410,., _.. ..., • . . „„„,,, ..... This photo is copyrighted by 4„ • . 6 ,, ,, • • - Alaska, inc. an'd : #- . ,iso t. „.• :.-, . ,. •• ConocoPhill:IPs -- ,-,, . ..,,:*":74 , •.4;* - , , ,... , , ' - cannot be released or published ' oe , , . . „..'.... ' written consent without express of ConocoPhillips, Ala - . .., , . . .. , . •„,,, „ska' ,, , s 4100 `,: S , r ,. „, _ _ .. ,..,,,k ''...41"”:77: 4, _,_,,„.. ',tA '- t `-',a j r , ,,, .4 ...,, , , , .,, „..,,,r 4111F A- �r�'r.„ � lie,„ r �if o 2G-02 PTD 184-121 ©ConocoPhillips Alaska, Inc. This photo is copyrighted by 4. ConocoPhillips Alaska, Inc. and � � cannot be released or published without express written consent of ConocoPhillips Alaska ' •4 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 08/08/15 Inspector: Johnnie Hill Operator: ConocoPhillips Alaska Inc Well Name: KRU 2G-02 - Oper. Rep: Martin Walters PTD No.: 1841210 Oper.Phone: 659-7043 Location Verified? Yes Oper.Email: n1878Aconocophillips.com_ If Verified,How? LAT/LONG Onshore/Offshore: Onshore Suspension Date: 05/13/15 - Date AOGCC Notified: 08/03/15 . Sundry No.: 315-274 - Type of Inspection: Initial Wellbore Diagram Avail.? No Well Pressures(psi): Tubing 0 Photos Taken? Yes IA 0 OA 0 Condition of Wellhead: good Condition of Surrounding Surface Location: good gravel Follow Up Actions Needed: Well sign missing Comments: well was verified by pad well location map Attachments: Photos(1) SCANNED SEP 0 7 2016 REVIEWED BY: Insp.Supry .7-5z 117 Comm PLB 06/2014 2015-0808_Suspend_KRU_2G-02jh.xlsx • • Suspended Well Inspection—KRU 2G-02 PTD 1841210 Photos by AOGCC Inspector J. Hill 8/8/2015 rl O t . — ti v • R 2015-0808 Suspend_KRU_2G-02j h.docx Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM. jSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing Operations Shutdown r Performed Suspend p r Perforate r Other Stimulate r Alter Casing r Change Approved Program T Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: I- 2 2 Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number. ConocoPhillips Alaska, Inc. Development J7 Exploratory r 184-121 3 Address: 6 API Number P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r 50-029-21153-00 7.Property Designation(Lease Number): 8.Well Name and Number. ADL 25656 KRU 2G-02 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): CBL Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 6675 feet Plugs(measured) 2327, 4743 true vertical 6258 feet Junk(measured) none Effective Depth measured 6554 feet Packer(measured) 6152,6241 true vertical 6181 feet (true vertical) 5912, 5975 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 116 116 SURFACE 2682 9.625 2720 2720 PRODUCTION 4779 7 6631 6231 E I V E D PRODUCTION INI 3350 5.5 6150 5914 �.a t1y WORK STRING 1342 2.875 6098 5872 I J N 1 0 2015 Perforation depth. Measured depth: 6376'-6396',6414'-6458' A`✓G C C True Vertical Depth: 6068'-6081',6094'-6121 SCANNED J U L •/ 0 )015 Tubing(size,grade,MD,and ND) 3.5, L-80,6267 MD, 5993 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER 85-40 F-1 PERMANENT PRODUCTION PACKER @ 6152 MD and 5912 ND PACKER-BAKER SAB-2 PERMANENT PACKER @ 6241 MD and 5975 ND NO SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured). 3600'and 5360' Treatment descriptions including volumes used and final pressure: cement in 5.5"x7"annulus with TOC @ 3600' and cement in 5.5" casing from 6152'to 5360' 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments(required per 20 AAC 25.070,25 071,&25 283) 15.Well Class after work Daily Report of Well Operations Exploratory r Development r Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r VVINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C O.Exempt. 315-058 & 315-274 Contact Travis Smith @ 265- 450 Email Travis.T.Smith@conocophillips.com Printed Name,- Tr/is Smith,- ( Title Wells Engineer Signature Phone:265-6450 Date VT' 7--// fl S RBDM JUN 1 1 2015 140YForm 10-404 Revised 5/2015 Submit Original Only Y KUP PROD 2G-02 COnOCOPhillips °- Well Attributes Max Angle',&MD TD Alaska,Inc Wellbore API/UWI Field Name Wellbore Status Incl(°) MD(ftKB) Act Btm(ftKB) mgcoyl,1A, 500292115300 KUPARUK RIVER UNIT PROD 50.90 6,500.00 6,675.0 ".. Comment MS(ppm) Date Annotation End Date KB-Grd(ft) 'Rig Release Date 2G-02,6/5/20158:49:23 AM SSSV:NONE 0 12/30/2012 Last WO: 4/13/2015 40.41 8/9/1984 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 6,364.0 10/13/2012 Rev Reason:WORKOVER smsmith 5/20/2015 Casing Strings r• . . """'-"in 1 a...,' aua,Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 38.0 116.0 116.0 62,50 H-40 WELDED .M.PCONDUCTOR;38.0-116,0 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE 9 5/8 8.921 37.4 2,719.4 2719.4 36.00 J-55 ETC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wf/Len(I...Grade Top Thread PRODUCTION-CUT 7 6.276 1,852.0 6,631.6 6,230.8 26.00 J-55 BTC 2015 WO Retrievable Bndge Plug;2,329.4 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CEMENTED CASING- 51/2 4.950 2797.7 6,153.4 5,912.5 15.50 L-80 BTCM 2015 WO-5,5"x 5" @6075 x 3.5" Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TOD)(...Wt(Ib/ft) Grade Top Connection TUBING-WO-2015 31/2 2.992 6,152.3 6,226.3 5.964.8 9.30 L-80 EUE 8rd Mod SURFACE;37.4-2,719.4-• eCompletion Details Nominal ID I Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 6,152.3 5,911.7 43.51 PACKER BAKER 85-40 F-1 PERMANENT PRODUCTION 3.990 Retrievable Bridge Plug;1740.0 PACKER 6,200.8 5,946.7 44.39 NIPPLE DS NIPPLE W/CA-2 PLUG INSTALLED 2.813 111.1 6,218.6 5,959.3 44.78 OVERSHOT BAKER POORBOY OVERSHOT W/PACKOFF3.6102 7/6 HT PAC drill pipe;4,782.0 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection Cement;5,3600 L TUBING-ORIGINAL 31/2 2.992 6,220.0 6,267.9 5,994.0 9.30 L-80 EUE8RDMOD Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(") Item Des Corn (In) 6,241.2 5,9752 45.28 PACKER BAKER SAB-2 PERMANENT PACKER w/K22 ANCHOR 3.250 SEAL ASSEMBLY 6,257.9 5,987.0 45.65 NIPPLE CAMCO D NIPPLE w/2.75"NO GO PROFILE 2.750 6,267.0 5,993.3' 45.85 SOS BAKER SHEAR OUT SUB PINNED FOR 3500 PSI, 2.937 • ELMD 6289'FROM SWS BHP OF 6/30/2005 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) la Top(ND) Top Incl If Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 4,740.0 4,708.8 18.90 Retrievable COE 4743 5/11/2015 Bridge Plug 4,782.0 4,748.5 19.30 2 7/8 HT PAC Cemented in-TOC 5360 Inside 5/1/2015 2.151 I I drill pipe 5,360.0 5,277.0 29.77 Cement TOC 2 TIB x 5.5 5360' 5l1/2015 0.000 1111 TOC 5.5"X7"3280' 6,181.5 5,932.8 44.04 Junk Catcher Junk Catcher(10.3') 4/21/2015 CEMENTED CASING-2015 - 6,191.8 5,940.2 44.22 Sand Plug 9'Sand Plug 4/21/2015 WO-5.5-zS,7807-6,153; ] 2,797.743,ts3.a� 6,200.8 5,946.6 44.39 CA-2 Plug 2.812"CA-2 Plug 4/21/2015 PACKER;8,152.3 I w I 6,220.0 5,960.3 44.81 CUT TUBING CHEM CUT 3/22/2015 6,253.0 5,983.6 45.54 CATCHER CATCHER 3/14/2015 6.258.0 5,987.1 45.65 PLUG 2.75"CA-2 PLUG 10/14/2012 0.000 Junk Catcher;6,181.5 4 - Perforations&Slots Shot Sand Plug 8.191.8 Dens CA-2 Plug;6,200.01as Top(ND) BM,(ND) (shots)f NIPPLE;6,200.8 Top(ftKB) Blue(ftKB) (ftKB) (ftKB) Zone Date t) Type Com i 6,376.0 6,396.0 6,067.5 6,080.8 A-5,2G-02 9/16/1984 4.0 (PERF 90 deg.Phasing;4" -ii iiSclumberger 6,414.0 6,458.0 6,092.6 6,121.1 A-4,20-02 9/16/1984 4.0 IPERF 90 deg.Phasing;4" Sclumberger Notes:General&Safety T End Date Annotation 4/5/2004 NOTE:LEAK PARTIALLY(2 BARRIERS)REPAIRED WITH SEALANT CUT TUBING;8220.0 10/19/2010 NOTE:View Schematic w/Alaska Schemagc9.0 OVERSHOT:6,218.6 9/24/2011 NOTE:LEAK IN 7"LOCATED AT 3988'RKB USING TECWEL LDL TOOL PACKER;6,241.2 CATCHER;6,253.0 f;Ili NIPLUG;PPLE;6,6,258.257.09, �� �. SOS;6,267.0 IPERF;6,378.0-8396.0 ` IPERF;6,414.0-8458.0 PRODUCTION-CUT 2015 WO; 41 la' 1,852.0-6,631.8 2G-02 PRE-RIG WELL WORK DATE SUMMARY 12/24/2014 (PRE-RWO) : FUNCTION TESTED T & IC LDS'S (COMPLETE), T-POT (PASSED), T-PPPOT (PASSED), IC-POT (PASSED), IC-PPPOT (PASSED). 3/13/2015 ON COLD WEATHER HOLD, IN PROGRESS. 3/14/2015 .2500# MITT AND DRAWDOWN TEST PASSED.SET 2.74" OD X 61" CATCHER ON PLUG @ 6258' RKB.PULLED 1.5" DV @ 6156' RKB.READY FOR CIRCOUT.IN PROGRESS 3/15/2015 circ-out well, pump 130 bbls 10.2#CRW Brine and 90 bbls dsl down tbg, u-tube well, READY FOR ELINE 3/19/2015 PERFORMED LEAK DETECT WITH TMD3D PULSED NUETRON TOOL CONFIGURED FOR UP FLOW. OBSERVED FLUID ENTERING IA BETWEEN 5250'-5500'AND EXITING THE IA THROUGH KNOWN LEAK @ 3975. DID NOT OBSERVE ANY FLUID MOVEMENT AROUND PERMANENT PACKER 3/22/2015 RAN STRING SHOT FROM 6,216'TO 6,224' RKB CUT TBG W/CHEM CUTTER @ 6,220' RKB ConocoPhillips Time Log & Summary We((view Web Reporting Report Well Name: 2G-02 Rig Name: NABORS 9ES Job Type: RECOMPLETION Rig Accept: 4/15/2015 2:00:00 AM Rig Release: 5/13/2015 12:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 34/13/2015 24 hr Summary Move shops, satellite camp, and pits from 1E pad to CPF2. Move the sub from 1E pad to E pit. 00:00 12:00 12.00 0 0 MIRU MOVE MOB P Continue to prep for rig move. Remove berming,clean cellar area, install new cement line, and perform general maintenance. 12:00 19:00 7.00 0 0 MIRU MOVE MOB P Move pits away from the sub and install the jeep. Load up the, pits, welding shop, mechanic shop and satellite office and move from 1 E pad to CPF2. 19:00 00:00 5.00 0 0 MIRU MOVE MOB P Lower the derrick, pull sub off 1E-170, clean location, and transport sub from 1 E pad to E pit. 04/14/2015 Move the, pits,welding shop, mechanic shop and satellite office and move from CPF2 to 2G pad and spot on location. Move sub from 1 E pit to 2G pad and spot over well 2G-02. Spot the pits next to the sub and rig up lines. Raise the derrick, raise the cattle chute, and bridle down. Spot cutting tank and set up berming. 00:00 01:00 1.00 0 0 MIRU MOVE MOB P Move the, pits,welding shop, mechanic shop and satellite office and move from CPF2 to 2G pad and spot on location. 01:00 12:00 11.00 0 0 MIRU MOVE MOB P Move sub from 1E pit to 2G pad 12:00 14:00 2.00 0 0 MIRU MOVE MOB P Spot sub of well 2G-02 14:00 16:00 2.00 0 0 MIRU MOVE MOB P Spot the pit to the sub 16:00 19:30 3.50 0 0 MIRU MOVE RURD P Re-string bridal line tugger and hook up the line to the pits. 19:30 21:30 2.00 0 0 MIRU MOVE RURD P Raise the derrick, raise the cattle chute,and bridal down. 21:30 00:00 2.50 0 0 MIRU MOVE RURD P Spot cuttings tank and setup berming. 34/15/2015 Accept the rig at 02:00 hours. Load the pits with seawater. Attempt to test lines but leaks in the choke house manifold. Replaced two chokes and rubber gaskets; retest passed. RU lubricator,test to 1000 psi, and attempt to pull BPV without success. Troubleshoot with Vetco town rep and mobilize valve crew to assist 00:00 02:00 2.00 0 0 MIRU MOVE RURD P Spot matting board and herculite for LEPD tank. Go through rig acceptance check list and accept the rig at 02:00 hours. IA=275 psi; OA=4 psi 02:00 09:00 7.00 0 0 MIRU MOVE RURD P Bring on 580 bbls of seawater. RU circulating equipment in the cellar and RU the rig floor. Page 1 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 17:30 8.50 0 0 MIRU WELCTL PRTS T Unable to get auxiliary AES choke manifold and circ manifold to test at 250/3,000 psi. Replaced two chokes and rubber gaskets in the choke house manifold. Retest passed. 17:30 19:30 2.00 0 0 MIRU WELCTL RURD P PU and RU lubricator to tree. PT to 1000 psi(good test) 19:30 20:30 1.00 0 0 MIRU WELCTL MPSP P Attmept to pull type'F' BPV but did not get it on the first try. On second attmept engaged BPV but unable to move it up more than about 15" 20:30 00:00 3.50 0 0 MIRU WELCTL MPSP T Troubleshoot with Vetco rep in town and attmept to pull BPV. Unseated BPV but unable to pull and unable to re-set. Lubricator pump is not putting out proper pressure. Wait for new lubricator pump and valve crew to arrive. 04/16/2015 Successfully pulled the BPV with help from the valve crew. Began killing the well by pumping 25 bbls hi visc sweep followed by 230 bbls of seawater walking the pumps up to 5 BPM. Shut down and monitored the well pressures;tubing= 100 psi and IA= 100. New KWF calculated to be 9.4 ppg with 125 psi safety factor. Call out 280 bbls of 9.7 ppg NaCI and mixed with seawater in the pits to make 460 bbls of 9.4 ppg NaCI. Circulate around 255 bbls of 9.4 ppg at 5 BPM, shut down, and allowed tubing and IA to equalize. Monitor for 30 minutes,well static. Install BPV, ND tree, installed blanking plug, NU DSA, and NU BOPE. 00:00 01:45 1.75 0 0 MIRU WELCTL MPSP T Valve crew arrived to assist and found the SSV not fully opened. Second attempt to pull BPV unsuccessful and had to grease the master valve. 01:45 ' 02:15 0.50 0 0 MIRU WELCTL MPSP P Recovered BPV on third attempt. RD lubricator. 02:15 03:00 0.75 0 0 MIRU WELCTL RURD P RU circulating equipment to kill well. 03:00 03:15 0.25 0 0 MIRU WELCTL SF-FY P PJSM. During discussions on kill tank volume it was determined that the kill line was RU to the slop tank not the kill tank. 03:15 03:30 0.25 0 0 MIRU WELCTL RURD T RU kill line from the slop tank to the kill tank and PT line. 03:30 04:30 1.00 0 0 MIRU WELCTL KLWL P Begin well kill by pumping 25 bbls hi visc sweep followed by 230 bbls of seawater walking the pump up to 5 BPM. Got good clean seawater to surface. Shut down pumps. 04:30 06:00 1.50 0 0 MIRU WELCTL OWFF P RU working gauges to the tubing/IA and monitor the pressures. Tubing= 100 psi; IA= 100 psi. 06:00 14:00 8.00 0 0 MIRU WELCTL COND T Calculated new kill weight fluid with 125 psi safety factor=9.4 ppg. Call out 280 bbls of 9.7 ppg NaCl and mix with sea water to make 460 bbls of 9.4 ppg NaCI 14:00 15:00 1.00 0 0 MIRU WELCTL KLWL T Open up well, 100 psi on tbg/csg. Hold 100 psi back pressure. Circulate 255 bbls @ 5 bpm ©840 psi and recovered 250 bbls at the kill tank. Page 2 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 17:00 2.00 0 0 MIRU WELCTL RURD T Blow down circulating lines. Jumper the tubing and IA allowing well to u-tube and equalize. 17:00 17:30 0.50 0 0 MIRU WELCTL OWFF T Observer the well for flow for 30 minutes. Well is static. 17:30 18:30 1.00 0 0 MIRU WHDBO MPSP P Install type'F' BPV. Attempt a rolling 1000 psi test on the BPV from below but injecting fluid in the holes in the 7"casing at 580 psi but no communication above BPV. 18:30 19:30 1.00 0 0 MIRU WHDBO OTHR P Blow down lines, RD lines, and circulating equipment. 19:30 22:30 3.00 0 0 MIRU WHDBO NUND P ND tree, unseat tree using the TD, set the tree back using the bridge crane, clean up the wellhead, and install blanking plug onto BPV. Had to clean scale out of the hanger lift threads. 22:30 00:00 1.50 0 0 MIRU WHDBO NUND P NU DSA and NU BOPE. 04/17/2015 Continue to NU BOPE, change upper rams to 7"solid body rams, and install riser. RU BOPE testing equipment and attempt to shell test but unable to get a passing test. Trouble shoot leaks, change upper rams from 7"solid body rams to 2-7/8"x 5"VBR's, and change out choke#16. Determine blanking plug to be leaking, pull blanking plug, and pull BPV. RU Dutch riser, RU HES slickline, and PT Dutch riser to 250/1000 psi. 00:00 05:00 5.00 0 0 MIRU WHDBO NUND P Continue to NU BOPE, change upper rams to 7"solid body rams and install riser. 05:00 08:00 3.00 0 0 MIRU WHDBO RURD P RU BOPE testing equipment. PU and MU 3-1/2"test joint. Fill BOPE, choke manifold, and Kill NCR's with water. 08:00 09:30 1.50 0 0 MIRU WHDBO PRTS P Attempt to shell test BOPE but the pressure leaks off. 09:30 10:30 1.00 0 0 MIRU WHDBO RURD T Trouble shoot leak. Prep to change out choke#16 and change upper rams. 10:30 13:30 3.00 0 0 MIRU WHDBO RURD T Change upper rams from 7"solid body rams to 2-7/8"x 5"VBR's. Change out choke#16. Clean up the cellar 13:30 16:00 2.50 0 0 MIRU WHDBO PRTS T Attempt to shell test against blinds, Demco kill, and chokes 1, 2, 3, & 16. Still will not holding pressure. Trouble shoot and isolating components to determine leak. Blanking plug confirmed to be leaking. 16:00 17:00 1.00 0 0 MIRU WHDBO RURD T Blow down lines, drain the stack, and grease choke/HCR's. 17:00 19:00 2.00 0 0 MIRU WHDBO MPSP T Pull blanking plug, redress, and reinstall blanking plug. Fill the stack, close the blinds, and attempt to test against blanking plug but it will not hold pressure, slow leak. 19:00 19:30 0.50 0 0 MIRU WHDBO RURD T Drain BOPE and blow down lines Page 3 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:30 20:30 1.00 0 0 MIRU WHDBO MPSP T Pull blanking plug,sting into BPV, and open poppet to check for pressure. SimOps: Spot HES slickline unit and prep to RU slickline. 20:30 21:00 0.50 0 0 MIRU WHDBO OWFF T Observer the well for 30 minutes to ensure not trapped gas below BPV (static)and pulled BPV. 21:00 00:00 3.00 0 0 MIRU WHDBO SLKL T PJSM. RU Dutch riser and RU HES slickline. MU dummy tool string. Attempt to PT Dutch riser to 250/1000 psi failed, had to replace o-ring on stripper cap. Re-test to 250/1000 psi passed. 04/18/2015 Set CA-2 plug in 2.812" 'DS' nipple at 480' MD and PT to 250/3000 psi for 5 minutes. Conducted initial BOPE test to 250/3000 psi: test VBR's to with 3-1/2"and 4"test joints;test annular to 250/3000 with 3-1/2" and 4"test joint;conducted CPAI Koomey Draw Down Test. All tested passed. The States right to witness was waived by AOGCC inspector Jeff Jones. RU HES slickline, pull CA-2 plug, POOH, and RD HES slickline. Spear tubing hanger, BOLDS, unseat tubing hanger, pull hanger to the rig floor, and lay down tubing hanger. POOH laying down 3-1/2"tubing from 6220'to 4599'at midnight. 00:00 02:30 2.50 0 0 MIRU WHDBO SLKL T RIH with dummy drift and locate nipple profile. Could not get into tubing hanger. Reconfigure tool string still with centralizer got about 18"in and tagged hard. Drained the stack,visually saw no obstructions. RIH with dummy string making sure it was centered and made it in 40'. 02:30 03:15 0.75 0 0 MIRU WHDBO SLKL T RIH with dummy drift and locate nipple profile. POOH, reconfigure tool string with CA-2 plug, RIH, set CA-2 plug in'DS' nipple at 480', and POOH. 03:15 04:00 0.75 0 0 MIRU WHDBO PRTS T Close the blind rams and PT CA-2 plug to 250/3000 psi for 5 minutes (good test). 04:00 04:30 0.50 0 0 MIRU WHDBO SLKL T Partially RD HES slickline leaving unit on location to be able to pull the CA-2 plug after BOPE testing is complete. 04:30 05:00 0.50 0 0 MIRU WHDBO SLKL T RD Dutch riser and place in pipe shed. 05:00 05:30 0.50 0 0 MIRU WHDBO RURD T RU BOPE testing equipment. PU and MU 3-1/2"test joint. Fill BOPE, choke manifold, and Kill HCR's with water. Shell test BOPE to 250/3000 psi. Page 4 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:30 14:30 9.00 0 0 MIRU WHDBO BOPE P Conduct initial BOPE test to 250/3000 psi: test VBR's to with 3-1/2"and 4"test joints;test annular to 250/3000 with 3-1/2"and 4"test joint. The States right to witness was waived by AOGCC inspector Jeff Jones on 4/14/15 at 06:46 hours via email. Tests: #1) Blinds, Demco Kill, Chokes 1,2, 3, & 16(Passed) #2) HCR Kill, Chokes 4, 5, &6 (Passed) #3) Manual Kill, Chokes 7, 8, &9 (Passed) #4) Manual Choke, Hydraulic Choke (Passed) #5) Chokes 10& 11 (Passed) #6) Chokes 12, 13, & 14(Passed) #7) TIW, Choke 15, HCR Kill, Annular with 3-1/2"test joint (Passed) #8) TIW, HCR Choke, Upper IBOP, Upper Pipe rams with 3-1/2"test joint(Passed) #9) Manual Choke, Lower IBOP, Upper Pipe rams with 3-1/2"test joint(Passed) #10) Lower Pipe rams with 3-1/2" test joint(Passed) #11) 3-1/2"EUE TIW#1, Outer Test Spool, Upper Pipe rams with 3-1/2" test joint (Passed) #12) 3-1/2" EUE TIW#2, Inner Test Spool, Upper Pipe rams with 3-1/2" test joint (Passed) #13) Dart Valve, HCR's,Annular with 4"test joint(Passed) #14) TIW, HCR's Upper Pipe rams with 4"test joint(Passed) #15) TIW, HCR's Lower Pipe rams with 4"test joint(Passed) Conduct CPAI Koomey Draw Down Test: Starting Accumulator Pressure= 2950 psi Accumulator Pressure After Closer= 1700 psi Pressure Gain of 200 psi=32 seconds Full System = 152 Seconds Average N2(6 Bottles)= 1992 psi 14:30 16:00 1.50 0 0 MIRU WHDBO RURD P RD BOPE testing equipment. Page 5 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 17:30 1.50 0 0 MIRU WHDBO SLKL T PJSM. RU Dutch riser and HES slickline. MU CA-2 equalizing prong retrieving tool and PT Dutch riser to 500 psi. 17:30 18:30 1.00 0 0 MIRU WHDBO SLKL T RIH with equalizing prong retrieving tool, pull equalizing prong,and POOH. Reconfigure tool string to pull CA-2 plug, RIH, pull CA-2 plug, and POOH. 18:30 19:15 0.75 0 0 MIRU WHDBO SLKL T Lay down tools, RD HES slickline, RD Dutch riser. Clean and clear the floor. 19:15 20:15 1.00 0 0 COMPZ RPCOM RURD P RU GBR tubing pulling equipment. SimOps-PU and MU BHA#1 - Spear assembly to spear tubing hanger. 20:15 20:30 0.25 0 0 COMPZ RPCOM SFTY P PJSM for pulling 3-1/2"tubing completion 20:30 21:30 1.00 0 6,220 COMPZ RPCOM PULL P Spear tubing hanger, BOLDS(had to work old LDS loss from gland nuts), unseat tubing hanger at 107K(72K over block weight), pull hanger to the rig floor, and lay down tubing hanger. 21:30 22:00 0.50 6,220 6,220 COMPZ RPCOM RURD P Secure well with 3-1/2"EUE 8rd TIW, lay down spear assembly,and change elevators from 4"DP to 3-1/2"tubing. 22:00 00:00 2.00 6,220 4,599 COMPZ RPCOM PULL P POOH laying down 3-1/2"tubing from 6220'(PU =85K; SO=75K)to 4599'at midnight 04/19/2015 Continue to POOH laying down 3-1/2"tubing from 4599'to surface. PU, MU, and RIH with cleanout/dress-off assembly to 6161'RKB;wash down to 6206' RKB(shoe depth)and tag tubing stub with 10K down. Dress-off tubing stub down to 6208' RKB(shoe depth); top of tubing stub at 6199' RKB. Pump sweep surface to surface and pump 37 bbl corrosion inhibited 9.4 ppg brine pill. Hydraulic return hose on the TD failed releasing 1/2 gallon of hydraulic fluid. Cleaned up hydraulic fluid with absorb and dispose of absorb properly. Repair hydraulic return line on the TD. 00:00 00:15 0.25 4,599 4,599 COMPZ RPCOM SFTY P Crew change. 00:15 06:30 6.25 4,599 0 COMPZ RPCOM PULL P Continue to POOH laying down 3-1/2"tubing from 4599'to surface. Strapping,tallying, and offloading from the pipe shed. Cut joint length= 15.62-ft w/3.53"OD at cut. 06:30 08:00 1.50 0 0 COMPZ RPCOM RURD P RD Tbg running/pulling equipment. Clean and clear work floor and pipe shed in order to RIH w/BHA#1 - Cleanout/Dress-off Assembly. 08:00 11:00 3.00 0 318 COMPZ WELLPF BHAH P PU, MU and RIH w/6"x 3.625" Sizing shoe with inner mill to 318-ft 11:00 16:30 5.50 318 6,161 COMPZ WELLPF PULD P Continue to RIH w/BHA#1 while PU, MU and RIH on 4"HT 40 Drill pipe to 6161' RKB(PU = 143K; SO= 115K) Page 6 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:30 17:30 1.00 6,161 6,208 COMPZ WELLPF WASH P Wash down over stub at 3 BPM = 300 psi and tag stub with 10K down at 6205.7' RKB(shoe depth). Dress-off down to 6207.7' RKB at 50 RPM and 8K torque. Top of tubing stub located at 6198.7' RKB. 17:30 19:00 1.50 6,208 6,207 COMPZ WELLPF CIRC P Pump 40 bbl 10.2 ppg flow pro mud sweep followed by 9.4 ppg brine surface to surface at 8.5 BPM = 1642 psi. Monitor the well (well static). Lay down single and blow down TD. 19:00 20:00 1.00 6,207 6,207 COMPZ WELLPF SLPC P Slip&Cut 80'of drilling line. 20:00 21:00 1.00 6,207 6,207 COMPZ WELLPF WAIT T Wait on truck with corrosion inhibited brine. SimOps: Service crown,TD, and draw works. General house keeping and maintenance. 21:00 22:00 1.00 6,207 6,207 COMPZ WELLPF CRIH P Circulate 37 bbls of corrosion inhibited 9.4 ppg brine at 2.5 BPM= 231 psi followed by 51 bbls of 9.4 ppg brine at 4 BPM=450 psi. 22:00 22:30 0.50 6,207 6,207 COMPZ WELLPF RURD P Blow down top drive and prep rig floor to TOOH. 22:30 00:00 1.50 6,207 6,207 COMPZ WELLPF RGRP T Hydraulic return hose on the TD failed releasing 1/2 gallon of hydraulic fluid. Cleaned up hydraulic fluid with absorb and dispose of absorb properly. Repair hydraulic return line on the TD. 04/20/2015 TOOH with cleanout/dress-off assembly; after close inspection of dress-off mill and discussions with Baker Fishing it was determined that another dress-off run was needed. TIN with dress-off assembly, circulate out corrosion inhibited brine,tag tubing stub at 6208'RKB, and wash over to 6216' RKB(tubing stub dressed off down to 6207' RKB). Spotted 38 bbls corrosion inhibited 9.4 ppg brine pill, TOOH, and laid down dress-off assembly(recovered approximately 10 lbs of metal). PU and MU poorboy overshot and nipple assembly. Dump 9'of sand on top of CA-2 plug, MU 1 joint of 3-1/2"tubing, installed 10.3'junk catch on top of sand, MU F-1 packer assembly, and MU B-2 hydraulic setting tool. 00:00 00:30 0.50 6,207 6,207 COMPZ WELLPF SFTY P Crew Change 00:30 03:00 2.50 6,207 318 COMPZ WELLPF TRIP P TOOH with BHA#1 - Cleanout/Dress-off Assembly. 03:00 03:30 0.50 318 318 COMPZ WELLPF RURD P Change elevator from 4"DP to 3-1/2" DP to stand back DC's. 03:30 05:30 2.00 318 0 COMPZ WELLPF BHAH P Stand back 3 stands of DC's and lay down BHA#1. Clean and clear the floor of fishing tools. 05:30 07:00 1.50 0 0 COMPZ RPCOM RURD T RU GBR tubing running equipment. After close inspection of dress-off mill and discussions with Baker Fishing it was determined that another dress-off run was needed. RD tubing tong equipment. 07:00 08:00 1.00 0 312 COMPZ WELLPF BHAH T PU and MU BHA#2-Dress-off assembly. Page 7 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:00 10:30 2.50 312 6,208 COMPZ WELLPF TRIP T Change elevator to 4' DP. TIH with BHA#2 and tag tubing stub at 6208' RKB(PU = 140K; SO= 120K). 10:30 11:00 0.50 6,208 6,208 COMPZ WELLPF CIRC T Circulate out corrosion inhibited pill at 5 BPM =590 psi taking returns to the cutting tank. 11:00 13:15 2.25 6,208 6,216 COMPZ WELLPF WASH T Wash over tubing stub from 6208'to 6215.5' RKB at 3-6 BPM=230-540 psi, rotating weight= 125K,torque off=4K, torque on 5-7K,weight on bit=5-15K. Tubing stub at 6206.5' RKB. 13:15 13:30 0.25 6,216 6,216 COMPZ WELLPF OWFF T Blown down TD while observing the well for flow for 10 minutes,well static. 13:30 14:30 1.00 6,216 6,216 COMPZ WELLPF WAIT T Wait on truck with corrosion inhibited brine. SimOps: Service TD wash pipe packing. 14:30 16:15 1.75 6,216 6,216 COMPZ WELLPF CRIH T Circulate 38 bbls of corrosion inhibited 9.4 ppg brine at 3 BPM = 270 psi followed by 66 bbls of 9.4 ppg brine at 5 BPM=620 psi. 16:15 16:30 0.25 6,216 6,216 COMPZ WELLPF OWFF T Blown down TD while observing the well for flow for 10 minutes,well static. 16:30 19:30 3.00 6,216 312 COMPZ WELLPF TRIP T TOOH with BHA#2-Dress-off assembly from 6215.5'to 312' RKB. 19:30 21:30 2.00 312 0 COMPZ WELLPF BHAH T Stand back 3 stands of DC's and lay down BHA#2. Recovered approximatelyl0 lbs of metal in the boot basket. Clean and clear the floor of fishing tools. 21:30 22:00 0.50 0 0 COMPZ RPCOM RURD P RU GBR tubing running equipment 22:00 22:15 0.25 0 0 COMPZ RPCOM SFTY P PJSM for PU, MU, and RIH of lower packer assembly. 22:15 00:00 1.75 0 88 COMPZ RPCOM PUTB P PU and MU poorboy overshot and nipple assembly. Dump 9'of sand on top of CA-2 plug, MU 1 joint of 3-1/2"tubing, installed 10.3'junk catch on top of sand, MU F-1 packer assembly,and MU B-2 hydraulic setting tool. 04/21/2015 TIH with F-1 packer assembly,engage overshot onto tubing stub, no-go, PU 1', set F-1 packer per Baker rep and release B-2 hydraulic setting tool. Lay down 3 joints, set test packer, pressure up down the DP to 1500 psi for 30 minutes to test the packer/plug combination from above(good test). Unset test packer, lay down 90 joints of DP, and TOOH standing back 33 stands of DP. PU, MU,and TIH with 'G' Lock-set RBP. Set RBP at 3042' RKB(center of element at 3046' RKB), release running tool, and stand back 2 stands of DP. PT'G' Lock-set RBP to 1500 psi for 30 minutes(good test). Dump eighteen 60 lb(50')sacks of sand down the DP on top of the RBP. 00:00 00:15 0.25 88 112 COMPZ RPCOM BHAH P MU up bumper sub and test packer 00:15 00:45 0.50 112 112 COMPZ RPCOM RURD P RD GBR tubing running equipment. Change elevator from 3-1/2"DP to 4" DP. RU DP fill up hose. Page 8 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:45 06:00 5.25 112 6,207 COMPZ RPCOM RCST P TIH with F-1 packer assembly on DP filling DP every stand. Tag top of tubing stub at 6206.5' RKB(PU= 130K, SO= 115K). 06:00 07:00 1.00 6,207 6,138 COMPZ RPCOM PACK P Engage overshot over tubing tub and saw good shear indication of overshot engagement. No-go and PU 1'. Pressure up to 3000 psi(saw initiation shear at 1600 psi), pulled 40K over, and SO 30K(repeated sequence 3 times). Release B-2 hydraulic setting tool with 15 turn to the right. Top of packer at 6152'ORKB. 07:00 07:15 0.25 6,138 6,025 COMPZ RPCOM PULD P Blow down TD and lay down 3 joints of DP. 07:15 07:30 0.25 6,025 6,025 COMPZ RPCOM MPSP P Set test packer at 6020' RKB(center of element). 07:30 08:00 0.50 6,025 6,025 COMPZ RPCOM PRTS P Pressure up on the DP to 1500 psi to test the F-1 packer/CA-2 plug combination from above for 30 minutes 08:00 08:30 0.50 6,025 6,025 COMPZ RPCOM MPSP P Unset test packer and RD testing equipment. Prep to lay down DP. 08:30 10:30 2.00 6,025 3,187 COMPZ RPCOM PULD P POOH laying down 90 joints of DP to 3187'RKB(PU 10:30 12:00 1.50 3,187 45 COMPZ RPCOM TRIP P TOOH standing back DP from 3187' RKB to 45' RKB 12:00 13:00 1.00 45 0 COMPZ RPCOM BHAH P Lay down test packer, bumper sub, and B-2 hydraulic setting tool. 13:00 13:30 0.50 0 0 COMPZ RPCOM RURD P RD GBR tubing running equipment. Clean and clear the floor. 13:30 14:30 1.00 0 21 PROD1 WELLPF BHAH P PU and MU BHA#3- 'G' Lock-set RBP with running tool. 14:30 17:00 2.50 21 3,053 PROD1 WELLPF TRIP P TIH with BHA#3 to 3053'RKB(PU= 83K, SO=83K) 17:00 18:30 1.50 3,053 2,857 PROD1 WELLPF MPSP P Set'G' Lock-set RBP per Baker rep at 3042'(center of element at 3046'), release running tool, and stand back 2 stands of DP 18:30 18:45 0.25 2,857 2,857 PROD1 WELLPF SFTY P PJSM on PT RBP 18:45 19:30 0.75 2,857 2,857 PROD1 WELLPF PRTS P Line up to pressure test, purge line, and close up pipe rams. PT'G' Lock-set RBP to 1500 psi for 30 minutes(good test). Bleed off pressure and blow down TD. 19:30 00:00 4.50 2,857 2,857 PROD1 WELLPF OTHR P RU DP funnel with water hose and dump eighteen 60 lb(50')sacks of sand down the DP on top of the RBP. Page 9 of 31 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 04/22/2015 24 hr Summary Allow sand to settle and attempt to tag sand but sand is still in the DP. Work sand out of the DP and tag top of sand to 3010' RKB(31'of sand on top of RBP). Circulate the well over to 140° hot freshwater and TOOH. RU Dutch riser, RU HES E-line, and run CBL from 2800'to surface;estimated top of cement at 1995'ORKB. RIH with 7"casing jet cutter, cut the 7"casing at 1852'ORKB,and POOH. E-line tool string parted leaving 7.03'of tool string in the hole. RIH with overshot assembly to fish E-line tools,took weight at 1909'RKB, brought the pumps online, saw a pressure increase indicating the fish is in the overshot, and TOOH. Recovered 4.72'of E-line tool string. 00:00 01:00 1.00 2,857 2,857 PROD1 WELLPF OTHR P Allow sand to settle. RD DP funnel with water hose. Clean and clear the floor. SimOps: Crew change 01:00 04:30 3.50 2,857 2,965 PROD1 WELLPF OTHR T Attempt to tag top of sand but sand has not cleared the DP. Work DP to get sand out of DP. Pump a DP volume to ensure DP is clean. Blow down TD. Well out of balance acts like sand is on the falling on the backside of the DP. TIH and tag top of sand at 3010' RKB(31'of sand). Stand back one stand of DP 04:30 06:00 1.50 2,965 2,965 PROD1 WELLPF CIRC P Circulate the well over to 140°F hot freshwater at 5 BPM; ICP=280 psi, FCP=215 psi. Blow down TD. 06:00 06:30 0.50 2,965 2,965 PROD1 WELLPF SVRG P Service TD, draw works, and blocks. 06:30 08:00 1.50 2,965 0 PROD1 WELLPF TRIP P TOOH with DP from 2965' RKB to surface. 08:00 08:30 0.50 0 0 PROD1 WELLPF BHAH P Lay down RBP running tool. 08:30 09:00 0.50 0 0 PROD1 WELLPF OWFF P Observe the well for flow for 30 minutes,well static. SimOps: Clean and clear the floor. Prep for E-line. 09:00 10:30 1.50 0 0 PROD1 WELLPF FLOG P PJSM. RU Dutch riser and RU HES E-line 10:30 13:00 2.50 0 0 PROD1 WELLPF ELOG P RH with CBL and log from 2800'to surface. Estimated top of cement at 1995'ORKB. 13:00 14:30 1.50 0 0 PROD1 CSGRC'ELNE P Lay down CBL tool, MU 7"jet cutter, MU lubricator extension with pack-off. Test Dutch riser to 500 psi, no leaks 14:30 16:30 2.00 0 0 PROD1 CSGRC'ELNE P RIH with 7"jet cutter, cut 7"casing at 1852.3.'ORKB, and POOH. E-line tool string parted leaving 7.03' of tool string in the hole(7"jet cutter, variable spacer pipe,Tekco centralizer, and knuckle). 16:30 17:30 1.00 0 0 PROD1 CSGRC'ELNE P RD HES E-line, lubricator, and Dutch riser. Clean and clear the floor 17:30 18:30 1.00 0 0 PROD1 CSGRC'CIRC P Establish circulation through the OA (broke circulation at 1097 psi),shut in and blow down lines. Page 10 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:30 20:00 1.50 0 0 PROD1 CSGRC'WAIT T Wait for fishing tools. SimOps: Clean the rig. Prep the cellar for ND and changing rams. 20:00 20:45 0.75 0 0 PROD1 CSGRC'RURD T Change elevator to PU DC's. Load and strap fishing tools. RU DP tongs. 20:45 22:00 1.25 0 301 PROD1 CSGRC'BHAH T PU and MU BHA#4-Overshot assembly 22:00 22:30 0.50 301 1,909 PROD1 CSGRC'TRIP T TIH with BHA#4 to 1909'RKB and took weight. PU and SO slowly to 1947' RKB. PU to 1909'RKB. 22:30 22:45 0.25 1,909 1,909 PROD1 CSGRC'FISH T Check to see if we found the E-line fish. Screw in top drive to pump and saw a pressure increase indicating we have the E-line fish. Blow down TD. 22:45 23:30 0.75 1,947 301 PROD1 CSGRC'TRIP T TOOH with BHA#4-Overshot assembly from 1947'to surface 23:30 00:00 0.50 301 0 PROD1 CSGRC'BHAH T Stand back drill collars. Recovered part of the E-line fish(Tekco centralizer+knuckle=3.66'and 1.06'of in mandrel of the variable spacer pipe;total length=4.72'). 34/23/2015 Displaced Arctic pack by pumping 140°F heated diesel followed by 140°F hot freshwater. Installed tubing hanger with bull plug,tested to 250/3000 psi from above(good test), changed lower rams to 4-1/2"x 7" VBR's, and tested VBR's to 250/3000 psi with 7"test joint(good test). Pulled hanger, ND BOPE, ND DSA, RU Hydratight system, and ND tubing head controlling the casing growth(total casing growth 10-1/4"). NU DSA, mud cross spool, and BOPE. PU and MU rolling dog overshot assembly to fish remaining parted E-line tool string. 00:00 00:30 0.50 0 0 PROD1 CSGRC'BHAH T BHA#4-Overshot assembly and fish. 00:30 01:30 1.00 0 0 PROD1 CSGRC'RURD P RU Little Red Services(LRS)to displace Arctic pack. Blow down lines to ensure lines are clear. PT lines to 2000 psi. 01:30 01:45 0.25 0 0 PROD1 CSGRC'SFTY P PJSM with crew, LRS, and ASRC truck drivers on circulating out Arctic pack to open top tank. 01:45 03:30 1.75 0 0 PROD1 CSGRC'CIRC P Circulate out Arctic pack by pumping 160 bbls of 140°F diesel at 1.5 BPM; ICP=450 psi, FCP=375 psi to open top tank. Shut down. RD LRS. 03:30 05:00 1.50 0 0 PROD1 CSGRC'CIRC P Line up to pump hot fresh water. Pump 284 bbls 140°F freshwater at 5 BPM; ICP=697 psi, FCP=742 psi. Blow down like to open top tank 05:00 05:30 0.50 0 0 PROD1 CSGRC'OWFF P Monitor the OA for 30 minutes, 0 psi. 05:30 07:30 2.00 0 0 PROD1 CSGRC'BOPE P Install tubing hanger with bull plug on the tubing pup below tubing hanger in order to test rams after the ram swap. RILDS per Vetco rep. 07:30 08:00 0.50 0 0 PROD1 CSGRC'BOPE P RU to test tubing hanger/bull plug combination with 7"test joint to verify isolation. Page 11 of 31 0 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:00 08:30 0.50 0 0 PROD1 CSGRC'BOPE P Fill the stack. PT tubing hanger/bull plug, annular, and 5"TIW to 250/3000 psi for 5 minutes(good test). Empty stack. 08:30 10:30 2.00 0 0 PROD1 CSGRC'BOPE P Change lower pipe rams from 2-7/8" x5"VBR'sto4-1/2"x7"VBR's. Inspect all rubbers and door seals. 10:30 11:00 0.50 0 0 PROD1 CSGRC'BOPE P Test 4-1/2'x 7"VBR's with 7"test to 250/3000 psi for 5 minutes joint (good test). 11:00 12:00 1.00 0 0 PROD1 CSGRC'BOPE P BOLDS per Vetco rep, pull test joint with tubing hanger/bull plug, and lay down tubing hanger/bull plug and 7" test joint. Pull mouse hole 12:00 14:30 2.50 0 0 PROD1 CSGRC'NUND P ND BOPE,set BOPE back on stump, and ND DSA. 14:30 16:30 2.00 0 0 PROD1 CSGRC'CUTP P RU Hydratight system per PESI rep. ND the tubing head using the Hydratight system to control the growth. Casing grew 10-1/4". RD Hydratight system. Remove and inspect tubing head. Remove 7" casing pack-off. 16:30 17:30 1.00 0 0 PROD1 CSGRC'RURD P Clean and clear the cellar. Prep casing head and DSA. Bring in mud cross spool. 17:30 21:30 4.00 0 0 PROD1 CSGRC'NUND P NU DSA, mud cross spool, and BOPE. Install riser. 21:30 22:00 0.50 0 0 PROD1 CSGRC'RURD T Load and strap fishing tools 22:00 00:00 2.00 0 310 PROD1 CSGRC'BHAH T PU and MU BHA#5-Rolling Dog Overshot assembly. Had some issues making up the boot basket to overshot therefore added an extension and everything made up. 04/24/2015 TIH with rolling dog assembly, rotate down to 3011' RKB, attempt to wash down but unable to. TOOH and did not recover E-line fish. TIH with overshot,tag at 3011' RKB,TOOH, and did not recover fish. TIH with reverse circulating junk basket,wash down to 3018' RKB, TOOH,and did not recover fish. Spear 7"casing and POOH laying down 7"casing. Bottom cut joint= 11.55'and cut flared out to 8.5"OD. 00:00 02:30 2.50 310 2,976 PROD1 CSGRC'TRIP T TIH with BHA#5-Rolling Dog Overshot assembly to 2976' RKB (PU=85K, SO=85K). 02:30 03:00 0.50 2,976 3,011 PROD1 CSGRC'FISH T Rotate over fish at 10 RPM(free torque= 1K ft-lbs)to 3011' RKB. PU and tag two times at 3011' RKB. Bring the pumps on at 2 BPM= 100 psi and attempt to wash down but unable to get past 3011' RKB. Blow down TD. 03:00 05:00 2.00 3,011 310 PROD1 CSGRC'TRIP T TOOH with BHA#5 05:00 05:30 0.50 310 0 PROD1 CSGRC'BHAH T Stand back collars and lay down BHA#5. Did not recover fish. 05:30 06:00 0.50 0 302 PROD1 CSGRC'BHAH T PU and MU BHA#6-Overshot assembly. 06:00 07:30 1.50 302 3,011 PROD1 CSGRC'TRIP T TIH with BHA#6 to 3011' RKB(PU= 85K, SO=85)) Page 12 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:30 08:00 0.50 3,011 3,011 PROD1 CSGRC'FISH T Attempt to fish parted E-line tool string. Bring the pumps on at 3 BPM= 100 psi, rotate at 10 RPM, but unable to make it past 3011' RKB. 08:00 09:30 1.50 3,011 302 PROD1 CSGRC'TRIP T TOOH with BHA#6-Overshot assembly 09:30 10:00 0.50 302 0 PROD1 CSGRC'BHAH T Stand back collars and lay down BHA#6. Did not recover fish. 10:00 11:00 1.00 0 306 PROD1 CSGRC'BHAH T PU and MU BHA#7-Reveres Circulating Junk Basket(RCJB) assembly. 11:00 13:00 2.00 306 3,011 PROD1 CSGRC'TRIP T TIH with BHA#7 to 3011' RKB(PU= 85, SO=85). 13:00 14:30 1.50 3,011 3,018 PROD1 CSGRC'MILL T PU, bring the pumps online at 5 BPM =395 psi, rotate at 10 RPM, and tag at 3011' RKB. Dry mill from 3011'to 3021' RKB at 60 RPM with 2-6K torque. Drop 7/8"to divert flow on RCJB. Wash down from 3011'to 3018' RKB at 8 BMP= 1215 psi, rotating 60 RPM with 6K torque. Circulate bottoms up to clean the hole. 14:30 16:00 1.50 3,018 306 PROD1 CSGRC'TRIP T TOOH with BHA#7-RCJB assembly. Halliburton Engineer mentioned that the spacer tube we were trying to fish was aluminum not steel and the OD was 1.5"not 1.69"as listed on the tool diagram. 16:00 18:00 2.00 306 0 PROD1 CSGRC'BHAH T Stand back collars and lay down BHA#7. Did not recover fish. Clean and clear the floor of Baker fishing tools. 18:00 19:00 1.00 0 0 PROD1 CSGRC'RURD P RU GBR casing pulling equipment. 19:00 19:15 0.25 0 0 PROD1 CSGRC'SFTY P PJSM for spearing casing and POOH laying down 7"casing. 19:15 20:00 0.75 0 1,825 PROD1 CSGRC'BHAH P PU and MU 7"casing spear. Spear casing and pull to the rig floor(pulled at 60 K over). 20:00 20:30 0.50 1,825 1,825 PROD1 CSGRC'OTHR P Remove 7"casing slips. 20:30 00:00 3.50 1,825 0 PROD1 CSGRC'PULL P Lay down top 7"cut joint with 7" casing spear. POOH laying down 7" casing. Bottom cut joint 11.55' long and cut flared to 8.5"OD. 34/25/2015 TIH with 9-5/8"scraper to casing stub at 1850' RKB, circulate hole clean, and TOOH. TIH with bladed junk mill assembly to 3018' RKB,dry mill on aluminum parted E-line tool string,wash down to 3022' RKB, and TOOH. TIH with RCJB to 3023'RKB,wash down to clean up aluminum parted E-line tool string debris to 3035' RKB,and TOOH (recovered several large chunks of aluminum). 00:00 01:30 1.50 0 0 PROD1 CSGRC'RURD P RD GBR casing pulling equipment. Clean and clear the floor. Load Baker tools for scarper run. 01:30 02:30 1.00 0 308 PROD1 CSGRC'BHAH P PU and MU BHA#8-9-5/8"scraper assembly Page 13 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 04:00 1.50 308 1,845 PROD1 CSGRC'TRIP P TIH with BHA#8 and tag casing stub at 1850' RKB with 5K down. PU to 5' to 1840'. 04:00 05:30 1.50 1,845 1,845 PROD1 CSGRC'CIRC P Pump 24 bbls flow pro sweep followed by 290 bbls of 140°F hot freshwater at 8 BPM=445 psi. Blow down TD. 05:30 06:30 1.00 1,845 308 PROD1 CSGRC'TRIP P TOOH with BHA#8 from 1845'to 308'RKB. 06:30 07:30 1.00 308 0 PROD1 CSGRC'BHAH P Stand back collars and lay down BHA#8-9-5/8"scraper assembly. 07:30 08:30 1.00 0 0 PROD1 CSGRC'BHAH P PU 7"spear and cut joint. Break out spear, lay down cut joint, service break spear, and lay down spear. 08:30 09:30 1.00 0 0 PROD1 CSGRC'BHAH T Bring in and strap tools needed for junk mill run. 09:30 10:30 1.00 0 311 PROD1 CSGRC'BHAH T PU and MU BHA#9-Bladed Junk Mill assembly to break up aluminum parted E-line tool string. 10:30 12:00 1.50 311 2,997 PROD1 CSGRC'TRIP T TIH with BHA#9 to 2997'RKB(PU= 85, SO=85) 12:00 12:30 0.50 2,997 3,018 PROD1 CSGRC'CIRC T Attempt to wash down at 3 BPM = 160 psi, set 12K down at 3018' RKB, PU, and circulate bottoms up at 10 BPM=760 psi. 12:30 14:00 1.50 3,010 3,022 PROD1 CSGRC'MILL T Dry mill from 3018'to 3020' RKB, rotating at 80 RPM,free torque= 1K ft-lbs, but unable to keep weight on bit(washing away sand). PU and wash down to 3022' RKB at 3 BPM= 160 psi. PU and continue to dry mill from 3020'to 3022'with minimal torque and no weight on bit. 14:00 15:30 1.50 3,022 3,022 PROD1 CSGRC'SLPC P Slip&cut 78'of drilling line. Service draw works, crown, TD, and calibrate block height. 15:30 16:45 1.25 3,022 311 PROD1 CSGRC'TRIP T TOOH with BHA#9. 16:45 17:45 1.00 311 0 PROD1 CSGRC'BHAH T Stand back collars and lay down BHA#9-Bladed Junk Mill assembly 17:45 18:30 0.75 0 305 PROD1 CSGRC'BHAH T PU and MU BHA#10- RCJB assembly to clean up aluminum debris from parted E-line tool string. 18:30 20:15 1.75 305 3,023 PROD1 CSGRC'TRIP T TIH with BHA#10 and tag at 3023' RKB with 10K down 20:15 21:00 0.75 3,023 3,035 PROD1 CSGRC'WASH T Wash down from 3023'to 3028' RKB at 8 BPM= 1215 psi. PU, rotate at 20 RPM, and work the DP up/down 20'at 8 BPM= 1215 psi. PU and ciculate bottoms up. SO and tag top of sand at 3035' RKB. 21:00 22:30 1.50 3,034 305 PROD1 CSGRC'TRIP T Blow down TD and TOOH with BHA #10. 22:30 00:00 1.50 305 0 PROD1 CSGRC'BHAH T Lay down 9 DC's and lay down BHA #10- RCJB assembly. Recovered several large chunks of aluminum. Need to make another run. Page 14 of 31 9 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04/26/2015 24 hr Summary TIH with RCJB assembly to 3034' RKB,wash down to clean up aluminum parted E-line tool string debris to 3039' RKB, and TOOH(recovered two small chunks of aluminum). TIH with'G' Lock-set retrieving head,tag sand at 3033' RKB, circulate the well over to 9.4 ppg NaCI, and wash down to plug at 3041' RKB. Release plug per Baker rep, circulate out sand, and TOOH (encountered 10-15K over pull on the first couple casing collars). Changed out saver sub and PT to 3000 psi(good test). Single in the hole with RCJB assembly on DP to 3189' RKB and TIH from 3189'to 6128' RKB. Wash down to top of F-1 packer at 6138' RKB and circulate out sand. 00:00 00:15 0.25 0 27 PROD1 CSGRC'BHAH T PU and MU BHA#11 -RCJB assembly without DC's. 00:15 01:30 1.25 27 3,034 PROD1 CSGRC'TRIP T TIH with BHA#11 and tag at 3034' RKB with 5K down(PU =80K, SO= 80K). 01:30 02:00 0.50 3,034 3,039 PROD1 CSGRC'WASH T Wash down from 3034'to 3039' RKB at 10 BPM= 1650 psi, rotating at 10 RPM. 02:00 03:30 1.50 3,039 27 PROD1 CSGRC'TRIP T Blow down TD and TOOH with BHA #11. Change elevators. 03:30 04:45 1.25 27 0 PROD1 CSGRC'BHAH T Lay down BHA#11 -RCJB assembly without DC's. Clean and clear the floor of Baker fishing tools. Recovered two small chunks of aluminum. 04:45 05:00 0.25 0 13 PROD1 CSGRC'BHAH P PU and MU BHA#12- 'G' Lock-set retrieving head. 05:00 06:00 1.00 13 3,028 PROD1 CSGRC'TRIP P TIH with BHA#12,tag sand at 3033' RKB(PU =80K, SO=78K), and PU 5'. 06:00 06:30 0.50 3,028 3,028 PROD1 CSGRC'CIRC P Circulate the well from freshwater to brine by pumping 20 bbls flow pro sweep followed by 9.4 ppg NaCI until clean brine is seen at surface at 8 BPM =440 psi. 06:30 08:00 1.50 3,028 3,041 PROD1 CSGRC'WASH P Wash down from 3028'to 3038'RKB circulating out sand at 8 BPM =440 psi. Slow the pumps down to 3 BPM = 100 psi and wash down top of'G' Lock-set RBP at 3041' RKB. Circulate until returns are clean. 08:00 08:45 0.75 3,041 3,021 PROD1 CSGRC'MPSP P Release'G' Lock-set RBP per Baker rep. Lay down 1 joint and at 3021' RKB 10K overpull. PU up joint and go back down to 3041' RKB wiith no issues. Lay down 1 joint and again 10K overpull at 3021' RKB. 08:45 09:15 0.50 3,021 3,021 PROD1 CSGRC'SVRG P Sevice TD and draw works 09:15 09:45 0.50 3,021 3,021 PROD1 CSGRC'RGRP T Change out saver sub and test to 3000 psi(good test) 09:45 10:00 0.25 3,021 3,041 PROD1 CSGRC'PULD P PU single and RIH to 3041' RKB. 10:00 10:30 0.50 3,041 3,021 PROD1 CSGRC'CIRC P Circulate at 3 BPM= 100 psi and work the pipe. Worked through 3021' RKB with 15K overpull but did not see a pressure increase. 10:30 13:30 3.00 3,021 27 PROD1 CSGRC'TRIP P TOOH with BHA#12- 'G' Lock-set retrieving head. 13:30 14:00 0.50 27 0 PROD1 CSGRC'BHAH P Lay down BHA#12. Clean and clear the floor. Page 15 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:00 15:00 1.00 0 0 PROD1 CSGRC'BHAH T Bring Baker tools to the rig floor and load(9)4-3/4" DC's in the pipe shed. 15:00 15:30 0.50 0 0 PROD1 CSGRC'SFTY T PSJM for PU RCJB cleanout assembly 15:30 17:00 1.50 0 332 PROD1 CSGRC'BHAH T PU and MU BHA#13-RCJB cleanout assembly. 17:00 17:30 0.50 332 332 PROD1 CSGRC'SVRG P Service Iron Roughneck and install new hose on draw works(grease line to brake bearing). 17:30 21:00 3.50 332 3,189 PROD1 CSGRC'PULD T Single in the hole with BHA#13 on 4"DP to 3189' RKB. 21:00 22:45 1.75 3,189 6,128 PROD1 CSGRC'TRIP T TIH with BHA#13 from 3189'to tag at 6128' RKB. 22:45 00:00 1.25 6,128 6,138 PROD1 CSGRC'WASH T Wash down at 8 BPM = 1780 psi to top of F-1 packer at 6138' RKB with 3K down. PU,work DP up/down 5', circulate bottoms up(getting sand across the shakers). Build hi-visc I sweep while contining to circulate out sand. 04/27/2015 Open pump out sub and pump 20 bbl hi-visc sweep followed by 9.4 ppg at 10 BPM to circulate out sand and debris. POOH laying down DP, lay down 9 DC's and lay down RCJB assembly. BOPE diverter function test with 5-1/2"joint of casing. Closing time: Annular=23 seconds; Lower Rams(4-1/2"x 7"VBR's)=6 seconds. PU, MU, and RIH with E-22 Anchor Seal Assembly, Seal Bore Extension, and 5"TAM Cementing Port Collar on 5-1/2" 15.5#, L-80 BTCM SCC casing per tally placing centralizers per CemCADE. Depth at midnight=6080'RKB. 00:00 01:00 1.00 6,138 6,138 PROD1 CSGRC'CIRC T Drop dart to open pump out sub (sheared at 2400 psi)and pump 20 bbls hi-visc sweep following with 9.4 ppg brine at 10 BPM= 1620 psi. Blow down TD. 01:00 05:00 4.00 6,138 332 PROD1 CSGRC'PULD T POOH laying down DP. 05:00 07:30 2.50 332 0 PROD1 CSGRC'BHAH T Lay down 9 DC's and BHA#13- RCJB cleanout assembly. Recovered several small chunks of aluminum. 07:30 08:30 1.00 0 0 PROD1 CSGRC'BHAH T Clean and clear the floor of all Baker fishing tools. 08:30 10:30 2.00 0 0 PROD1 CASING RURD P Load and RU GBR casing running equipment. MU 5-1/2"crossover to TIW and prep for running 5-1/2" casing. 10:30 11:00 0.50 0 0 PROD1 CASING BOPE P BOPE diverter function test with 5-1/2"joint of casing. Closing time: Annular=23 seconds Lower Rams(4-1/2"x 7"VBR's)=6 seconds *BOPE is considereda diverter due to the surface casing leak at 32' ORKB.* Page 16 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 00:00 13.00 0 6,080 PROD1 CASING PUTB P PU, MU, and RIH with E-22 Anchor Seal Assembly, Seal Bore Extension,and 5"TAM Cementing Port Collar on 5-1/2" 15.5#, L-80 BTCM SCC casing per tally placing centralizers per CemCADE. Depth at midnight=6080' RKB 04/28/2015 Continue to RIH with 5-1/2"casing to 6,134', tag up 3.5' high. Pick up,anchor did not latch. Attempt to latch anchor, observeve increase in pump pressure as seals engage. Unable to get anchor to latch. Discuss options with town. Pressure test casing to 3000 psi for 10 minutes-good. N/D BOPE and install emergency slips. Cut excess casing. Install and test packoffs 250/3000 psi. N/U tubing head and BOPE. Rig up and test BOPE's. Right to witness test waived by Bob Noble. 00:00 01:00 1.00 6,080 6,135 PROD1 CASING PUTB P RIH with final joint of 5-1/2"casing. PU and MU 3 space out pups(PU= 120k, SO= 110K) 01:00 04:00 3.00 6,135 6,135 PROD1 CASING HOSO T Tagged 3.5' high with 10K down, PU, and anchor is not latched up. Change out 10'pup to 6'. PU and MU crossovers to get from 5-1/2" back to 4"HT to screw in the TD. Roll the pumps and see a pressure increase indicating the seals are engaging. Pressure up to 1000 psi, 2000 psi, and 3000 psi to latch anchor but unsuccessful. Rotate the string 1/2 turn and attempt to latch anchor without success. 04:00 06:00 2.00 6,135 6,135 PROD1 CASING WAIT T Consult with Baker shop and town engineer. Wait on orders 06:00 07:00 1.00 6,135 6,135 PROD1 CASING PRTS P Rig up and Pressure test 5-1/2" casing to 3000 psi for 10 minutes- good. 07:00 09:00 2.00 6,135 6,135 PROD1 CASING HOSO P Drain stack and break BOPE, pick up to install emergency slips. 09:00 11:30 2.50 0 0 PROD1 CASING HOSO P Set emergency slips. Cut excess 5-1/2"casing with Wach's cutter. Total length cut=30.76'. 11:30 14:30 3.00 0 0 PROD1 CASING HOSO P Pull riser. nipple down DSA and set BOPE on stump. Load tubing spool in cellar. 14:30 17:30 3.00 0 0 PROD1 CASING WWSP P Clean up 5-1/2"stump cut. Install packoff and test 250/3000 for 10 minutes-good. Install IA working valves. 17:30 18:00 0.50 0 0 PROD1 CASING SFTY P AAR with crew on cellar work. 18:00 19:30 1.50 0 0 PROD1 CASING NUND P N/U BOPE 19:30 21:30 2.00 0 0 PROD1 CASING BOPE P Change out lower pipe rams from 4-1/2"x 7"VBR's to 2-7/8"x 5" VBRs 21:30 22:45 1.25 0 0 PROD1 WHDBO RURD P Rig up to test BOP's. Install hanger with bull plug. Page 17 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:45 00:00 1.25 0 0 PROD1 WHDBO BOPE P Test BOPE's 250/3000 psi with 2-7/8"and 3-1/2"test joints. Right to witness waived by Bob Nobles. 1. Blind rams; Demco Kill; chokes 1, 2, 3, 16-pass. 2. HCR kill; Chokes 4, 5,6-pass. 34/29/2015 Continue to test BOPE 250/3000 psi; right to witness waived by Bob Noble. Accumulator test: Starting pressure 2950 psi, final 1600 psi. First 200 psi recharge 35 seconds,full recharge 162 seconds. Rig down testing equipment and rig up GBR. Pick up Tam Port tool and single in the hole. Locate Tam Port Collar and open after multiple attempts. Break circulation, isolation cups leaking. Unsuccessfully attempt to get isolation cups to hold. Attempt to verify Tam Port tool is in closing position-unsuccessful. Drop down and work torque down mutliple times. Tam Port closed 3-5K early. Open Tam Port and break circulation. Isolation cups still leaking. Discuss options with town. 00:00 05:30 5.50 0 0 PROD1 WHDBO BOPE P Continue to test BOPE 250/3000 psi. Right to witness waived by Bob Noble: 3. Manual Kill; Chokes 7, 8,9-pass 4. Chokes 10, 11 -Pass 5. Chokes 12, 13, 14-grease choke 12, 13-pass 6. UPR with 3.5"TJ; HT40 TIW; IBOP; Choke 15-pass 7. Annular with 3.5"TJ; HCR choke, HT 40 TIW-pass 8. LPR with 3-1/2"TJ, Manual IBOP- pass 9. LPR with 2-7/8"TJ, HT40 Dart valve-pass 10. UPR with 2-7/8"TJ; Manual Choke 11.Annular with 2-7/8"TJ; outer test spool valve; HT40 Dart 12. Inner test spool-pass Accumulator test: Starting pressure 2950 psi, final 1600 psi. First 200 psi recharge 35 seconds, full recharge 162 seconds. 6 N2 bottles at 2033 psi 05:30 06:30 1.00 0 0 PROD1 WHDBO RURD P Rig down testing equipment. M/U landing joint and pull hanger. 06:30 08:00 1.50 0 0 PROD1 CEMEN-RURD P Rig up GBR, change out pipe handling tools 08:00 08:30 0.50 0 0 PROD1 CEMEN-BHAH P Pick up and make up 5"Tam Port tool. 08:30 17:00 8.50 0 6,094 PROD1 CEMEN-PULD P Run in hole with 2-7/8 HT PAC pipe from pipe shed Page 18 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 19:00 2.00 6,094 6,096 PROD1 CEMEN-OTHR T Locate Tam Port collar 10'deep. Attempt to open Tam Port, stack 8K down with 200 psi. Observe pressure bleed. Attempt to circulate through Tam Port-no flow out the OA;does not appear to be open. Attempt to align and open Tam Port. Pick up 20'and relocate on depth. Slack off 8K and open Tam Port. Circulate through Tam Port-only partial circulation through collar with majority past the sealing cups. 19:00 20:00 1.00 6,096 6,096 PROD1 CEMEN-RURD T Rig up head pin for cement job. Discuss options with town. 20:00 00:00 4.00 6,096 6,096 PROD1 CEMEN-OTHR T Close OA and attempt to pressure up on sealing cups to get them to hold. Pressure up to 500 psi, still leaking past. Shut down. Pick up on pipe to ensure Tam Port in closing position;designed to close at 5-8K over pull. No over pull observed. Slack off and rotate 1/4 turn and retry multiple times with no succuss. Slack off and unable to go past opening position, attempt mulitple times prior to success. Pick up and observe 2500 ft-lbs overpull indicating in closing position. Slack off to opening position and break circulation-no circulation Tam Port closed early, cups holding. Re-open Tam Port and break circulation-sealing cups leaking by. 04/30/2015 Close Tam Port Collar. POOH with TAM Port tool. Inspect tool, observe scarring on tool, lower isolation cup damaged and pushed up tool. RIH with reverse circulating basket to 6,033'. Establish parameters,wash down from 6,033'to 6,070'. 00:00 02:30 2.50 6,096 6,096 PROD1 CEMEN-OTHR T Close annular and establish circulation 2 bpm 540 psi through OA. Discuss options with town. Pick up on Tam Port tool,collar closed correctly. Establish circulation to verfy closed, isolation cups leaking by at 2 bpm 430 psi. 02:30 08:30 6.00 6,096 0 PROD1 CEMEN-PULD T POOH with Tam Port tool laying down 2-7/8" HT PAC. 08:30 10:00 1.50 0 0 PROD1 CEMEN BHAH T Lay down TAM PORT tool. scarring observed on tool Lower Isolation cup damaged and shifted up on tool. Break down choke on tool. 10:00 10:30 0.50 0 0 PROD1 CEMEN-SVRG T Inspect and service top drive 10:30 14:30 4.00 0 0 PROD1 CEMEN-WAIT T Discuss options with town. Wait on RCJB from Baker Sim Ops: service draw works, service crown. Clean and clear rig floor. Page 19 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:30 16:00 1.50 0 0 PROD1 CEMEN-BHAH T Pick up reverse circulating junk basket. 16:00 23:00 7.00 0 6,033 PROD1 CEMEN-PULD T RIH with RCJB BHA picking up 2-7/8"HT PAC pipe from the shed to 6033'. 23:00 00:00 1.00 6,033 6,070 PROD1 CEMEN-WASHT Establish parameters. PUW 92K, SOW 88K. Pump pressure 2700 psi at 4.5 bpm. Free torque 700 ft-lbs at 20 rpms. Wash down from 6,033'to 6,070'. 35/01/2015 Continue to wash down to 6,100'with RCJB. POOH, nothing recovered in boot baskets or RCJB. Pick up Tam Port Tool. RIH, open Tam Port Collar. Establish circulation out OA. Cement as per detail. Pick up and close Tam Port, PT Tam Port and confirm close. Observe IA dropping, flow out tubing. PT Tam Port to verify closed. Slack off and attempt to shear choke,will not shear. Begin circulating 3 x annular volume at 4.5 bpm, 3400 psi. 00:00 01:00 1.00 6,070 I 6,100 PROD1 CEMEN-WASH T Continue to wash down to 6,105'at 4 bpm 2700 psi. Circulate hole volume. Monitor well for 10 minutes. Blow down top drive 01:00 06:00 5.00 6,100 0 PROD1 CEMEN-PULD T POOH with RCJB laying down 2 7/8" HT PAC pipe. 06:00 07:30 1.50 0 0 PROD1 CEMEN BHAH T Break out RCJB. Nothing recovered. 07:30 09:00 1.50 0 0 PROD1 CEMEN BHAH T Pick up Tam Port tool. Break connection and install shear pins to increase choke shear to 3,400 psi. 09:00 18:00 9.00 0 6,093 PROD1 CEMEN-PULD T Run in hole 2-7/8"HT PAC singling in from pipe shed to 6093'. Observe dogs engage Tam Port Collar. Establish circulation,Tam Port open, isolation cups leaking by. Increase circulation to 4 bpm 1400 psi and observe seals engage. 18:00 19:15 1.25 6,093 6,093 PROD1 CEMEN RURD P Rig up cement lines with side door entry sub. 19:15 20:15 1.00 6,093 6,093 PROD1 CEMEN"CIRC P Close annular and establish circulation at 3 bpm 1400 psi. 20:15 22:30 2.25 6,093 6,093 PROD1 CEMEN CMNT P PJSM. Flood lines from cement truck. PT lines to 3000 psi. Cement as per deatail at 3 bpm 1800 psi: 10 bbls fresh water, 18.5 bbls 13.0 ppg Extended slurry, 21 bbls 15.8 ppg Class G cement, 10 bbls fresh water. Swap over to rig pumps and displace cement with 17.5 bbls seawater slowing pumps down to 1 bpm 2000 psi. 22:30 23:00 0.50 6,093 6,091 PROD1 CEMEN CMNT P Shut down and pick up to close Tam Port Collar with 8K overpull, maintaining drill pipe pressure at 1150 psi. Pressure up to 2200 psi for 5 minutes-pressure held. 23:00 23:30 0.50 6,091 6,091 PROD1 CEMEN PRTS P Open annular. Observe flow out tubing, IA falling. Shut in tubing, IA becomes static. PT Tam Port to 2300 psi, holding,slight ooze out OA. Page 20 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:30 00:00 0.50 6,098 6,098 PROD1 CEMEN-CIRC T Slack off 7'and attempt to shear out choke. Isolation cups not holding. Stage pumps up to 3700 psi, no shear. Circulate 3times annular volume 4.5 bpm, 3400 psi. 05/02/2015 Continue to circulation 3 times annular volume 4.5 bpm 3400 psi. Shut down and observe flow, suspect U-tube. Pressure test Tam Port and verify it's closed. Break out head pin. Pick up above Tam Port Collar, attempt to circulate, unable to. POOH to 5,950'erratic torque building to max pull. Continue to attempt and gain circulation and slack off, unable to. Call out SLB E-Line crew to run free point tool. 00:00 00:45 0.75 6,098 6,098 PROD1 CEMEN CIRC T Continue circulating 3 times annular volume at 4.5 bpm 3400 psi. 00:45 02:15 1.50 6,098 6,098 PROD1 CEMEN RURD P Slack off to rig down head pin. Break out hoses, observe flow out the tubing and IA, OA dead. Shut in. PT casing to 2000 psi, bled to 570 psi in one minute, no flow out OA. Open well. IA,Tubing, OA static. Pick up and position isolation cups around Tam Port Collar. Pressure up on Tam Port collar to 2500 psi, no flow out the OA. 02:15 03:30 1.25 6,098 6,050 PROD1 CEMEN RURD P Break out head pin and circulation. POOH with Tam Port tool to 6,050', isolation cups inside the 5-1/2" casing. Attempt to break circulation, no circulation pressure up to 3500 psi to try and shear choke, no circulation. 03:30 04:30 1.00 6,050 5,950 PROD1 CEMEN-PULD P POOH with Tam Port tool, observe 5-15K erratic drag on first joint laid down, Second joint 20-25K erratic torque spiking to 30K, attempt to circulate while POOH. Pressuring up no circulation. Rotate 15 rpms 1200 ft-lbs of torque. Up to 40k over pull observed on third joing laid down, still erratic,still no circulation. Attempt to continue out of the hole, unable to. Attempt to slack off, unable to. Continue to attempt and gain circulation with up to 4100 psi pump pressure. Unable to. Pull 88K over, slack off string weight, unable to move pipe. 04:30 12:00 7.50 5,950 5,950 PROD1 CEMEN-WAIT T Continue to work stuck pipe, discuss options with Town, E-Line and Baker Fishing. 12:00 00:00 12.00 5,950 5,950 PROD1 CEMEN WAIT T Wait on Ad-Hoc crew from SLB E-Line. Rig up and prep for E-Line work. Install long bails, clean and organize rig, service rig. 05/03/2015 Wait on SLB Ad-Hoc crew from deadhorse. Spot E-Line unit and rig up. RIH with free point tool, not acting correct. POOH with free point tool and change out. RIH and determine stuck point between 5287 and 5317'. Tag up in 2 7/8"drill pipe at 5,360'. POOH. Make up split shot. RIH and fire split shot at collar at 5,263'and POOH. Attempt to work pipe free, not free. Wait on severity tool from Deadhorse. Page 21 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:30 1.50 5,950 5,950 PROD1 CEMEN-WAIT T Continue to wait on Ad-Hoc E-Line crew from deadhorse. On location at 01:30 01:30 02:45 1.25 5,950 5,950 PROD1 CEMEN-FLOG T Spot E-line truck and rig up. 02:45 07:00 4.25 5,950 5,950 PROD1 CEMEN-FLOG T RIH with SLB free point. Calibrate at 200'. Take reading from 2000'to 5000'. Tool does not appear to be functioning correctly. POOH to 1000' and attempt to read tool, still not reading correctly. POOH 07:00 10:00 3.00 5,950 5,950 PROD1 CEMEN-ELOG T Change out E-Line free point tool. RIH and determine free pipe between 5,287'and 5,317'. Tag up in 2-7/8" DP at 5,360' 10:00 13:30 3.50 5,950 5,950 PROD1 CEMEN-WAIT T Wait on SLB Split shot tool from Deadhorse. 13:30 17:30 4.00 5,950 5,950 PROD1 CEMEN ELOG T M/U Split shot and RIH to 5,263'. Pick up 15K over and fires split shot. POOH with split shot 17:30 20:00 2.50 5,950 5,950 PROD1 CEMEN OTHR T Attempt to pull pipe free. Work up to max pull 180K with no movement. Attempt to circulate, no circulation. Attempt to work torque down. Pipe not free. 20:00 00:00 4.00 5,950 5,950 PROD1 CEMEN WAIT T Wait on SLB tools from deadhorse. No back up tool for Magnet loacator/firing head for split shot Severity tool detanator has too large of OD. Work on building extension for severity tool. 05/04/2015 Slip and cut drilling line. M/U SLB E-Line Severity tool. RIH to 5,150'and fire, observe 5K loss in overpull. POOH; E-line tool left downhole.. Work pipe, unable to come free. Establish circulation and circulate pipe. Rig up and RIH with E-Line severity tool,tag up at 4,026'-E-line tool. Call out Slickline. Rig up and RIH to fish E-Line tool. 00:00 01:30 1.50 5,950 5,950 PROD1 CEMEN-WAIT T Wait on SLB tools from deadhorse. No back up tool for Magnet loacator/firing head for split shot Severity tool detanator has too large of OD. Work on building extension for severity tool. 01:30 03:30 2.00 5,950 5,950 PROD1 CEMEN SLPC T Slip and cut drilling line. Service rig. 03:30 07:30 4.00 5,950 5,950 PROD1 CEMEN-ELNE T SLB E-line tools on location. Build tools. RiH with severity tool to 5150'. String in tension 30K over. Fire severity tool, observe 5K drop in weight. POOH; E-Line tool string did not come out of the hole. R/D E-Line 07:30 17:00 9.50 5,950 5,950 PROD1 CEMEN OTHR T Work pipe up to max pull of 180 K. Establish circulation, 2 bpm 220 psi. Stage pumpes up to 3 bpm 707 psi. Continue to work pipe, not free. 17:00 19:30 2.50 5,950 5,950 PROD1 CEMEN-ELNE T Run in hole with E-Line severity tool, tag up at 4,026'. Suspect first severity tool Page 22 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:30 20:30 1.00 5,950 5,950 PROD1 CEMEN-ELNE T Discuss options with Town. Discuss options with HES slickline and SLB E-Line. Call out slickline to fish out E-Line tool. 20:30 22:00 1.50 5,950 5,950 PROD1 CEMEN-ELNE T POOH with E-Line. R/D and pull unit out of the way. 22:00 00:00 2.00 5,950 5,950 PROD1 CEMEN-ELNE T PJSM, spot slick line rig up sheaves. Pick up tools. 05/05/2015 RIH with Slickline'S'tool to retrieve E-Line tools to 4,033' ELM. Tag up, does not appear to be E-Line tools. POOH. M/U 1.25"LIB and RIH to 5,000'with no issues. POOH. R/U E-Line with severity tool to 4,782' ELM. Fire severity tool. Pipe free. Attempt to POOH with E-Line, unable to travel. Pull max safe pull. Discuss options with E-Line, call out'T'-bar. Make up'T' bar to E-line above stump and latch in elevators, secure. Pick up and sever E-Line from socket with Top Drive. POOH with E-Line. POOH with 2-7/8"drill pipe. 00:00 04:00 4.00 5,950 5,950 PROD1 CEMEN-SLKL T RIH with slickline, max tool OD 1.42",observe several collars on the way in. Gently work through. Tag up at 4,033'ELM,does not appear to be E-Line tool string. POOH. M/U 1.25"OD lead impression block. RIH to 5,000'with no issues. POOH. R/D slickline. 04:00 09:00 5.00 5,950 4,787 PROD1 CEMEN-ELNE T R/U E-Line and RIH with 1.38"OD severing tool to 4900'. Log up and correlate across a collar at 4,787'. Fire string shot. Observe string weight fall off. Good indication of cut. 09:00 10:30 1.50 4,787 4,787 PROD1 CEMEN-ELNE T Attempt to POOH with E-Line. Stuck at first collar, unable to move up or down. Pull to max safe pull, no movement. Discuss options with town. SLB call out for'T'-Bar. Discuss'T'-bar operations with Nabors and Schlumberger. 10:30 12:00 1.50 4,787 4,787 PROD1 CEMEN WAIT T Wait on'T' Bar from Deadhorse 12:00 13:30 1.50 4,787 4,787 PROD1 CEMEN-ELNE T Rig up'T'-bar. Clamp'T Bar to E-Line above stump. Latch in elevators and secure with wire sling. Pick up on elevators and Part E-Line with top drive,4K pull. 13:30 14:30 1.00 4,787 4,787 PROD1 CEMEN-ELNE T POOH with E-Line 14:30 15:30 1.00 4,787 4,787 PROD1 CEMEN ELNE T Rig down E-Line. 15:30 16:00 0.50 4,787 4,787 PROD1 CEMEN-SFTY T Derrick Inspection. 16:00 16:30 0.50 4,787 4,787 PROD1 CEMEN RURD T Rig up GBR to pull 2-7/8"drill pipe out of the hole 16:30 00:00 7.50 4,787 0 PROD1 CEMEN PULD T POOH with 2-7/8"drill pipe. 151 joints recovered from 4787'. E-Line tools recovered in last joint. 05/06/2015 Rig up and test BOPE 250/3000 psi. Lou Grimaldi witnessed partial test. Perform Accumulator test:starting pressure 2950,final 1650. First 200 recharge 40 seconds final 166 seconds. 5N2 at 2116 psi. Change out HCR choke valve during test. Rig up and test 5-1/2"casing-fail. Change out UPR to 3-1/2"x 6"VBR's and test on 5 1/2"and 3 1/2"test joints-fail. Page 23 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:00 2.00 0 0 PROD1 WHDBO RURD P R/U to test BOPE's. Make up landing joint to tubing hanger. Land hanger, RILDS. Set TWC. Fill choke and BOPE stack. 02:00 10:00 8.00 0 0 PROD1 WHDBO BOPE P Test BOPE 250/3000 psi. Test witnessed by Lou Grimaldi. 1. Blind rams; Kill demco; Chokes 1, 2, 3 and 16-pass 2. IBOP; Chokes 4, 5,6-pass 3. HCR Kill; manual IBOP; Chokes 7, 8, 9-pass 4. Super and bean choke, Manual Kill-HCR choke leaking,grease and retest-pass 5. Chokes 10, 11 -HCR Choke leaking-fail 6. UPR with 3-1/2"TJ, Dart valve, Manual choke, Manual Kill-pass 7. LPR with 3-1/2"TJ,TIW valve -pass. 8. Annular to 250/2500 psi-pass Accumulator test: Starting pressure 2950 psi, Final pressure 1650 psi. First 200 psi recharge 40 seconds, full recharge 166 seconds 6 N2 bottles at 2116 psi 10:00 12:00 2.00 0 0 PROD1 WHDBO RGRP T Change out HCR choke valve. 12:00 14:00 2.00 0 0 PROD1 WHDBO BOPE P Continue testing BOPE to 250/3000 psi. This portion of the test waived by Lou Grimaldi. 9. Chokes 8, 12, 13, 14-pass 10. Choke 15, 3-1/2"TIW 11. HCR choke-pass 12. Outer test spool-pass 13. Inner test spool-pass 14:00 15:30 1.50 0 0 PROD1 WHDBO RURD P Rig down testing equipment. Blow down choke and kill lines. L/D test joing. Pull TWC and tubing hanger 15:30 18:30 3.00 0 0 PROD1 PLUG PRTS T Rig up and test 5-1/2"casing. Test to 3500 psi; lost 600 psi in 20 minutes, 180 psi in an additional 20 minutes. Attempt to retest with similar results. 18:30 19:00 0.50 0 0 PROD1 PLUG RURD T Rig down testing equipment. Discuss options with town. Call out HES E-Line unit-timed out until 02:00. 19:00 20:30 1.50 0 0 PROD1 PLUG BOPE T Close blinds and change out upper pipe rams to 3-1/2"x 6"VBR's. 20:30 22:30 2.00 0 0 PROD1 PLUG BOPE T R/U to test upper pipe rams. 22:30 00:00 1.50 0 0 PROD1 PLUG BOPE T Test Upper pipe rams with 5.5"test joint 250/3000 psi-pass. Test upper pipe rams with 3.5"test joint-fail leaking by rams Page 24 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 35/07/2015 24 hr summary Pull 3-1/2"x 6"UPR. Change out seal and packing. Install UPR and test with 5.5"; 3.5"test joints 250/3000 psi pass. Test annular on 5.5"test joint-pass. Rig up dutch riser and E-Line. Log hole with Cement Bond Log from 4700'to 1300'. Make up Jet cutter. RIH and cut 5.5"casing at 3,550'. POOH with E-line and attempt to circulate, unsuccessful. E-Line timed out,Adhoc crew from deadhorse unavailable. Rig down E-Line. Rig up and test UPR, LPR, and annular with 4"test joint-pass. Rig down testing equipment. 00:00 01:00 1.00 0 0 PROD1 PLUG RURD T Lay down test joint. Suck out stack. 01:00 04:00 3.00 0 0 PROD1 PLUG RGRP T Remove 3-1/2"x 6"VBR upper pipe rams. Install new rubber elements. 04:00 05:00 1.00 0 0 PROD1 PLUG RGRP T Install 3-1/2"x 6"VBR's in upper pipe rams. Simops: Halliburton E-Line crew on location at 04:30, spot unit. 05:00 08:00 3.00 0 0 PROD1 PLUG BOPE T Test UPR with 3.5"test joint 250/3000-pass Test UPR with 5.5"test joint 250/3000-pass Test annular with 5.5"test joint 250/2500-pass Simops-Halliburton prep tools and unit. 08:00 08:30 0.50 0 0 PROD1 PLUG BOPE T Rig down test equipment. Drain stack and pull hanger 08:30 09:30 1.00 0 0 PROD1 PLUG QEVL T Rig up dutch riser. 09:30 11:00 1.50 0 0 PROD1 PLUG QEVL T PJSM Rig up Halliburton E-Line. PT dutch riser-good. 11:00 12:00 1.00 0 0 PROD1 PLUG WAIT T Wait on Halliburton crew to obtain a trigger key for unit 12:00 13:00 1.00 0 0 PROD1 PLUG ELNE T RIH with CBL to 25', unable to pass through. POOH, bow spring centrilizer 7"OD. Change out centrilizer. 13:00 16:00 3.00 0 0 PROD1 PLUG ELNE T RIH with CBL and log from 4,700'to 1,300'. 16:00 17:30 1.50 0 0 PROD1 PLUG ELNE T Change out E-Line tools to Jet cutter. RIH cut 5.5"casing at 3,550'. POOH, one centrilizer damaged. Stand back E-line 17:30 18:30 1.00 0 0 PROD1 PLUG CIRC T Rig up and attempt to circulate out the OA. Pressure up to 3500 psi, no circulation. Bleed off. 18:30 19:30 1.00 0 0 PROD1 PLUG WAIT T Wait on centrilizer for Jet cutter tool. E-Line crew timed out. 19:30 20:30 1.00 0 0 PROD1 PLUG RURD T Rig down E-Line crew and stand back. Rig down Dutch riser. 20:30 21:30 1.00 0 0 PROD1 PLUG BOPE T Install TWC in hanger. M/U hanger and set in tubing spool. RILDS. 21:30 23:00 1.50 0 0 PROD1 PLUG BOPS T Test BOPE's 250/3000 psi with 4" test joint. Test LPR, UPR and annular-pass. 23:00 00:00 1.00 0 0 PROD1 PLUG BOPS T Suck out stack. Pull hanger and TWC. R/D testing equipment. Page 25 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/08/2015 24 hr Summary Rig down testing equipment. Rig up dutch riser. Rig up HES E-line. RIH with jet cutter and cut 5.5"casing at 2800' ELM. POOH, rig down E-Line. Nipple down BOPE's,tubing head. Spear casing and pull packoffs and slips. Nipple up BOPE's. POOH with 5.5"casing from 2800'to 1815'. 00:00 00:30 0.50 0 0 PROD1 PLUG BOPE T Continue to rig down testing equipment. 00:30 03:00 2.50 0 0 PROD1 PLUG ELNE T Rig up dutch riser and prep for E-Line work 03:00 06:00 3.00 0 0 PROD1 PLUG WAIT T Wait on E-Line crew-timed out. 06:00 08:00 2.00 0 2,800 PROD1 PLUG ELNE T PJSM. rig up HES E-Line. RIH with jet cutter and cut 5.5"casing at 2800' ELM. POOH. 08:00 08:30 0.50 2,800 2,800 PROD1 PLUG CIRC T Rig up and circulate down the 5.5" casing up the OA. 15 bbls to fill the back side. 08:30 09:30 1.00 2,800 2,800 PROD1 PLUG ELNE T Rig down E-Line, rig down dutch riser. 09:30 13:00 3.50 2,800 2,800 PROD1 PLUG NUND T PJSM nipple down BOPE's. Nipple _ down tubing head. 13:00 15:00 2.00 2,800 PROD1 PLUG PULL T Spear casing and pull packoff and _ slips. 15:00 18:00 3.00 2,800 2,800 PROD1 PLUG NUND T Nipple up DSA and BOPE's. 18:00 19:00 1.00 2,800 2,800 PROD1 PLUG RURD T Rig up GBR casing equipment. 19:00 20:00 1.00 2,800 2,768 PROD1 PLUG PULL T Pick up Itco Spear. Spear 5.5" casing and pull to the floor. Lay down spear. 20:00 21:00 1.00 2,768 2,500 PROD1 PLUG PULL T POOH with 5.5"casing tfrom 2768 to 2500; PUW 80K, SOW 66K. 21:00 22:00 1.00 2,500 2,500 PROD1 PLUG CIRC T Establish circulation, returns noted. Pressure up to 2500 psi at 1 bpm. 22:00 00:00 2.00 2,500 1,815 PROD1 PLUG PULL T Continue to POOH with 5.5"casing from 2500'to 1815'. Minimize trip speed to prevent swabbing. 35/09/2015 Continue to POOH with 5.5"casing. Make up retrievamatic test packer. RIH to 1900'and attempt to establish an injectivity test. Pressure up to 3000 psi with 400 psi bleed in 15 minutes. Continue to RIH to 2,750'; pressure up to 3000 psi 600 psi lost in 15 minutes. POOH. M/U 9 5/8"test packer and RIH to 1900'. Pressure up to 2500 psi with 250 psi lost in 15 minutes. POOH. RIH with mule shoe to 958'. 00:00 01:30 1.50 1,815 1,815 PROD1 PLUG CIRC T Rig up and circulate 2 times annular volume at 4 bpm. 01:30 02:45 1.25 1,815 1,300 PROD1 PLUG PULL T Continue to POOH with 5.5"casing from 1815'to 1300. 02:45 03:15 0.50 1,300 1,300 PROD1 PLUG OTHR IT Crew change 03:15 08:00 4.75 1,300 0 PROD1 PLUG PULL T Continue to POOH with 5.5"casing, minimizing trip speed to prevent swabbing from 1300'to Surface. Recovered a total of 64 joints plus 33.97-ft of the 65th. Jet cut flair= 6.25"OD. Also recovered 29-5.5"x 6.125"x 8"Centralizers and 12-5.5" x 8.25"x 8"Centralizers 08:00 09:00 1.00 0 0 PROD1 PLUG RURD T Offload GBR casing and Tubular _running equipment from rig floor. 09:00 09:30 0.50 0 0 PROD1 PLUG BHAH T Make up retrievamatic test packer. Page 26 of 31 _Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:30 12:30 3.00 0 1,900 PROD1 PLUG PULD T RIH with test packer to 1900' picking up drill pipe from the shed. PUW 63K, SOW 63K. 12:30 13:30 1.00 1,900 1,900 PROD1 PLUG MPSP T Set test packer and attempt an injectivity test. Pressure up to 3000 psi, 500 psi bleed in 15 minutes. 13:30 14:30 1.00 1,900 2,750 PROD1 PLUG TRIP T Continue to RIH with test packer to 2750'. Set and attempt an injectivity test. Pressure up to 3000 psi; 600 psi in 15 minutes.. 14:30 15:30 1.00 2,750 0 PROD1 PLUG TRIP T POOH with test packer. 15:30 16:30 1.00 0 0 PROD1 PLUG BHAH T Lay down 7"test packer. Pick up 9 5/8"test packer. 16:30 18:30 2.00 0 1,900 PROD1 PLUG TRIP T RIH to 1900' PUW 62K, SOW 62K. 18:30 19:30 1.00 1,900 1,900 PROD1 PLUG MPSP T Set packer and attempt an injectivity test. Pressure up to 2500 psi. Pressure bled 250 psi in 15 minutes. R/U and test backside to 1000 psi for 10 minutes-good. 19:30 21:00 1.50 1,900 0 PROD1 PLUG TRIP T POOH with 9 5/8"test packer 21:00 22:00 1.00 0 0 PROD1 PLUG BHAH T Lay down test packer. 22:00 23:00 1.00 0 0 PROD1 PLUG RURD T Clean and clear rig floor. 23:00 00:00 1.00 0 956 PROD1 PLUG TRIP T Make up mule shoe and RIH with HT40 drill pipe to 956'. 05/10/2015 Continue to RIH to 2546'. Make up test packer and set at 75'. PT casing below to 2500 psi; 350 psi bleed in 5 minutes. POOH, L/D test packer. Rig up GBR. Discuss options with town. Pick up 5.5"WRP. 00:00 03:00 3.00 956 2,546 PROD1 PLUG TRIP T Continue to RIH with mule shoe to 2,546'. M/U test packer and set at 75'. pressure up on casing below packer; 350 psi leak in five minutes. 03:00 04:00 1.00 2,546 0 PROD1 PLUG TRIP T POOH with Mule shoe. 04:00 04:30 0.50 0 0 PROD1 PLUG RURD T Clean and clear rig floor. 04:30 05:00 0.50 0 0 PROD1 PLUG SVRG T Service top drive, drawworks. 05:00 06:00 1.00 0 0 PROD1 PLUG RURD T Rig up GBR. 06:00 12:00 6.00 0 0 PROD1 PLUG WAIT T Wait on order. Discuss options with town. Organize and clean rig. 12:00 23:30 11.50 0 0 PROD1 PLUG WAIT T Wait on 5.5"WRP from Baker. 23:30 00:00 0.50 0 0 PROD1 PLUG ELNE T Pick up WRP. 05/11/2015 RIH with 5.5"WRP to 4743'and set_.:Jick up 1 joint and set test packer and test WRP-good. POOH. Make up 7"WRP and test packer. RIH and set at 2,326' COE. 00:00 01:00 1.00 0 0 PROD1 PLUG BHAH T PJSM. M/U Wireline Retriveable plug. Strap and tally. 01:00 05:00 4.00 0 2,432 PROD1 PLUG PULD T RIH with WRP with 3-1/2" PH6 from pipe shed to 2431.7 05:00 05:30 0.50 2,432 2,445 PROD1 PLUG BHAH T Pick up and make up 7" retrievamatic test packer. 05:30 08:30 3.00 2,445 4,743 PROD1 PLUG TRIP T Continue to RIH with HT40 drill pipe from derrick to 4,743'. PUW 95K, SOW 94K. Page 27 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:30 10:00 1.50 4,743 4,733 PROD1 PLUG MPSP T Space out and drop ball and set WRP with 2600 psi. Pick up 10'. 10:00 12:00 2.00 4,733 4,733 PROD1 PLUG MPSP T Rig up and attempt to test WRP. Bleed 500 psi in 30 minutes. Attempt again. Suspect surface leak 12:00 14:00 2.00 4,733 4,733 PROD1 PLUG MPSP T Re-rig circulation hose to isolate surface equipment. Pressure up and test WRP to 3500 psi for 30 minutes. 300 psi bleed with 100 psi in last 15 minutes-good. 14:00 15:30 1.50 4,733 2,450 PROD1 PLUG TRIP T POOH with WRP running tool and test packer to 2450' 15:30 16:30 1.00 2,450 2,450 PROD1 PLUG BHAH T Lay down test packer. 16:30 18:30 2.00 2,450 0 PROD1 PLUG PULD T Continue to POOH with WRP running tool, laying down 3-1/2"PH6 pipe. 18:30 19:30 1.00 0 0 PROD1 PLUG BHAH T Lay down WRP running tool 19:30 20:00 0.50 0 PROD1 PLUG SVRG T Servie rig. Grease drawworks ant top drive. 20:00 21:00 1.00 0 14 PROD1 PLUG BHAH T Pick up 7"WRP and running tool 21:00 23:00 2.00 14 2,327 PROD1 PLUG TRIP ( T" RIH with 7"WRP and running tool __vh stands from the derric ✓ 23:00 00:00 1.00 2,327 2,327 PROD1 PLUG MPSP T Drop ball and pressure up to 3000 psi to set WRP. 35/12/2015 Set 7"test packer and test WRP to 3500 psi for 30 minutes(good test). POOH and lay down 7"test packer. PU, MU, and RIH with 9-5/8"test packer to 1817' RKB; set test packer and test 7"x 9-5/8"casing below test packer to 2500 psi for 30 minutes(good test). RU to freeze protect, unset test packer, and freeze protect by reverse circulating 135 bbls of diesel at 2 BPM. POOH laying down DP and 9-5/8"test packer. Install one joint of DP into the BOP stack and close the bottom rams. Open the blind ram doors, remove the blind rams to be redressed and close blind ram doors. Open lower rams and remove joint of DP. ND BOPE and set back on stump. NU tubing head, install tubing hanger with bull plug, RILDS, NU DSA, and NU BOPE to conduct CPAI BOPE inspection per CPAI Between Well Maintenance(BWM)program. 00:00 00:30 0.50 2,327 2,315 PROD1 PLUG MPSP T Set 7" Retrievamatic test packer. 00:30 01:45 1.25 2,315 2,315 PROD1 PLUG PRTS T Rig up to test WRP and test to 3500 psi for 30 minutes-good. 01:45 02:00 0.25 2,315 2,315 PROD1 PLUG RURD T Rig down testing equipment. 02:00 03:00 1.00 2,315 1,079 PROD1 PLUG TRIP T POOH standing back drill pipe. 03:00 03:30 0.50 1,079 1,079 PROD1 PLUG SVRG T Service top drive 03:30 04:30 1.00 1,079 128 PROD1 PLUG PULD T POOH laying down drill pipe. 04:30 05:30 1.00 128 0 PROD1 PLUG BHAH T Lay down 7"test packer BHA. Clean and clear the floor 05:30 06:00 0.50 0 17 PROD1 PLUG BHAH T PU and MU 9-5/8"test packer BHA 06:00 07:15 1.25 17 1,817 PROD1 PLUG TRIP T TIH with 9-5/8"test packer to 1817' RKB. 07:15 08:30 1.25 1,817 1,817 PROD1 PLUG MPSP T RU to test below test packer. Set test packer per Baker rep and PT 9-5/8"casing below test packer to 2500 psi for 30 minutes(good test) Page 28 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:30 09:15 0.75 1,817 1,817 PROD1 PLUG FRZP T PJSM. RU Little Red Services(LRS) to the OA. RD test equipment. Unset test packer per Baker rep. RU to reverse circulate. PT LRS lines to 2500 psi(good test). 09:15 11:00 1.75 1,817 1,817 PROD1 PLUG FRZP T Reverse circulate 135 bbls of diesel at 2 BPM with LRS to freeze protect the well. 11:00 11:30 0.50 1,817 1,817 PROD1 PLUG FRZP T RD LRS and RD circulating equipment. 11:30 12:30 1.00 1,817 1,384 PROD1 PLUG PULD P POOH laying down DP from 1817'to 1384'RKB. 12:30 14:00 1.50 1,384 1,384 PROD1 PLUG SLPC P Slip&Cut 60'of drilling line. Inspect break linkage, brake bands, rollers, dead man brass,existing line, and draw works. 14:00 14:30 0.50 1,384 1,384 PROD1 PLUG SVRG P Service top drive: grease TD, check the oil, and inspect. 14:30 16:00 1.50 1,384 17 PROD1 PLUG PULD P Continue to POOH laying down DP from 1384'to 9-5/8"test packer. 16:00 16:30 0.50 17 0 PROD1 PLUG BHAH T Lay down 9-5/8"test packer BHA. Clean and clear the floor. 16:30 19:30 3.00 0 0 PROD1 WHDBO SVRG P PJSM. CPAI BOPE inspection: Install one joint of DP into the BOP stack and close the bottom rams. Open the blind ram door, remove the blind rams to be redressed and close blind ram doors. Open lower rams and remove joint of DP. 19:30 21:30 2.00 0 0 PROD1 WHDBO NUND P Remove riser, ND BOPE, and set back on stump. ND spacer spool and ND DSA. 21:30 00:00 2.50 0 0 PROD1 WHDBO NUND P PJSM. NU tubing head, install tubing hanger with bull plug, RILDS, NU DSA, and NU BOPE. 05/13/2015 Perform CPAI BOPE inspection per CPAI Between Well Maintenance(BWM)program. ND BOPE, set back on stump, and secure for rig move. ND DSA and pull tubing hanger with bull plug. NU frac head, ND top Otis connection flange, and NU new Otis connection flange. Freeze protect tubing head and frac head with LRS. Pressure test breaks to 1000 psi(good test). Rig Release at 12:00 hours. 00:00 01:00 1.00 0 0 PROD1 WHDBO SVRG P CPAI BOPE inspection per CPAI Between Well Maintenance(BWM) program: Blow down choke and kill lines. Install 4"test joint and function annular two times checking for excessive wear and overall condition (photos taken of annular). SimOps: Transport shops from 2G pad to 3F pad and continue to clean pits. Page 29 of 31 . _.. .... ..__. .. . . Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 02:30 1.50 0 0 PROD1 WHDBO SVRG P CPAI BOPE inspection per CPAI Between Well Maintenance(BWM) program: Break bolts on upper ram doors, open doors,and function ram piston to the closed position. Inspect ram cavities, sealing surfaces, and door seals. Inspect 3-1/2"x 6"VBR's upper seal and front packer assembly. Function piston back to the open position and inspect door bolt. Close upper ram doors and tighten bolts(photos taken of all components and of stack cavities). SimOps: Continue to clean pits. Remove berming from around LEPD tank and transport from 2G pad to 3F pad. 02:30 04:30 2.00 0 0 PROD1 WHDBO SVRG P CPAI BOPE inspection per CPAI Between Well Maintenance(BWM) program: Break bolts on blind ram doors, open doors, and function ram piston to the closed position. Inspect ram cavities, sealing surfaces, and door seals. Install re-dressed blind rams. Inspect blind upper seal and front packer assembly. Function piston back to the open position and inspect door bolt. Close blind ram doors and tighten bolts(photos taken of all components and of stack cavities). SimOps: Blow down water and steam to the pits. Unhook service lines from the pits to the sub. Load trucks to transport from 2G pad to 3F pad. 04:30 06:00 1.50 0 0 PROD1 WHDBO SVRG P CPAI BOPE inspection per CPAI Between Well Maintenance(BWM) program: Break bolts on lower ram doors, open doors, and function ram piston to the closed position. Remove 2-7/8"x 5"VBR's. Inspect ram cavities, sealing surfaces, and door seals. Install re-dressed 2-7/8" x 5"VBR's. Inspect 2-7/8"x 5" VBR's upper seal and front packer assembly. Function piston back to the open position and inspect door bolt. Close lower ram doors and tighten bolts(photos taken of all components and of stack cavities). SimOps: Continue to load trucks to transport equipment from 2G pad to 3F pad. 06:00 08:00 2.00 0 0 PROD1 WHDBO NUND P ND BOPE, set back on stump, and secure for rig move. ND DSA and pull tubing hanger with bull plug. Page 30 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:00 11:00 3.00 0 0 PROD1 WHDBO NUND P NU frac head. ND top Otis connection flange and NU new Otis connection flange. SimOps: Disconnect TD inner connect at the A leg. Hook up the jeep to the pits. Move the pits and satillite office from 2G pad to 3F pad. 11:00 11:30 0.50 0 0 PROD1 WHDBO FRZP P Freeze protect tubing head and frac head with LRS. 11:30 12:00 0.50 0 0 PROD1 WHDBO PRTS P Pressure test breaks to 1000 psi (good test). **Rig Release at 12:00 hours"* 1 Page 31 of 31 25$4(2 WELL LOG TRANSMITTAL DATA LOGGED 611/2015 4.K BENDER To: Alaska Oil and Gas Conservation Comm. May 19, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED RE: Cement Bond Log - Jet Cutter Records: 2G-02 MAY 2 1 2015 Run Date: 5/7/2015 AOGCC The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2G-02 Data in LAS format, Digital Log Image files 1 CD Rom 50-029-21153-00 SCANNED 'U N 1 2 2015 Cement Bond Log 1 Color Log 50-029-21153-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS ANC@halliburton.com Date: Signed: /12 PTV / '4 -/ Z / Loepp, Victoria T (DOA) From: Smith,Travis T <Travis.T.Smith@conocophillips.com> Sent: Saturday, May 09, 2015 8:28 PM To: Loepp,Victoria T(DOA) Subject: RE:2G-02 (PTD 184-121,Sundry 315-058) Follow Up Flag: Follow up Flag Status: Flagged Hello Victoria— Regarding the suspension of 2G-02:we spoke on Friday about our plan to set a 7" cement retainer and squeeze cement downward. Because we have seen low injectivity in the leaks thus far, we will not be able to squeeze cement away. Instead, we plan to set a balanced plug in the 5-%2" casing, then set a retainer or bridge plug in the 7" casing and lay at least 100' of cement on top of it in the 7". This is a slight change to the suspension plan you and I discussed, but should not materially affect the outcome. We will still be pressure testing the plug from above afterwards. Travis From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Thursday, May 07, 2015 3:34 PM To: Smith,Travis T Subject: [EXTERNAL]RE: 2G-02 (PTD 184-121, Sundry 315-058) Travis, The 2 sets of packer/plug combinations with the 800' of cement as outlined below are adequate for the abandonment of the Kuparuk sands. Thanx, Victoria SCANNED JUN 0 92015 Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W. 7th Ave,Ste 100 Anchorage,AK 99501 Work (907)793-1247 Victoria Loepp(o�alaska qov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov 1 From: Smith,Travis T[mailto:Travis.T.Smith@conocophillips.com] Sent:Tuesday, May 05, 2015 5:40 PM To: Loepp, Victoria T(DOA) Subject: RE: 2G-02(PTD 184-121, Sundry 315-058) Hello Victoria— Per our conversation today, our current status is pulling out of hole with the 2-7/E," drill pipe after severing free from the drill pipe section that is cemented in hole. Because we are free from the stuck drill pipe, we will not need to get an extension to the BOP testing. Attached here is the proposed suspension diagram. The well has 2 mechanical plugs above the perforations (from the 2 sets of packer/plug combinations) as well as a minimum of approximately 800' of cement at the bottom of the 5-%2" x 7" annulus and the interior of the 5-%2" casing. Our intent would be that these mechanical and cement barriers would serve as a lower plug if the well were eventually abandoned in the Kuparuk. We are planning to run our kill string in this well tomorrow following the BOP testing. Please let me know if you need any other information. Thanks very much, Travis From: Loepp, Victoria T(DOA) [mailto:victoria.loeDD@ alaska.gov] Sent:Tuesday, May 05, 2015 8:02 AM To: Smith,Travis T Subject: [EXTERNAL]RE: 2G-02 (PTD 184-121, Sundry 315-058) Travis, What is the current status?At what point would you be able to do a BOP test? How long do you need the extension for? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W 7th Ave,Ste 100 Anchorage,AK 99501 Work (907)793-1247 Victoria Loeppalaska qov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeor©alaska.gov From: Smith,Travis T[mailto:Travis.T.Smith©conocophillips.com] Sent: Monday, May 04, 2015 4:59 PM 2 To: Loepp, Victoria T(DOA) Subject: 2G-02 (PTD 184-121, Sundry 315-058) Hello Victoria— I left you a phone message on Sunday. We are still having difficulties with the workover on KRU producer 2G-02. As near as we can tell,approximately 700'of drill pipe is cemented in hole at the bottom of our newly run 5-'A"casing. We are currently attempting to cut the drill pipe to pull the free pipe out of hole. Our operations forward will include: 1. Cut and pull the free drill pipe from the well 2. Run a CBL on the 5-'4"to determine the top of cement It is likely we will pursue a plan to suspend this well once the free drill pipe is removed. I will send you this plan as soon as we know more about the status of the 5'/:" cement. Additionally,the BOP test for this well is due May 6. Would we be able to get an extension on this testing deadline? Thank you very much, Travis Smith 3 ConocoPhillips II 4 Est.32'MD,9-5'."Casing Leak 116'MD,16"62.5#,H-40 2G-02 Producer 2719'MD,9-5/8"36#,J-55 4 3-1/2"L-80 EUE-8RD Kill String -4---- 7"Cement Retainer 3988'MD,7''Casing Leak — 11.- 5-x/2"15.5#,L-80 Casing ---P► 2-'/."HT-PAC Drillpipe in* TAM Combo Tool(BTM @ 5956') 6100'TAM 5"Cement Port Collar—R ;:,i;; :' 1 — 3-1/2"x 5-W Crossover dimilri 4-- Baker Model F Permanent Packer CA-2 Plug --0' 2.813"DS Nipple 3-1/2"Tubing Cut —L► -4 — Baker Poor-Boy Overshot f—6241'Baker SAB-3 Permanent Packer CA-2 Plug —' I I f-- 6258'MD 2.75"Camco D Nipple -- 6267'MD Baker SOS I -2000'-6632'MD,7"26#,J-55 om: aft y,2015 I awn By: TrsN$5220 -T TtI• � \�����j�,s� THE STATEAlaska Oil and Gas 77,-.COF --s.�.—9� of Conservation Commission 1 .I�AS� 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main. 907.279.1433 Op ALAS Fax. 907.276 7542 4� AWL( ?S www.aogcc.alaska.gov Travis Smith Wells Engineer ConocoPhillips Alaska, Inc. I g/ ✓ P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2G-02 Sundry Number: 315-274 Dear Mr. Smith: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P oerster Chair DATED this eicay of May, 2015 Encl. ' STATE OF ALASKA .KA OIL AND GAS CONSERVATION COMmi6SION • APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request. Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r- Change Approved Program I✓ Suspend r,:ti Rug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casing 1 Other: I- 2.Operator Name: 4.Current Well Class. 5.Permit to Drill Number ConocoPhillips Alaska, Inc. . Exploratory r Development r. 184-121 3.Address: Stratigraphic r Service r 6.API Number P.O. Box 100360,Anchorage,Alaska 99510 50-029-21153-00 • 7. If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes 1 No Fi/ KRU 2G-02 9.Property Designation(Lease Number) _ I(b 10.Field/Pool(s): ADL 26Cf8 2S St'o Kuparuk River Field/Kuparuk River Oil Pool • 11 PRESENT WELL CONDITION SUMMARY Total depth MD(ft)• Total Depth TVD(ft): Effective Depth MD(ft) Effective Depth TVD(ft): Plugs(measured): Junk(measured): 6675 • 6258 s 6554' • 6181' • 6258' none Casing Length Size MD TVD Burst Collapse Conductor 78' 16" 116' 116' Surface 2682' 9 625" 2719' 2719' Production 6597' 7" 6632' 6231' RECE I V E U VA,/ba il 15 AUGO++�ww C Perforation Depth MD(ft). Perforation Depth TVD(ft): Tubing Size: Tubing Grade. Tubing MD(ft). 6376-6396,6414-6458 • 6068-6081,6094-6121 3.5 L-80 6268 Packers and SSSV Type. Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER SAB-2 PERMANENT PACKER W/K22 ANCHOR SEAL AS'MD=6241 TVD=5975 - NIPPLE-CAMCO DS NIPPLE MD=480 TVD=480 12.Attachments: Description Summary of Proposal F. 13. Well Class after proposed work' Detailed Operations Program r- BOP Sketch ` Exploratory r Stratigraphic r Development 17• Service r" 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work. 5/6/2015 Oil r Gas r WDSPL r Suspended pa ' 16.Verbal Approval Date: WINJ r GINJ r WAG I- Abandoned r Commission Representative. GSTOR l SPLUG r 17. I hereby certify that the foregoing is true and correct to-the bit of my knowledge Contact: Travis Smith @ 265-6450 - Email: Travis.T.SmithAconocophillips com �J/ i / Printed Name Travis S J�'` Title: Wells Engineer „.---/(//5--- ,/ / Signature �, 7 \, - -) Phone:265-6450 Date 5 /5- Commission Use Only Sundry Number. t1 Conditions of approval: Notify Commission so that a representative may witness 315-2-1�C Plug Integrity r- BOP Test r Mechanical Integrity Test r- Location Clearance r” Other. Spacing Exception Required? Yes ❑ No i Subsequent Form Required. /b _ 4 U 4_, APPROVED BY Approved by: /(1) L- COMMISSIONER THE COMMISSION Date: S—8-kr' i'�L 5 7J /c APPro I1l Il� 12 the ro the date of approval. 2015FSP.- SRB DMST MAY 1 1 orm 10-403(Revised 10/2012) Submit Form and Attachents in Duplicate ‘ y1,,C— ConocoPhillips RECEIVED Alaska MAY U 6 2015 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 (" AOGCC May 6,2015 Commissioner State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc. hereby submits a 10-403 form for Change of Approved Scope to Kuparuk Producer 2G- 02(PTD# 184-121, Sundry 315-058). The approved workover scope for Kuparuk River producer 2G-02 is no longer economically feasible because of drillpipe cemented in hole during a casing operation. After pumping cement to the backside of the 5-1/4" casing a v port collar was inadvertently opened allowing cement back inside the 5-'/2"casing which cemented the lower portion of the drillpipe in hole. The well has 2 mechanical plugs above the perforations (from the 2 sets of packer/plug combinations) as well as a minimum of approximately 800' of cement at the bottom of the 5-'/2" x 7" annulus and the interior of the 5-'/2" casing. These mechanical and cement barriers would serve as a lower plug if the well were eventually abandoned in the Kuparuk. This Sundry is intended to request approval of the change in scope of the workover operations. If you have any questions or require any further information,please contact me at 265-6450. Sincere y, 1 T� is mrth Wells Engineer CPAI Drilling and Wells " KUP 2G-02 C011000011illip5 Well Attributes Max Angle&MD TD • Wellbore API/UWI Field Name Well Status Incl CI MD(ftKB) Ant Btm(ftKB) Alaska.Inc 500292115300 KUPARUK RIVER UNIT PROD 50.90 6,500.00 6,675.0 Comment HES(ppm) Date Annotation End Date KB43b(ft) Rig Release Date •.. Well C0/40.-20-02 10/15/2012e4435AM SSSV:NIPPLE 10 1/17/2010 Last WO: 5/17/1997 40.41 8/9/1984 Schematic-Actual Annotation Depth(ft1(8) End Date Annotation Last Mod...End Date Last Tag:SLM 6,364.0 10/13/2012 Rev Reason:TAG,RESET PLUG ninam 10/15/2012 Casing Strings Casing Description String 0... String ID...'Top(ftl(B) Set Depth(1...Set Depth(TVD)...String Wt...String...String Top Thrd ' CONDUCTOR 16 15.062 38.0 116.0 116.0 62.50 H-40 WELDED HANGER,35 ` Casing Description String 0... String ID_.Top(I8(8) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd '• SURFACE 95/8 8.921 37.4 2,719.4 2,719.4 36.00 J-55 BTC t--1 Casing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd PRODUCTION 7 6.276 352 6,631.6 6230.8 26.00 J-55 ETC Tubing Strings I Tubing Description String 0... String ID...Top(IS(8) SDepth(f...Set Depth(TVD)...String Wt...String... String Top Thrd TUBING 31/2 2.992 34.9 Iet 6,267.9 5,993.8 9.30 I L-80 EUE8RDMOD Corn•letion Details IIIIII Top Depth (TVD) Top not Nomi... •„ Top( 8) (ftKB) C) Item Description Comment ID(in) 34.9 34.9 0.15 HANGER 5M GRAY KUPARUK STYLE TUBING HANGER 3.500 479.6 479.5 0.17 NIPPLE CAMCO DS NIPPLE w/2.81?NO GO PROFILE 2.812 6,201.6 5,945.7 44.28 NIPPLE CAMCO W NIPPLE w/2.812"SELECTIVE PROFILE 2.812 CONDUCTOR,_� Sat is 6,241.2 5,974.7 45.20 PACKER BAKER SAB-2 PERMANENT PACKER w/K22 ANCHOR SEAL 3250 ASSEMBLY NIPPLE,400III 6,258.0 5,986.8 45.60 NIPPLE CAMCO D NIPPLE w/2.75"NO GO PROFILE 2.750 6,267.0 5,993.2 45.81 SOS BAKER SHEAR OUT SUB PINNED FOR 3500 PSI,ELMD 6289'FROM 2,937 SWS BHP OF 6/30/2005 GAS LIFT, Other In Hole(Wireline retrievable lu s valves _Lungs,fish,etc.) 2.462 'Top Depthl �� fp 1 (TVD) Top Inol 1 Top(11(8) (11(8) CI Description Comment Run Date ID(In) 6,258 5,986.8 45.60 PLUG 2.75"CA-2 PLUG 10/14/2012 0.000 • Perforations&Slots Shot Top(TVD) Elm(TVD) Dens SURFACE. l Top(18(5)Btm OMB)5) Mai/ MICR/MICR/ Zone Data (oh-• type Conanent 6,376 6,396 6,067.5 6,080.8 A-5,2G-02 9/16/1984 4.0 IPERF 90 deg.Phasing;4"Sclumberger 37-2,719 I 6,414 6,458 6,093.6 6,121.3 A-0,2G-02 9/16/1984 4.0 IPERF 90 deg.Phasing;4"Sclumberger -----,/ Notes:General&Safety GAS LIFT. End Date Annotation 3,896 1 -4_ 4/5/2004 NOTE:LEAK PARTIALLY(2 BARRIERS)REPAIRED WITH SEALANT I. l 10/19/2010 NOTE:View Schematic w/Alaska Schematic9.0 9/24/2011 NOTE:LEAK IN 7"LOCATED AT 3988'RKB USING TECWEL LDL TOOL GAS LIFT ... ..__4_.. 5,035 GAS LIFT. 5,797 1:1 GAS LIFT, 6156 , ._=/. NIPPLE.6,202 -- 1 PACKER.6.241 - T NIPPLE,6256 4"/�dl/ PLUG,6,256 SOS,6267 i-Z_.1 PER. 6,3786.396 Mandrel Details _ ITop Depth Top Port (TVD) Incl OD Valve Latch Size TRO Run 6.4t4G,458 SIPERF, tn Top(ftKB) (ftKB) C) Make Model (in) Sere Type Type lin) (psi) Run Date Corn... 1 2,462.5 2,462.4 0.38 MERLA TMPD 1 GAS LIFT DMY BK-5 0.000 0.0 11/17/2003 _m- 2 3,894.7 -3,891.6 11.56 MERLA TMPD 1 GAS LIFT DMY BK-5 0.000 0.0 11/172003 3 5,034.5 4,984.4 22.35 MERLA TMPD 1 GAS LIFT DMY BK-5 0.000 0.0 11/17/2003 4 5,796.8 5,640.4 36.75 MERLA TMPD 1 GAS LIFT DMY BK-5 0.000 0.0 11/172003 5 6,156.0 5,9142 43.58 CAMCO MMM 1 12 GAS LIFT DMY RK 0.000 0.0 1120/2003 PRODUCTION, 35-6.632 I.6.675 -- ConocoPhillips 4 Est.32'MD,9-%"Casing Leak 116'MD,16"62.5#,H-40 2G-02 TAM 5-1/2"Cement Port Collar(Closed) ► Producer - Proposed Suspension 2719'MD,9-5/8"36#,J-55 3-1/2"L-80 EUE-8RD Kill String 5-1/2'15.5#,L-80 Casing O- il 4111-- 3477':ESTIMATED TOC in 542"x 7" 3988'MD,7"Casing Leak • 5307':TOC in 24a"x 5-1/2' 2--'/a"HT-PAC Drillpipe 4 5360':TOC in 2-'/a"DP TAM Combo Tool(BTM @ 5956') 6100'TAM 5"Cement Port Collar—► 1 : r ]i 3-1/2"x 5-/"Crossover Baker Model F Permanent Packer CA-2 Plug I i 1 2.813"DS Nipple 3-1/2"Tubing Cut —►, I Baker Poor-Boy Overshot -- 1, �— 6241'Baker SAB-3 Permanent Packer CA-2 Plug I 1 -4— 6258'MD 2.75"Camco D Nipple I 6267'MD Baker SOS I I -2000'-6632'MD,7"26#,J-55 .. 'L. Date: May 3,2015 I Drawn By: Trivia Smith 25795 WELL LOG TRANSMITTAL DATA LOGGED 5/2$/2oi8 M.K.BENDER • To: Alaska Oil and Gas Conservation Comm. April 29, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED RE: Radial Cement Bond Log &Jet Cut Record: 2G-02 MAY 0 6 2015 Run Date: 4/22/2015 AOGCC The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2G-02 Data in LAS format, Digital Log Image files 1 CD Rom 50-029-21153-00 Radial Cement Bond Log 1 Color Log 50-029-21153-00 sumo ,1LiN 1 5Z015 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: 6.24"---C • Loepp, Victoria T (DOA) From: Smith,Travis T <Travis.T.Smith@conocophillips.com> Sent: Tuesday, May 05, 2015 5:40 PM To: Loepp,Victoria T(DOA) Subject: RE:2G-02 (PTD 184-121,Sundry 315-058) Attachments: 2G-02 Proposed Suspension.pdf Hello Victoria— Per our conversation today, our current status is pulling out of hole with the 2-7/8' drill pipe after severing free from the drill pipe section that is cemented in hole. Because we are free from the stuck drill pipe, we will not need to get an extension to the BOP testing. Attached here is the proposed suspension diagram. The well has 2 mechanical plugs above the perforations (from the 2 sets of packer/plug combinations)as well as a minimum of approximately 800' of cement at the bottom of the 5-1/2" x 7" annulus and the interior of the 5-%2" casing. Our intent would be that these mechanical and cement barriers would serve as a lower plug if the well were eventually abandoned in the Kuparuk. We are planning to run our kill string in this well tomorrow following the BOP testing. Please let me know if you need any other information. Thanks very much, Travis From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Tuesday, May 05, 2015 8:02 AM To: Smith,Travis T Subject: [EXTERNAL]RE: 2G-02 (PTD 184-121, Sundry 315-058) Travis, What is the current status?At what point would you be able to do a BOP test? How long do you need the extension for? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W 7th Ave,Ste 100 Anchorage,AK 99501 Work (907)793-1247 Victoria Loepp@alaska qov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov 1 From: Smith,Travis T[mailto:Travis.T.Smith@conocophillips.com] Sent: Monday, May 04, 2015 4:59 PM To: Loepp, Victoria T(DOA) Subject: 2G-02 (PTD 184-121, Sundry 315-058) Hello Victoria— I left you a phone message on Sunday. We are still having difficulties with the workover on KRU producer 2G-02. As near as we can tell,approximately 700'of drill pipe is cemented in hole at the bottom of our newly run 5%"casing. We are currently attempting to cut the drill pipe to pull the free pipe out of hole. Our operations forward will include: 1. Cut and pull the free drill pipe from the well 2. Run a CBL on the 5%"to determine the top of cement It is likely we will pursue a plan to suspend this well once the free drill pipe is removed. I will send you this plan as soon as we know more about the status of the 5-1/2" cement. Additionally,the BOP test for this well is due May 6. Would we be able to get an extension on this testing deadline? Thank you very much, Travis Smith 2 PTO —/z ) Loepp, Victoria T (DOA) From: Regg,James B (DOA) Sent: Thursday,April 23, 2015 3:45 PM To: Loepp,Victoria T(DOA) Subject: RE:2G-02 BOPE Testing (PTD 184-121, Sundry 315-058) Follow Up Flag: Follow up Flag Status: Flagged Yes. Jim Regg Supervisor, Inspections AOGCC %OW MAY 0 4 Z015 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or jim regg@alaska.gov. From: Loepp, Victoria T(DOA) Sent: Thursday, April 23, 2015 3:44 PM To: Regg,James B(DOA) Subject: RE: 2G-02 BOPE Testing (PTD 184-121, Sundry 315-058) They are rigging up the BOP on the casing head and would need a BOP test extension from 4/25/15 until they have the BOP rigged back up on the tubing head by about 4/28/15. So the extension would be for more like—3 days. Does this sound more reasonable? From: Regg,James B(DOA) Sent:Thursday, April 23, 2015 3:38 PM To: Loepp, Victoria T(DOA) Subject: RE: 2G-02 BOPE Testing (PTD 184-121, Sundry 315-058) Not reading this as a 1 week extension.They need to give estimate of time needed Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, 1 please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or iim.regg@alaska.gov. From: Loepp, Victoria T(DOA) Sent: Thursday, April 23, 2015 3:34 PM To: Regg,James B (DOA) Subject: FW: 2G-02 BOPE Testing (PTD 184-121, Sundry 315-058) Jim, Do you have any issue with a BOP extension of 1 week as described below? Thanx, Victoria From: Smith, Travis T[mailto:Travis.T.Smith@conocophillips.com] Sent:Thursday, April 23, 2015 3:27 PM To: Loepp,Victoria T(DOA) Subject: 2G-02 BOPE Testing (PTD 184-121, Sundry 315-058) Hello Victoria- Nabors 9ES is working on KRU 2G-02 workover operations. As per the workover program,the BOPE are being rigged up to the casing head so that the 7"casing can be pulled to repair a surface casing leak. While the casing repair is ongoing the BOPE will be on diverter status. Because of this,we request an extension of the 1 week required BOPE test (currently scheduled for April 25th) until the casing is re-installed and the BOPE are back to full function status. Nabors 9ES KRU 2G-02 PTD 184-121 Sundry 315-058 Thank you very much, Travis Smith 2 ���1•X21 25&Ltci WELL LOG TRANSMITTAL DATA OED Si LOGGED M K.BENDER To: Alaska Oil and Gas Conservation Comm. March 30, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED APR 032015 RE: Leak Detect Log: 2G-02 AOGGC Run Date: 3/19/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS ANC@halliburton.com 2G-02 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21153-00 SCANNED MAY 0 6 2015 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: () ,Aizia-,z4k-ii) 6.-e-oteat rOF T�J� \V/7, 4N THE STATE Alaska Oil and Gas foALASKA Conservation Commission 333 West Seventh Avenue *;. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main 907 279.1433 OF ALAS71°.' Fax 907 276 7542 \* 4 4 www.aogcc.alaska.gov scost Travis Smith Wells Engineer1: 1 " r� D. ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2G-02 Sundry Number: 315-058 Dear Mr. Smith: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. F erster Chair, Commissioner DATED this 2 "Tay of March, 2015 Encl. STATE OF ALASKA FEB 0 5 2015 . ALASKA OIL AND GAS CONSERVATION COMMISSION • APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r Change Approved Program r Suspend r Rug Perforations r Ferforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate Alter casingw r rOther: r 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc - Exploratory r Development P, 184-121 3 Address: Stratigraphic r Service r 6.API Number. P.O. Box 100360,Anchorage,Alaska 99510 50-029-21153-00 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No F. KRU 2G-02 • 9.Property Designation(Lease Number). 10.Field/Pool(s): ADL 25658 - Kuparuk River Field/Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft) Effective Depth TVD(ft): Plugs(measured): Junk(measured). 6675 , 6258 . 6554' - 6181' • 6258' none Casing Length Size MD TVD Burst Collapse Conductor 78' 16" 116' 116' Surface 2682' 9.625" 2719' 2719' Production 6597' 7" 6632' 6231' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6376-6396,6414-6458 . 6068-6081,6094-6121 3.5 L-80 6268 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER SAB-2 PERMANENT PACKER W/K22 ANCHOR SEAL AS:MD=6241 TVD=5975 • NIPPLE-CAMCO DS NIPPLE MD=480 TVD=480 • 12.Attachments: Description Summary of Proposal . 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development .17- Service 1- 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 2/16/2015 Oil r.7 ' Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Travis Smith @ 265-6450 Email. Travis.T.Smithaconocophillips.com Printed Name Travi ith Title: Wells Engineer 4ir Signature /f V' Phone:265-6450 Date ��/S Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness -�S — O S5� Plug Integrity r BOP Tes r7Mechanical Integrity Test r Location Clearance r Other: L3p 71-- -,5t fb 3,0C)O ip 5 r (.4/71)5? 75 Z600 /25-1., 4-v7r-ivlccr prr-veyr7-Ci— re/-- ?L Z5-0 C ,oS ' , -Z!/lfCn'r/fv/ 0i 5— i " Ca51iy r✓LV�f 6t rfrfl0/ Cvcy 4 yra �s • Spacing Exception Required? / Yes ❑ No Subsequent Form Required: /0— 4 0 4. APPROVED BY / � Approved by:06711:SIONER THE COMMISSION Date: 3�2-�1 3 4pepl II I 1 months trom the date of approval. _t2��� �1 � Form 10-403(Revised 10/2012) 1 �5�� Submit Form and chments in Duplicate V`TL 2/74,0.,- -'?41/0 RBDMS MAR - 4 2015 ConocoPhillips RECEIVED Alaska FEB 0 5 2015 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOGCC February 4,2015 Commissioner State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to workover Kuparuk Injector 2G- 02(PTD# 184-121). Well 2G-02 was drilled, completed, and fracture stimulated in late 1984 as an A-Sand only single completion. The well was re-fractured in May 1988. During the frac job,the tubing buckled and the well was worked over in May 1993 to repair the corkscrewed tubing. The well was re-fractured again in June 1993. In January 1997 a leak developed in the packer and a workover was completed in May 1997 to replace the tubing and packer. In November 2003 the well failed an MIT-OA, was taken off gas lift and a leak was detected near 32' Milk_t e surface casing (9-%" casing). Between 2004 and 2005 attempts to repair the hole in the surface casing at 32' with Seal-Tite and cement were unsuccessful. The well remained on production without gas lift because the production casing, tubing, and packer all passed pressure integrity tests to liquid. In June 2011 the well failed a mechanical integrity test of the inner annulus and was shut-in. The leak in the production casing (7" casing) was detected at 3988' MD. The proposed workover plans are to pull the upper 3 '/2"tubing completion, cut and pull the 7"casing above the top of cement, and run a 5-'/2" casing string from the packer to surface, with cement in the 5-'/2" x 7" and 7" x 9-%" annuli. A new 3 '/2"upper completion will then be run. This Sundry is intended to document the proposed work on the production well because of the modification to the production casing and request approval to workover the well. If you have any questions or require any further information,please contact me at 265-6450. '1 vi Ardif mi Wells Engineer CPAI Drilling and Wells • 2G-02 Rig Workover Subsidence RWO (PTD #:184-121) Current Status: This well has been SI since June 2011 because of a production casing leak. The well is isolated from the reservoir with a wireline retrievable plug set at 6,258'. Scope of Work: The proposed workover plans are to pull the upper 3 ''h" tubing completion, cut and pull the 7" casing above the top of cement, and run a 5-''A"casing string from the packer to surface, with cement in the 5-V2"x 7"and 7"x 9-%"annuli. A new 3 '/2"upper completion will then be run. General Well info: Well Type: Producer MPSP: 2,600 psi using maximum SITP ever observed(12/2011) Reservoir Pressure/TVD: 4,435 psi/6,076'TVD(14.0 ppg EMW)on 10/13/2012 Wellhead type/pressure rating: Gray Gen III(5M Tubing Head/3M Casing Head) BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT results: MIT-IA failed on 7/6/11 MIT-T passed on 6/20/11 SCLD of OA showed leak at 32' on 11/28/03 Earliest Estimated Start Date: March 10,2015 Production Engineer: Deanna van Dam/Mike Balog Workover Engineer: Travis Smith(265-6450/Travis.T.Smith@cop.com) Summary Procedure Pre-Rig Work 1. Spectraflow Log to verify packer 2. Set Catcher and pull DV from lowest GLM for circulation 3. Chemical cut tubing at 6,220'RKB 4. Set BPV Rig Workover 1. MIRU RWO Rig 2. Pull BPV. Circulate seawater. Obtain SITP & SICP, if still seeing pressure at surface, calculate new KWF and repeat circulation as necessary. Verify well is dead. 3. Set BPV&blanking plug,ND tree,NU BOPE&test. 4. Pull blanking plug&BPV,screw in landing joint,BOLDS's,unseat tubing hanger. 5. PU on tubing and pull hanger to the floor. POOH laying down 3-'h"tubing. a. If tubing will not pull free, RU wireline. RIH to first full joint of tubing above K-22 anchor seal assembly and cut tubing. RD wireline. 6. TIH using 2-%"drillpipe with casing scraper to SAB-3 packer,circulate well clean. TOOH racking back. 7. RIH with Poor Boy Overshot, Camco D-Nipple with CA-2 plug, and Baker Model F packer on drillpipe. Hydraulically set packer,then POOH with drillpipe standing back. 8. MIRU Wireline: a. Run cement bond log in 7"casing b. RIH w/jet cutter to cut the 7"casing above TOC. RD wireline. 9. NU BOPE to the 7" casing head. Change out Pipe Rams. (BOPE will be a diverter because of surface casing leak) 10. Spear 7"casing and PU to circulate out Arctic Pack from the OA using heated diesel&seawater. 11. TOOH sideways with 7"casing. Set test plug,change out Pipe Rams,PT BOPE,and pull test plug. . • 2G-02 Rig Workover Subsidence RWO (PTD #:184-121) 12. MU&TIH with 9-5/8"casing scraper to the top of the 7" stub and circulate well clean. 13. MIRU casing crew& TIH with new 5-'/z" casing, TAM port collars, and K-22 anchor seal assembly and sting into Model F packer. 14. ND BOPE,pull 5-%z" casing in tension and land in the slips. Cut off excess 5-'/z" casing. NU new tubing head and PT POs.NU BOPE,change out Pipe Rams,and PT BOPE. PT the 5-'/z"casing. 15. RIH with TAM cementing tool on drillpipe and sting into lower port collar to open. MIRU SLB cementers and cement the 5-'/z"x 7"/9-%"annulus to above the cut of the 7"production casing. Un-sting and close TAM port collar,and TOOH standing back drillpipe. 16. Lay down 5"TAM cementing tool and MU 5-'/z"TAM cementing tool. RIH and sting into upper port collar to open. Pump cement from upper port collar to surface in 5-1/4" x 9-%" annulus. Close TAM port collar and POOH laying down drill pipe. 17. TIH with new tubing to just above seal bore receptacle and swap well to CI brine. 18. Space out with pups, stab into seal assembly,MU tubing hanger,land hanger,and RILDS. 19. PT the tubing and IA.Bleed the IA and then the tubing.Ramp up the IA pressure quickly to shear the SOV. 20. Pull the landing joint and install two-way check 21. ND BOPE 'w 22. NU and test tree.Pull two-way check. 23. FP well with diesel through the SOV 24. Set BPV 25. RDMO RWO Rig Post-Rig Work 1. Reset well house,re-attach flowlines. Pull BPV. 2. RU Slickline: a. Pull the SOV from the KMG-2-9 mandrel and run GLD b. Pull the CA-2 Plug 3. Turn well over to Operations „,6,,,,i - ConocoPhilh 5 p i 4 -Est.32'MD,9-%”Casing Leak L r cc 3 116'MD,16"62.5#,H-40 R^ :::=,:lr. TAM 5=/:"Cement Port Collar--10- E 2G-02 Producer As-Planned 2719'MD,9-5/8"36#,J-55 IP Camco KBG-2-9 GLMs(5) all i,- (,- 3 . g. My 3988'MD,7"Casing Leak H - 51/ 15.5#,L-80 Casing 31/:"9.3#,L-80 Tubing - TAM 5"Cement Port Collar /' II 4 3-Y?x 5-1/2"Crossover MI 0 - 4 Baker Model F Permanent Packer M i -40-- 2.813"DS Nipple 3-1/2"Tubing Cut --►, ' 4 Baker Poor-Boy Overshot trim f— 6241'Baker SAB-3 Permanent Packer p f— 6258'MD 2.75"Camco D Nipple —4 -- 6267'MD Baker SOS I I I I -2000'-6632'MD,7"26#,J-55 Date: Feb.10,2015 I Drawn By: Trois Smith s KUP 2G-02 • , . ConocoPhillips if Well Attributes Max Angle&MD TD Alaska.lt1C Wellbore API/UWI Field Name Well Status Ind(*) MD(RKB) Act Btm(RKB) KB) 500292115300 KUPARUK RIVER UNIT PROD 50.90 6,500.00 6,675.0 Comment H2S(ppm) Date Annotation End Date KB.Grd(R) Rig Release Date "- SSSV:NIPPLE 10 1/17/2010 Last WO: 5/17/1997 40.41 8/9/1984 Well Contig:-2G-02,10/1520128:14:55 AM Schematic-Actual Annotation Depth(ItKB) End Date Annotation Last Mod...End Date Last Tag:SLM 6,364.0 10/13/2012 Rev Reason:TAG,RESET PLUG ninam 10/15/2012 Casing Strings Casing Description String 0... String ID...Top(RKB) Set Depth(I...Set Depth(TVD)...String Wt...String...String Top Thrd CONDUCTOR 16 15.062 38.0 116.0 116.0 62.50 H-40 WELDED HANGER,35 Casing Description String 0... String ID...Top(RKB) Set Depth(t..Sat Depth(TVD)...String Wt...String...String Top Thrd __ .. SURFACE 95/8 8.921 37.4 2,719.4 2,719.4 36.00 J-55 BTC Casing Description String 0... String ID...Top(RKB) Set Depth(t...Set Depth(ND)...String Wt...String...String Top Thrd PRODUCTION 7 6276 35.2 6,631.6 6,230.8 26.00 J-55 BTC Tubing Strings Isim Tubing Description String 0... String ID...Top(RKB) . TUBING I 31/2 I 2.992 34.9 I 6,267.9 I 5,993.8Set Depth(TVD)... String Top Thrd 9.30String Wt... L-80String... EUE8RDMOD Nomi... Completion Details Top Depth (ND) Top Incl Top(RSet Depth(f.. KB) (RKB) (°) Item Description Comment ID(in) 34.9 34.9 0.15 HANGER 5M GRAY KUPARUK STYLE TUBING HANGER 3.500 479.6 479.5 0.17 NIPPLE CAMCO DS NIPPLE w/2.812"NO GO PROFILE 2.812 CONDUCTOR. 6,201.6 5,945.7 44.28 NIPPLE CAMCO W NIPPLE w/2.812"SELECTIVE PROFILE 2.812 38-116 6,241.2 5,974.7 45.20 PACKER BAKER SAB-2 PERMANENT PACKER w/K22 ANCHOR SEAL 3.250 ASSEMBLY NIPPLE.480 6,258.0 5,986.8 45.60 NIPPLE CAMCO D NIPPLE w/2.75"NO GO PROFILE 2.750 I 6,267.0 5,993.2 45.81 SOS BAKER SHEAR OUT SUB PINNED FOR 3500 PSI,ELMD 6289'FROM 2.937 SWS BHP OF 6/30/2005 GAS LIFT. Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) 2,462 Top Depth / 7-' (TVD) Top not Top(RKB) ( I°) Description Comment Run Date ID(in) 6,258 5,986.8 45.60 PLUG 2.75"CA-2 PLUG 10/14/2012 0.000 Perforations&Slots Shot Top(TVD) Btm(TVD) Dens SURFACE J l Top(RKB)Ben(RKB) (RKB) (RKB) Zone Date (ah--- Type Comment --- 6,376 6,396 6,067.5 6,080.8 A-5,2G-02 9/16/1984 4.0 IPERF 90 deg.Phasing;4"Sdumberger 37'2.718 6,414 6,458 6,093.6 6,121.3 A-4,20-02 9/16/1984 4.0(PERF 90 deg.Phasing;4"Sdumberger s Notes:General&Safety _ GAS LIFT. End Date Annotation 3895 r4/52004 NOTE:LEAK PARTIALLY(2 BARRIERS)REPAIRED WITH SEALANT 10/19/2010 NOTE:View Schematic w/Alaska Schematic9.0 9/24/2011 NOTE:LEAK IN 7"LOCATED AT 3988'RKB USING TECWEL LDL TOOL GAS LIFT. 5 035 c` GAS LIFT, g rG T. GAS LIFT, 6,156 NIPPLE,6202- I I_p., PACKER.6,241 Wu'' ,"4ns1 i I NIPPLE,5256 ',.! PLUG,6,25!1 al SOS,6,267 f IPERF, 53765,396 114, Mandrel Details L" = Top Depth Top Port -_ -- (ND) Incl OD Valve Latch Size TRO Run IPERF, Stn Top(RKB) (RKB) (°) _ Make _ Model (In) Sery Type TYM (t^) (psi) Run Date Com... 6.414-6,458 _ ' 1 2,462.5 2,462.4 0.38 MERLA TMPD 1 GAS LIFT DMY BK-5 0.000 0.0 11/172003 2 3,894.7 3,891.6 11.58 MERLA TMPD 1 GAS LIFT DMY BK-5 0.000 0.0 11/17/2003 3 5,034.5 4,984.422.35MERLA'TMPD 1 GAS LIFT DMY BK-5 0.000 0.011/172003 4 5,796.8 5,640.4 36.75 MERLA TMPD 1 GAS LIFT DMY BK-5 0.000 0.0 11/172003 5 6,156.0 5,914.2 43.58 CAMCO'MMM 1 12 GAS LIFT DMY RK 0.000 0.0 11/20/2003 PRODUCTION, N5" A ii3CTIO , Loepp, Victoria T (DOA) From: Smith,Travis T <Travis.T.Smith@conocophillips.com> Sent: Thursday, February 19, 2015 2:43 PM To: Loepp,Victoria T (DOA) Subject: RE: KRU 2G-02(PTD 184-121, Sundry 315-058) Subsidence RWO Hello Victoria- We can run a CBL on the 5-1/2" casing after the cement jobs are in place if required. Yes,this well will be on gas-lift production. After the workover,the 5-1/2" casing will act as the production casing in place of the current 7" casing. In that regard, there isn't any difference between it and our other gas-lifted producers, except that the diameter of the casing has changed. Therefore the monitoring plan will be the same as our other gas- lifted producers. Our Operating Guidelines describe diagnostics below: a. Further diagnostics are required when: i) Tubing by IA leak is indicated; ii) IA tracks tubing pressure with gas lift off, even if below 2000 psi; iii) IA by OA leak that requires bleeding more than twice per week; iv) OA rapidly tracks IA pressure, even if below 1000 psi; v) Leaks are present to the formation or atmosphere under normal operating pressures. Thank you for your response. Let me know if you need other information! Travis From: Loepp,Victoria T(DOA) [ma ilto:victoria.loeppCa alaska.gov] Sent: Thursday, February 19, 2015 9:18 AM To: Smith,Travis T Subject: [EXTERNAL]RE: KRU 2G-02(PTD 184-121, Sundry 315-058) Subsidence RWO Travis, Would like to see a cement evaluation log run in 5-1/2"casing. Will this well be on gas lift?What are your monitoring plans for verifying the integrity of the 5-1/2"casing on an intermittent basis? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W 7th Ave,Ste 100 Anchorage,AK 99501 Work (907)793-1247 Victoria Loepp a(�alaska qov 1 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov From: Smith,Travis T[mailto:Travis.T.Smith@aconocophillips.com] Sent:Tuesday, February 10, 2015 2:31 PM To: Loepp, Victoria T(DOA) Subject: RE: KRU 2G-02(PTD 184-121, Sundry 315-058) Subsidence RWO Hello Victoria, This is the proposed post-RWO schematic for 2G-02. Let me know if you need anything else! Thanks, Travis From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Tuesday, February 10, 2015 1:15 PM To: Smith,Travis T Subject: [EXTERNAL]KRU 2G-02(PTD 184-121, Sundry 315-058) Subsidence RWO Travis, Could you please provide a schematic of the proposed completion and cementing? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W 7th Ave,Ste 100 Anchorage,AK 99501 Work (907)793-1247 Victoria Loeppalaska oov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov 2 ge Project Well History File Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. L ~(-~_ - ~_ i_ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) n Color items: [] Diskettes No, [] Maps: [] Grayscale items: [] Other. No/Type [] Other items scannable by large scanner [3 Poor Quality Originals: OVERSIZED (Non-Scannable) [3 Other: NOTES: '[] Logs of various kinds [] Other BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: IS/ Project Proofing BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELl. DATE: /SI Scanning Preparation ~ x 30 BY: BEVERLY BREN VINCENT SHERYL(~ARIA~LOWELL Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: BY: Stage 2 BY~ (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATrENTION IS REQUIRED ON AN INDIVIDUAL PAGE SASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) -I- = TOTAL PAGES ~ ~)' PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~ YES NO NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO III IIIIlllllll II III RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S/ General Notes or Comments about this file: Quality Checked (done) 10125/02Rev3NOTScanned.wpd Schlumbel'ger NO. 342'9 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth 07/08/05 t<3'4--tJ--I Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 SCJ\J\ÎNEf" SEP {) () 2005 Field: Well Job# Log Description Date BL 2G-02 I~ ~ -j J.I 11047334 BHP SURVEY 06/30/05 1 f 2G-13 I~ ~i ~ i)'~' 11047336 BHP SURVEY 07/01/05 1 J, 2G-11 ¡g'-/-i 1'7 11047337 BHP SURVEY 07/01105 1 y 1Y-14}3~~ 01) 11022907 LEAK DETECTION LOG 06/30105 1 'J 3H-19/87 .,. {j J 11022907 PRODUCTION PROFILE 06/28/05 1 \/, 1J-03 ~(A - c). if 11022893 PRODUCTION PROFILE 06/17/05 1 'J 1L-09 ,'D.· ~ j'( 11022895 PROD PROFILE W/DEFT 06/19/05 1 .i, 3S-10 .J. o.À - 1 } 1. 11001235 PROD PROFILE W/DEFT 06/14/05 1 .i 3F-04 1"8:/ . )..,).8 11022891 INJECTION PROFILE 06/15/05 1 1Y-26A ¡~tJ··/t~ 11022892 PROD PROFILE W/DEFT 06/16105 1 ;.I1E-112)vï1-Ü'11 11047339 INJECTION PROFILE Ui~ 07103/05 1 j 1E-102 )..\7;'..(..J..}I 11047340 INJECTION PROFILE L.i i. <... 07/04/05 1 SIGNED: [/ Î / (! fJ~~ DATE: !, I ¿f\.lLi' ! ,\ l ¡ ) \,ø- Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Kuparuk Color ,_/ CD ----- "J ~-, :¿N. .1--' "-. { {it) ConocriPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 21,2004 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 rg l.J . I ~\ RECEIVED SEP 2 8 2004 Alaska Oil & Gas Cons. Anchorage Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field. Each of these wells was found to have a void in the conductor by surface casing annulus. The voids were filled with cement to the top of the circulation ports in the conductor. 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 top-fill operation was completed on September 19, 2004. Dowell-Schlumberger batch- mixed Tail System cement at 15.8 ppg in a blender tub. The cement was poured into the conductor from the top to fill the small void. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volume used on each conductor. Please call Jerry Dethlefs or myself at 907-659-7224, if you have any questions. Sincerely, t1/~~;Ø~ Marie McConnell ConocoPhillips Problem Well Supervisor Attachment SCANNED OCT 0 9 2004 WELL NAME 2G-02 2G-17 PTD# 1841210 2022430 ConocoPhillips Alaska, Inc. .... Surface Casing by Conductor Annulus Cement Top-off Kuparuk and Tarn Fields September 19, 2004 SERVICE CEMENT TOP VOLUME REASON TYPE ft bbl Producer 1 0.12 Cmt placed on 9/14/04 dropped below surface. Producer 1 0.12 Cmt not at surface, dispose of extra cmt product All cement pumped was Schlumberger "Tail System" 15.8 PPG Cement This report is submitted in substitution for Sundry 10-404, Report of Sundry Operations SCANNED OCT 0 9 2004 NSK Problem Well Supervisor RE: OOA Cement Top-offs Subject: RE: OOA Cement Top-offs From: NSK Problem Well Supv <nI617@conocophillips.com> Date: Mon, 27 Sep 200416:45:56 -0800 To: Thomas Maunder <tom - maunder@admin.state.ak.us> ~ \~~ /\ Tom, There is a couple reasons for the excess cement. The depth is calculated by a string, so if that hangs up on any debris in the OOA, it may give us a false depth. Also since there is no way to circulate, your right, we rely on the hose to fill up the DCA. We just wanted to make sure we had enough cement to fill to surface. Brad Gathman Problem Well Supervisor 907-659-7224 -----original Message----- From: Thomas Maunder [mailto:tom Sent: Monday, September 27, 2004 To: NSK Problem Well Supv Subject: OOA Cement Top-offs maunder@admin.state.ak.us] 9:44 AM MJ and Brad, I was looking at the packet recently sent on the 6 wells that had the OOAs topped-off. It appears that the pumped volumes varied anywhere from 1.3 to 2.2 times calculated. Was XS cement circulated to assure that the OOA was full?? That would seem prudent, since it may not have been possible to get the hose all the way down. Thanks in advance for your reply. Tom Maunder, PE AOGCC C Q: ~ \ -...) a \ ~ \J'-"\..~ d-c,-Od \, ~ 1- ~(),~Q- d~-~~ \ \ ~ 0 S~-Oc::' \ '" ¥ .~ ~ - 0 e:, d~d 2.,\--O~ \" '\ ?,\-\ - 0 S' ,~~ 1 of 1 10/1/20048:28 AM ConocoPhillips Alaska, Inc. Surface Casing by Conductor Annulus Cement Top-off Kuparuk and Tarn Fields September 14, 2004 WELL PTD# SERVICE CEMENT TOP VOLUME REASON NAME TYPE ft Bbls 2G-02 1841210 Producer 82 14.5 SC leak @ 32' previously sealant repaired 2N-341 1981030 Producer 3 0.5 Wobbly tree 38-06 1850760 Producer 8 2 Post SC leak patch repair; Sundry 304-225 3F-06 1852440 Producer 40 11.8 SC leak @ 64' previously sealant repaired 3F-09 1852700 Producer 17 3.9 SC leak @ 24' previously sealant repaired - fþP 3H-05 1870770 Producer 8 2 Post SC leak patch repair; Sundry 304-228 All cement pumped is Arctic Set I 15.8 PPG Cement This report is submitted in substitution for Sundry 10-404, Report of Sundry Operations NSK Problem Well Supervisor . ConocoPhlllips Alaska, Inc. KRU 3H-O5 3H-05 TUBING API: 501032007700 Well Tvee: PROD Anale lãl TS: 36 dea lãl 6764 (0-3147, SSSV Tvee: NIPPLE Ona Completion: 9/16/1987 AnoIe lãl TD: 36 dea lãl7166 OD:3.500, Annular Fluid: Last W/O: 6/28/2004 Rev Reason: Set OV 10:2.992) Reference Loa: 31' RKB Ref Loa Date: Last UDdate: 8/21/2004 Last Taa: 7026 TD: 7166 ftKB Last Taa Date: 3/24/2000 Max Hole Anale: 36 dea (â) 6300 Casing String - ALL STRINGS Descriotion Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 115 115 62.50 H-40 SURF CASING 9.625 0 3454 3127 36.00 J-55 PROD CASING 7.000 0 7150 6186 26.00 J-55 Tubing String. TUBING Size Top Bottom TVD Wt Grade Thread 3.500 0 3147 2867 9.30 L-80 EUE8rdMad . I 2.375 3248 6363 5546 3.70 Continuous CT 4.500 6510 6557 5704 12.60 L-80 Buttress Peñorations Summarv Interval TVD Zone Status Ft SPF Date Type Comment COIL 6760 - 6831 5869 - 5927 UNIT 71 8 8/30/1988 IPERF 2 1/8 EnerJet; 60 ph (3248-6363, OD:2.375, D C-4 C-3 ID:1.939) 6839 - 6859 5933 - 5950 A-5 A-3 20 8 8/30/1988 IPERF 2 1/8 EnerJet; 60 ph ESP 6869 - 6889 5958 - 5974 A-2 20 4 8/30/1988 IPERF 2 1/8 EnerJet. 60 Dh (6351-6510, 6894 - 6914 5978 - 5994 A-2 A-1 20 1 12/8/1987 APERF 4" Csa Gun: 120 ph OD:5.130) Gas Lift MandrelsNalves St I MD I TVD I:~ Man Type I V Mfr I V Type V OD I Latch I Port I TRO I Date I Vlv Run Cmnt 1 1 30521 27871 CAMCO I MMG I I OV I 1.5 1 RKP 1 0.188 1 0 I 7/2/2004 I Other h luGS e Quip.. etc.) - ORIGINAL COMPLETION Deoth TVD Type Descrlotlon ID 6351 5537 ESP Electrocoil ESP Pump & Motor Assembly w/2.375" Deployment Sub 0.000 PUMP INSTALLED BELOW MOTOR ASSEMBLY 6510 5666 PACKER Baker FB-1 Packer, w/4" Seal Bore; Baker snap latch & seal assembly 4.000 w/auide sub landed in packer OAL=13.16' TUBING 6513 5668 SBE Baker 80-40 4.000 (6510-6557, 6532 5684 TPAC Petroline TPACs valve 2.900 OD:4.500. 6541 5691 FSV Petroline FSV Valve 2.500 ID:3.958) 6557 5704 WLEG 3.968 Other II lugs e uip.. etc.) - WORKOVER JEWELRY Deoth TVD Tvoe Descriotion ID 31 31 HANGER FMC TUBING HANGER 2.992 533 533 NIP CAMCO 'DS' NIPPLE. set 6/28/04 2.875 3108 2834 PACKER BAKER GHL (#781-20-3595) RETRIEVABLE PACKER set 6/28/04 2.940 3136 2858 NIP CAMCO 'DS' NIPPLE set 6/28/04 2.812 3146 2866 WLEG BAKER WIRELINE GUIDE 3.000 Fish - FISH Deoth I Descrlotion I Comment 6719 11" GLV & Wobble Rina I Lost Downhole Could still be in hole after workover 6720 11/2" SS Bands I See WSR's 3/31/00 and 4/4/00 General Notes Date Note 6/17/2000 7" CASING DAMAGE AT 6544' SEE USIT LOG 3/26/00 6/28/2004 REMAINING CONTINUOUS COIL BELOW 3147' IS CORRODED, IN PIECES. ESP STILL WORKING, PRODUCING THROUGH 3.5" TUBING SET DURING 2004 WORKOVER. 1-GLV 7/20/2004 PATCH SURFACE CASING LEAK lãl110. BELOW OA VALVE WITH 24" WELDED SLEEVE. Wobble Ring (6719-6720, ~ ) OD:1.000) - f-- Perf (6760-8831) - ¡-- - ¡-- - ¡-- Perf - f-- (6839-6859) - f-- - f-- - f-- Perf - - (8869-8889) - - - - - - Perf - - (8894-6914) - - - - - - '" I&¿/-!-r/ Conoc~ ill i ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 15, 2004 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7fu Avenue, Suite 100 Anchorage, AK 99501 RECEIVED SEP 1 7 2004 Alaska Oil & Gas Cons. Commission Anchorage Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk and Tarn fields. Each of these wells was found to have a void in the conductor by surface casing annulus. The voids were filled with cement to the top of the circulation ports in the conductor, or in some cases holes were cut in the conductor to facilitate fill-up. 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 top-fill operation was completed on September 14,2004. Dowell-Schlumberger batch- mixed Arctic Set I cement to 15.8 ppg in a blender tub. The cement was placed in the conductor from the bottom-up via a hose ran to the bottom of the void. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volume used on each conductor. Note that in most cases these wells have been previously reported as having surface casing leaks and have either been repaired by excavation and patching or injection of sealant material. Please call Marie McConnell or me at 907-659-7224, if you have any questions. Sincerely, çz... ./ c Jerry Dethlefs ConocoPhillips Problem Well Supervisor ~ Attachment ConocoPhillips Alaska, Inc. Surface Casing by Conductor Annulus Cement Top-off Kuparuk and Tarn Fields September 14, 2004 WELL PTD# SERVICE CEMENT TOP VOLUME REASON NAME TYPE ft Bbls 2G-02 1841210 Producer 82 14.5 SC leak @ 32' previously sealant repaired 2N-341 1981030 Producer 3 0.5 Wobbly tree 38-06 1850760 Producer 8 2 Post SC leak patch repair; Sundry 304-225 3F-06 1852440 Producer 40 11.8 SC leak @ 64' previously sealant repaired 3F-09 1852700 Producer 17 3.9 SC leak @ 241 previously sealant repaired 3H-05 1870770 Producer 8 2 Post SC leak patch repair; Sundry 304-228 All cement pumped is Arctic Set I 15.8 PPG Cement This report is submitted in substitution for Sundry 10-404, Report of Sundry Operations NSK Problem Well Supervisor . ConocoPhlUlps Alaska, Inc. KRU 2G-O2 2G-02 API: 500292115300 Well Tvee: PROD - Annie (å) TS: 46 dea (å) 6290 SSSV Type: NIPPLE Orig 8/9/1984 Angle @ TD: 51 deg @ 6675 ComDletion: NIP (480-481. [] Annular Fluid: Last W/O: 5/17/1997 Rev Reason: Add Waiver note 00:3.500) Reference Log: Ref Loo Date: Last Uodate: 4/29/2004 lUBING (~68, Last T8O: 6472 TD: 6675 ftKB OD:3.5O0. Last TaaDate: 1/24/2004 Max Hole AnDie: 51 dea (à 6675 ID:2.992) CasIno Strlnn - ALL STRINGS Deserlntlon Size TOD Bottom TVD Wt Grade Thraad PROD. CASING 7.000 0 6631 6230 26.00 J-55 GasUl! ~ SUR. CASING 9.625 0 2720 2720 36.00 J-55 IndreVDummy Valw 1 CONDUCTOR 16.000 0 116 116 62.50 H-40 (2462-2463. Tublnn Strlnn - TUBING 00:5.620) Size I TOD I Bottom I TVD I Wt I Grade I Thread 3.500 I 0 I 6268 I 5994 I 9.30 I J-55 I EUE 8RD Perforations SummarY GasUl! ... Interval TVD Zone Status Ft SPF Date TvDe Comment 3ndreVDummy 6376 - 6396 6067 - 6081 A-5 20 4 9/16/1984 4" 90 deg. Phasing Valw 2 ~Iumbera (3895-3896, 6414 - 6458 6092 - 6121 A-4 44 4 9/16/1984 4" 90 deg. Phasing 00:5.620) lumbern Gas Lift MandrelsNalves St MD TVD Man Man Type VMfr V Type VOD Lateh Port TRO Date VIv GasUl! '" Mfr Run Cmnt 3ndreVDummy 1 2462 2462 Merla TMPD Cameo DMY 1.0 BK-5 0.000 0 1/17/200 Valw 3 2 3895 3892 Merla TMPD Cameo DMY 1.0 BK-5 0.000 0 1/17/200 (5035-5036, 3 5035 4985 Merla TMPD Cameo DMY 1.0 BK-5 0.000 0 1/17/200 00:5.620) 4 5797 5641 Merla TMPD Cameo DMY 1.0 BK-5 0.000 0 1/171200 5 6156 5914 Cameo MMM Cameo DMY 1.5 RK 0.000 0 1/20/200 Other (I JUt 11- eaulD. ete,} - JEWELRY GasUl! ... Denth TVD TvDe Deserlntlon ID 3ndret/Dummy 480 480 NIP Cameo 'DS' NiDDIe NO GO 2.812 Valw4 6202 5947 NIP Cameo W Selective NiDDle 2.812 (5797-5798, OD:5.620) 6241 5975 PKR Baker 'SAB-2" 3.250 6258 5987 NIP Cameo 'D' NiDDle NO GO 2.750 6267 5993 SOS Baker 2.992 6268 5994 TTL 2.992 GasUl! ... General Notes mdreVDummy Date INote Valw 5 (61~157. 4/512004 I WAIVERED WELL: OA x OOA COMMUNICATION - LEAK REPAIRED WITH SEALANT 00:6.020) NIP (6202-6203, 00:3.500) PKR (6241-6242, OD:6.151) NIP (6253-6259. [] OD:3.5OO) 50s (6267-6268, OD:3.5O0) TTL (6268-6269, 00:3.500) Perf - - (6376-6396) - - - - - - Perf = = (6414-6458) - - - - - - STATE OF ALASKA ~"~- ALAS'r,,A OIL AND GAS CONSERVATION L,,JMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well .......... Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 84-121 3. Address 8. APl Number P. O. Box 100360 Anchorage, Alaska 99510 .~~ I 50-029-21153 4. Location ofwell atsurface a~,~-~---, =~ 9. Unitor Lease Name 487' FSL, 44' FEL, Sec. 31, T11N, R9E, UM ~. Kuparuk River Unit At top of productive interval~ 10. Well Number 1193' FSL, 884' FEL, Sec. 31, T11N, R9E, UM 2G-02 At total depth 11 i' Fieid and pool 1350' FSL, 1068' FEL, Sec. 31, T11N, R9E, UM ................................................................................................................................ Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. 139' RKBi ADL 25656 ALK 2582 12. Date Spudded 113. Date T.D, Reached ! 14. Date Comp., Susp., or Aband.115. Water depth, if offshore I16. No. of Completions i !9/17/84I N/AIOne i7. Total Depth (M~)+T,VD)! i8. Plug' Back Depth (MD+'I'VD)~19. DirectiOnal surveYi20~ Depth Where sSSV Set~21, ThickneSS of Permafrost · 6675' .. 6258 FT~ 6554' 6181' FT] I-lYes []No I N/A up| 1465' (Approx.) 22. Type Electric or Other Logs Run 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE ......................................... ...... SI_Z.E _ _VVT:_PERFT_._ _GRADE . TOP DO'I-rOM SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf. 116' 24" 200 sx Cold Set II 9-5/8" 36.0# J-55 Surf. 2720' 12.25" 770 sx Permafrost E, 370 sx Permafrost C '7~'- ............ 2-C~;'b~ .... ~ - ,J:-~ -- I ---S~; .... 6-6~3i-~ ...... ~.5-~--- ~-~0 ~X- C-I-~.~-~; ~-0-~:~ P-b-~m-~.f-rb~:t c ................................................................................ 24. P~forations open to PrOduction (MD+TVD of Top and Bottom 25. ' ' :I'uB'~G RECORD ' " and interval, size and number) S~ZE DEp'I~ SET ,...,(UD~ .... PACKER ~ .............................................. L_ .................................... I- ..................................................... 3.5" 6268' 6241' MD TVD MD TVD ................................................................................................................................... 6376'-6396' 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ~ , , ............. 6414'-6458' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 4 spf 2~. PRODI~CTION TEST ........ D~te I~irst ProduCtion iMeth'~d of OperatiOn (Flowing', gas' lift, etcli ...... Date of Test iHours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE S~ZE i GAS-O~L RATIO I ~ TEST PERIOD · ! ...................... ! ........................................................................................................................................................................................... ~t ................................................ Flow TubinglCasing PressurelCALCULATED · OIL-BBL GAS-MCF WATER-BBL O~L GRAWTY-API (CORR) Pr. ess.. i J.2.4-HOUR RATE .. i ...... 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate ~ 30. ~ 29. Geologic Ma;' "; ' ' Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Freeze protected well with diesel. 31. List of Attachments Summary of Daily Drilling Reports 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed 'L.~'L ~, ~,,,,, Title ~¢[t.~'l~tl, [v, tl.,.T,.N~F, ti. Date ~ ] ?- ~1/~:l- Prepared By Name/Number: ................. 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 cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 JUN 1997 ', Anchorage Date: 5/23/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 REMEDIAL AND COMPLETION OPERATIONS WELL:2G-02 RIG:NORDIC WELL ID: 998771 TYPE: AFC:--998771 AFC EST/UL:$ 350M/ 437M STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD: START C0MP:05/09/97 FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-21153-00 05/09/97 (C1) TD: 6675' PB: 6554' SUPV: RLM DAILY: $ 05/10/97 (C2) TD: 6675' PB: 6554' SUPV: RLM DAILY: $ 05/11/97 (C3) TD: 6675' PB: 6554' SUPV:RLM DAILY:$ 05/12/97 (C4) TD: 6675' PB: 6554' SUPV:RLM DAILY:$ 05/13/97 (C5) TD: 6675' PB: 6554' SUPV: DLW DAILY: $ 05/14/97 (C6) TD: 6675' PB: 6554' SUPV:DLW DAILY:$ WEIGHT BRINE TO 12.1 MW:ll.9 BRINE Move rig to 2G pad. Accept rig @ 2100 hrs. 5/9/97. 25,236 CUM:$ 25,236 ETD:$ 0 EFC:$ 375,236 CIRC 12.7 PPG BRINE MW:12.6 BRINE Displace well with 12.1 Thixsal brine. Increase weight to 12.6 ppg and displace well to 12.6 ppg brine. 77,819 CUM:$ 103,055 ETD:$ 0 EFC:$ 453,055 RIH WITH SPEAR MW:12.6 BRINE Pump 12.7 ppg brine. Monitor well, well dead. NU BOPE and test. POH with tubing and lay down jewelry. 50,403 CUM:$ 153,458 ETD:$ 0 EFC:$ 503,458 CIRC. OUT FRAC SAND MW:12.7 BRINE Pull out tubing ring, drift, strap and inspect. RIH with spear and fishing assembly to 6125'. Spear PBR. Lay down fishing tools, PBR, packer and pups. RIH with scraper. 44,017 CUM:$ 197,475 ETD:$ 0 EFC:$ 547,475 N/U TREE MW:12.7 BRINE Clean out frac-sand from 6372' to 6527'. Circulate til hole clean. Re-run 3.5" completion. 31,415 CUM:$ 228,890 ETD:$ 0 EFC:$ 578,890 RIG RELEASED MW: 0.0 BRINE Continue to rerun 3.5" tubing. Set Baker packer. Release rig @ 1930 hrs. 5/14/97. 47,325 CUM:$ 276,215 ETD'$ 0 EFC:$ 626,215 End of WellSummary for We11:998771 ARCO Alaska, Inc. Post Office Box 10036u Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 24, 1997 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 . Subject: 2G-02 (Permit No. 84-121) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report to cover any changes made to the completion during the recent workover operations on KRU 2G~02. If there are any questions, please call 263-4622. Sincerely, W. S. Isaacson Drilling Engineer Kuparuk Drill Site Development WSI/skad ORIGINAL .RECEIVE, D JUN 25 1997 ~-~-~ ¢~ & Gas :Co~s. . . ARCO Alaska, I'n,';"'-'"- Post Offic~ ,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 28, 1993. Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501. ~ Dear Mr. Johnston: Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL %q"ql .. 2F- 11 ~5-~ $~1--2F. 14 '~'q-I~ 2G-02 ?rS.-q--2U-01 ACTION Stimulate Stimulate Stimulate Stimulate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Sr. Engineer Kuparuk Petroleum Engineering RECEIV£i) S EP 2 9 t995 (;omm'~ss'to~ Nas]~..0ii & Gas Cons. ~ch0rage ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B-6O03-C STATE OF ALASKA ~ ~ OIL AND GAS CONSERVATION ~MI~:ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Pedormed: Operation Shutdown __ Stimulate X Plugging Pull tubing ~( Alter casing Repair well Perforate Other 2. Name of Operator ARQO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development ~ Exploratory .. Stratigraphic Service Plugs (measured) 6. Datum elevation (DF or KB) RKB 139' 4. Location of well at surface 487' FSL, 44' FEL, SEC 31, T11N, R9E, UM At top of productive interval 1193' FSL, 884' FEL, SEC 31, T11N, R9E, UM At effective depth 1289' FSL, 908' FEL, SEC 31, T11N, R9E, UM At total depth 1350' FSL, 1068' FEL, SEC 31r T11Nr R9E~ UM 12. Present well condition summary Total Depth: measured 6675' feet true vertical 6258' feet Junk (measured) Effective depth: measured 6554' feet true vertical 6182' feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2G-02 9. Permit number/approval number 84-121 10. APl number 5o-029-21153 11. Field/Pool Kuparuk River Oil Pool Cemented Measured depth Casing Length Size Structural Conductor I 1 6' 1 6" Surface 2720' 9 5/8" Intermediate Production 6 631 ' 7" Liner Perforation depth: measured 6376'-6396', true vertical 6067'-6081 ', 200 SX CS II 11 6' 770 SX PERMAFROST E 2 720' 370 SX PERMAFROST C 350 SX CLASS G 6631' 250 SX PERMAFROST C 6414'-6458' 6092'-6121' True vertical depth 116' 2720' 6230' RECEIVED ,'::i F P ? -q 1.q.q3 Alaska 0il & Gas Cons, (~0mmis~i Anchorage Tubing (size, grade, and measured depth) 3 1/2:, J-55 9.3 LB/FT, EUE, 6230' Packers and SSSV (type and measured depth) PACKER: CAMCO HRP @6204'MD,. SSSV: CAMCO-TRDP-4A-RO @1824'MD 13. Stimulation or cement squeeze summary Replace corkscrewed tubing and fracture stimulate Intervals treated (measured) A5,A4 sands 6376'-6458' MD Treatment description including volumes used and final pressure Placed 20M lbs 16/20 and 160M lbs 12/18 carbolite in formation. Final pressure 7000 psi. Re_oreser~tative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 14. 550 300 550 1400 160 2000~900 0 1300 200 Service Prior to well operation Subsequent to operation 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys runt Water Injector m Daily Report of Well Operations X Oil X Gas Suspended 17. I hereb~/.,,,certify that the foregoing is true and correct to the best of my knowledge. Si~lned~'-~ ~~' ~ Title Senior Engineer Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ARCO Alaska, Inc. ~ Subsidiary of Atlautic Rieltfidd Comlmauy WELL DESCRI~I'ION OF WORK 2G-02 KUPARUK "A" SAND REFRA~ DATE CObcI'RAC-FOR I K~Y P~-RSON 6/19/93 DOWELL YOKUM DAY PBTD (RKB) [LAST TAG (RKB). DATE 1 6535' [ SURFACE 6/19/93 TIME 0700 KUPARUK RIVER UNIT WELL SERVICE REPORT [AFC/CC# - SCA# ] 998076 [FIELD COST EST. {ACCUMULATED COST { $160,950 ] $163,643, [SSSV TYPE / STATUS [CAMCO TRDP 4A-RO (FRAC S,LEEVE) LOG ENTRY MIRU DOWELL FRAC EQUIPMENT, VECO PI/MP TRUCK. QC MATERIAl S 0815 HOLD SAFETY MTG W/ALL PERSONNEL. 0845 PRIME & P/T TREATING EQLrfP~NT TO 10,000 PSI. 0855 PUMPED JOB AS FOLLOWS: PI#l-150 BBLS/WF-20/25 BPM/5400-3547 PSL/7" ANN @ 3400 PSI. FG=.69, CP=3920 PSI,CF= 1.96 MIN. PI#2-100 BBLS/WF-20/25 BPM/3442-3415 PSI FG=.69,CP=3960 PSI,CT=l.44 MIN. DF - 300 BBLS/DXL-GW/25 BPM/3400-3820 PSI. BD - 59 BBLS/NXL-GW/25 BPM/3820-3710 PSI S/D FOR ISIP. ISIP= 1570 PSI, FG=.69,CP= 4100 PSI,CF=7.84 MIN.~= 34%, MTR = 97% S/B TO CORR.E~ AC'WFVATOR PROBI.EM. 1255 DF#2- 50 BBLS/DXL-WG/25 BPM/3450-3600 PSI BDg2- 50 BBLS/NXL-GW/25 BPM/3650-3845 PSI PAD- 240 BBLS/DXL-GW/25 BPM/3300-4030 PSI/7" ANN.-3461 PSI , 1PPA- 190 BBLS/DXL-GW/16/20 MESH/25 BP1V'd 3740-3655 PSI 2PPA- 167 BBLS/DXL-GW/16/20 MESH/25 BPM/3680-3660 PSI 4PPA- 143 BBLS/DXL-GW/12/18 MESH/25 BPM13700-3690 PSI 6PPA- 114 BBLS/DXL-GW/12/18 MlqSH/25 BPM/3880-4030 PSI . 18PPA- 143 BBLS/DXL-GW/12/18 MESH/25 BPM/4156.4200 PSI 10PPA- 169 BBLS/DXL-GW/12/18 MIZ-SH/25 BPM/4225-4200 PSI 12PPA- 169 BBLS/DXL-GW/12/18 MESH/25 BPM/4260-4312 PSI ll 14PPA- 7 BBLS/DXL-GW/12/18 MESH/25-23 BPM/4400-5600-- FLUSH FLUSH-7 BBLS/NXL-GW/23-3 BPM/5600-7000 PSI--- S/D. lo00 SECURE WE~I J., BLED 7" ANN. TO 500 PSI, R~ & Rh-:I-FASE DOWELL. t. OST ¥o su ^c . Alaska 0i1 & fla~ f30.n._~. Cvmmis$1~ Anchorage REMARI~ CONT~IJED: TOTAL LOAD TO RECOVER: 1731 BBLS TOTAL PROP PUMPED: 198,640# EFFECTWE PROP: 180,0(~ PROP IN CSG/TBG: 18,60~ RECEIVED SUMMARY: S E P 2 9 1993 ~Uaska OJl & Gas Gons. {Jommissio. Anchorage COMPLETED KUPARUK "A" SAND KEFRACTURE W1TH YF-140D WATER 180,000g OF 16/20 & 12/18 EFFECFIVE PROP IN FORMATION. SCI-ID. CTU, PREVIOUS CHGS II SERVICE COMPANY DOWEI.I- Diesel TOTAL FIELD ESTIMATE signed: DAILY $158,950 $160,950 ACCUM. TOTAL $2,693 $158,950 $163,643 ARCO Alaska, ir~. AK7396 2G-O~ KRU Nordic Rig #1 N/U BOPe 7"@ 6675' Dally Corn~letioruINo~over Report ,-w IJRR / WJP 6'71.~41 $ 6376'.6396', 8414'-64S8' Time 0~X~.1730 1730- O~eramong from M4:X) to ~ ovM well. Ac. ce: 1730 hre wqd BPV while w/ ~ hardli~ f/~o~ to fio~i~ a~ T~ hi.line ~ flo~ine to 1~ ~, ~~ di~ from wMl~re ~ flo~i~ ~ 2~ b~l of 8.5 ~ ~~ it 3 ~m. ~ ~o~ ~ bullh~ 8 ~ ~~ ~t orifl~ to ~o~oni. ~ ~llz ~N~ p~m m~liz~ It 176 ~i, I, ~late ~11 ~ 275 ~1~ of 9.4 ~ ~. ~le O~nk ~ b~. ~ter w~l. ~ ~ .... N/U BOPe KUPARUK PETROLEUM ENGINEERING Alaska Oil & Gas Cons. Gou"I~sS~("' Anchoruge I I I ARCO Alatk., Ira, ~rdic Rig #1 Dally Completion/Workover Report JRR / WJP $104,336 10(X).1100 1100-1200 1:200.1700 1700-1900 1900- -2130 2130-2300 0100- over well. M/U chok~ lime. Te~t pump. M/U Teat BOPE. Teat witmma~ by Do.u,g Amo~ of AOGCC. R/U GBR. Ba~k out Iockdown mwew$, P/U and work pipe 120k-13Ok. Circulate @ 1/2 I:pm, ,2, ,~SO Pei. Unable to pull pipe tree. Wait on Alaaka Pipe Regovery, SWS, T ..H.State. R/U SW$. W~II taking 6.7 I:~le/hr brirte. R/D flow nipple~ M/U $CSSV control IIr~ from t~t pump to top of tbg hgr. Preeaure to ~KX)O e~ewv. Rm:ommct flow nipple a~l mvm,~ olrc 2 bble to eneure 8,C~35 ',/open. MA) and calibrate freepoim tools. Change out flUlly COL ami RIH. 5'796'. obemJctlon et 5840'. Tbg mill free et that point. POll w/freepoint ~taska Oil & uas G /~11~11~1 Note: Yeetm'day'a total corn corrected to $~r'771 aa tndioet~ on ~___tmched coat IVED 199 iI ns. CommissiOn ID:NORDIC RIG ~1 TEL NO:659710J ~J58 ARCO Alaska, Inc. ~ Dally Completlon/Workover Report t, K7~96 I 1/~l ..... JRR / WJP 2G-0~ ~U ~7S' ~ " ~y~ w~ ~ ' " ~rdio Rig el 2 ~ ~2" .,w~~ ~147,111 · H w/~1~' flahing a~y t147z111 ~ ......... 1~ hre ~1~ , J . ........ ~ 0aa I ~1~" X 8" 81 126 '~ AP ...... -1~ 10.0 , ~t ou~ 23 ~ ~8 a~,2 ~int~ w/~1~ thrMd~ . 1~17~ 1.0 ~ OSH~ ~ Io run .DP, ~r [17~1~ 1,0 , ~k ~ rally ~A, ~ mill, ~m~ ~bt ~ra~ O~, .. _ :1~1G 1.0 P/U~ ~U ~d RIH w/1~ 19~ 3.5 p~ ~d NIH ~1~" DP ~ ~1~. -, . i . .. . . ~ 1.S Di~ ~1 ~ 9.7 ~ ~ni. ~ for flow · ~1 d~d. ,. ~1~ 1.0 Mill 1-1~' ol t~ ~b S~'~. , . . 01~. , 3.0 ~ w/m~l~ a~. . ..... ...... . · . ~ _ i . "' .... KUPAHUK PETfiOLEUM ENGINEERING ~ ~ ~ ~ I -' ff ...... , [J, _, ' , , ' '" AI~ Oil & Ga~ Cons. Co , , I D nmissio': ARCO Ala~km, Inc. 2G.O2 KRU No~ ~g ~ Dally Cornpletlon/Workover Report , JOB / WJP $1i2,S77 81 T~ (X, OO.O~qO oa30.oa~ 0~30-1030 1030-1130 1130-1230 1230.1700 1700- .1930 1930-2100 2100,,0100 01(X)-05~ Continue RIH w/3-1/2 "fishing i~eembly. I;/ m~'r~ ~ ~ on flab 5730'. P~.1~,~ii~lFi~ll~ov~'!fliJd ~?~t~ free. POll ,lowly. Drag 3C4c Ibc over up ..w~gm. L/O fishing toq. le. PBR. corkscrewed. Kinked end split Jura above PBR. No tr~loatiofl of kic4cov~ tool fish in recovered lublng~ Brlll( down tool, bum RIH w/BI, IA oft 3-1/2' DP. T~g peelr~w ~ ~247". I~1! p~ck~r tree. CBU. G~e in I~ne m Ixmome u~.. CBU reD, irk Shut dewn pump. w~l flowing. hme mm I~to to 10.1 ppg brine j~or to POH w/pecker. MA'~-23-'93 06:~8 ID:NJ ~C RI6 ~l TEL N0:6597 ARGO Alaska, InC. '~f' Dally Completlon/Wofl<over Report AK73~, 5/23/93 DB / WJP W# 1U " .. 2G-02 KRU 6675' 6M4' Nordic Rig #1 T~AJ l~ glnTMi4 GOM .... ~ ~ ~ ~6'~'~ ~14'~' ~ . . ~. ~ ~ ,~ ~M ~w ~V~ ~ ~ PU~ ~ ~ "' Bi ~. '~-- , , , , ,~ ~ 0.8 , ~minue J~lOi~ hole e~ ~ ~ 10,1 ~ ~t~, , , ~1~ 4.0 , ~ · no ~e~, . ..... 1~11~ 1.0 ~ ~ r~iwi~ ~1. ~ove W~ ~om o~~ u~ M . 11~1~ 1.5 W~ ~ ~ , 1~1~ . 4,0 ~ fl~i~ ~A (ov~~ ~ RIH. . . 1~I~ 0.6 Jar ~ ~ ~ fl~. ~1~ ~, {O~i~ u~le ~ ~M I~ ~ ~ing m.) , ~~ 0.6 ~ ~. ~ hu~ ~ ~ ~'. Jar e~ r~. L~ ~. , , . ~~ 3.0 ~. ~~ ~i=k ~ .... ~ ~6 ~ ti~i~ ~A {~ ~ fllH. ~ 1.0 CBU ~ ~~on ~ ~. . , , _ i K~ IPARI_IK PETROLE~JM ..... vv IL E E!VE[ , ,, r , . sEp 2 9 t99 '1 · _~ .... : ,,. ~nehomge ARCO Ale~ka, Inc. ~ D~lly Completion/Workover Report AK?3g6 .4/g3 DB / WJP ._ . wen TU [~ni.~ ~ t~p I~ pm 2~ KR~ ~TS'~, . . . ' ' ~W~ ~ ' ~14'~' ~ o~ 1 ~1~' X 8" 81 126 NO. ~ .... ~M ~ ~ 'i~~ ' ...... w.. 1--. I~ ,. .. . , , -"' , . ,' , · . - ,... ' ~ o.8 ~i~ fi~. , . 1~11~ 1.0 I~111~rger g~e ~~r. (I.D. of ~ Inrpr ~nn. I!~ in ~m~ r~er~e.,) ., 11~1~ , 3.5 ~ RIH ~ fl~ ~~. , . . , 1~~ ~,~ ~~;~h~~~6~1'. d.r~l~~l~.~ll~r~ ,,, ~~ . =.s wo~ ~r ~c~ ~ ~ue CBU. . ...... ,1~2~ 4.o ~ mo~y m mtnimi~ ~.~. R~~ :2~1~ 1.0 UD fiihi~ ~1~ Ind fi~. ~ ~~ BHA. , . i , 01~~ 3.~ ~H w/~M~m ~. T~ till ~ ~. P/U ~. . .., ~~ 1.5 ~i~ k~ly~ clMn out ~ !nd Junk f/ . ., II . . ., ~c , . , ~ . ., · . ~. ,., , .._ , - - m , . . , ', RECEIVE ' - ' , ,. , ,. Alaska 011 & Ga80ons. Co Anchorage ARCO AiaM<a, Inc. 'qP' Dally Compk ~/Workover Report AK73~6 i-- 6,'26/~3 DBIWJP w~ lO 1/l14 TOp OI '2~ KRU Mil' ' ~: ... ~ic Rig gl ~,~ ~,6~ ~1~ hole ~ ~~ ~ hre ~1~ .. ~ o~ I ~1~" X 6" 61 126 ..... ~"~' I~"~ ~ ;~'v~ ,~ ' "~ F,u<~ ~~~ I1~ ~ 716 ~e 817,412 J~,lg6 ~ ~ C~ .. ~r~ ~ ~ ~ ~ . . ~~ 1.9 ~in~p,~ ~n out ~ ~ Junk ~ M~' PB~ (~' ~ 9 RKB). ~ 1.5 ~1~ hole ~, . ~~ 0.6 Bl~ ~ ~ ~ ~ k~.. ~ 10 ~ DP. . ~1~ t.0 ~ip ~ ~t ~lli~ li~. ,. ,.. . 1~1~ 3.0 ... n H. E GI EERI G ,. , ii '~-- I 19~21~ 1.6 ~1~ hole 21~1~. 4.0 B~ do~ ~ ~ ~ ~ly, ~. ... 01~1~ .0.1 ~ ~ m~, ~ ~. 01~ 1.0 ~H, ., ..... ~ 0.5 ~ fl~ out DP. ~1~ o~ . ~ 2.0 RIH ~ ~, i. O~ 0.6 P~ ~ ~ ~ ~ 2~ ~ for ~ min. · ~ R~ R~ a~ cl~ul~ hole d~.n. , .. ,. , .. . .. "~LCLi V , ' Alaska uii & Gas Cons. Commi ARCO Alaska, Inc. ~' Dally Comp~lon/Workover Report A,K7396 8 _ ~ IDB / KKL .. ,,, i~,- · , .,.,. , ..- ,.~,~,~., . ~_ · ,_ .__._ .. ~ ..... ~ ¢~ , ., ] .- ' F !': .~ ,. .r._y~_ _. ~ . .:~, ~ r- ..- .,. . 1~11~ 1~ 5 ~f~l lO.4p~ ~i~ I~. L~ 17 . . 11~1~ 2.0 l- Ci~uMe~wi~~ 1~4 ~. M~Wl. . .... 1~~ .~.0 6 ~d~DP. ~flW~ ~~DC. LDO. _ . :~ O~ ~ ~p~ . . ....... -t ~. ~ .i . - , -. ~4~ ,6.0 MU ~ ~, ¢ ~, ~..~, · ~ ~ ~R~ ~c~, ~R, ~' pup, . .. , ..... ~ ~1~" ,X 1.1~" ~ ~ ~ ~4" ~ 6' pup. , , ~r ~ · I~P_I i hli ~ - ~ .... - . . _ i ~ . l. _ - , , . ..... ., ,i ~ . . , ....... , .... ~ i .~ ~R ~ .. . . . i , ~ ,. RECEIVED S E P 2 9 199;~ Alaska Oil & Gas Cons. CommiSS~,, Anchorage ARCO Alaska, Inc, -~pr Dally Completlon~orkover Report , , OB / KKL AK7306 5/27/93 , u 2(302 KRU , . 6675' 6554' 6535' Nordic Rig I1 $83.679 $46'7,M4 ~;iOIt It uuu~ ~uflw~lvl wee ~ RELEASED RIG 1457j~ $ ~ .... !-' ' NO. ~er b~ ' ~ ~M ~ 8~ P~ ~J~ ~'~ ~ '' w~,10.4 ~ [~ 1~ ~ 7.6 -- ~t~ IM~I ~ ~ ~h In ]~h Ou~ ~ , o.s 21 ~wi~ rig. Drop eheBr ~11. Tu~ ~ing weigN up = ~ ~ :,~ _. ~7~ 0.6 ~B MU he~ and I,~nding Joi~ Hoo~ up ~V ~n~l li~,m hanger ~em t~ ~ pai. 07~ 2.~ 23E ~d tu~ and ~n Iq lock ~ ~ewF. Pr=re ruing Hold for ~ min~--. B~ o~ I~ ~ ~. PU and i , a~ ~n in I~k ~ ~owL T~I ~V to 1~ ~i. Ti~ annulus ud ~n~ to ,, , ,, 2~ ~. Inc~ea~ ~ ~ure to ~ 4~ psi, ~o~ ~y. ~12~ 2.; 23F ~ll la~ ~im. ~ BPY. RD fl~w dm. ND BOP; HO ~a. ~.n pb, ~O hlrdlino. . _.~11 BPV. ~t ~ pug, , ~12~ 0.6 ;3E Tmup~mto2~a~~~. Tem,~ckoffto~~i. Pullt~Fu ~12~14~ 2.O ~F ~V. MU ~rcula~ ~im BM h~. ,', ~Jnue ~ning ~ta. ~mp 12 ~la diml in mnulua eM 4 ~8 in lubi~. , _ SIGP = 0 ~, ~TP: 2~ ~ ~d dro~J~. RD circulmJn; ho~. ~ure well. ~ean u~ w~i i i i R~ rio et 1~ houre on 5~ from -- i , , , i ii ' ~LI V - SEP 2 .. .. i STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: -- Pull tubing x Alter casing Repair well X 2. Name of Operator 15. Type of Well: Development ~ ARCO Alaska, Inc. Exploratory _ 3. Address Stratigraphic _ P. O. Box 100360, Anchorage, AK 99510 Service _ Operation Shutdown __ Stimulate Plugging __ Perforate _ 4. Location of well at surface 487' FSL,44' FEL, SEC 31, T11N, R9E, UM At top of productive interval 1193' FSL, 884' FEL, SEC 31 , T11N, R9E, UM At effective depth 1289' FSL, 908' FEL, SEC 31, T11N, R9E, UM At total depth 1350' FSL, 1068' FEL, SEC 31, T11N, R9E, UM 6675' 6258' feet feet Plugs (measured) 12. Present well condition summary Total Depth: measured true vertical Other 6. Datum elevation (DF or KB) 'W/ RKB 139', PAD 104' 7. Unit or Property name Kuparuk River Unit 8. Well number 2G-02 9. Permit number/approval number ]4-121 (Conserv Order No. 10. APl number 50-029-21153 261) 11. Field/Pool Kuparuk River Oil Pool Effective depth' measured true vertical 6554' 6181' Casing Length Size Structural I I 6' 1 6" Conductor Surface 2720' 9 - 5/8" Intermediate feet feet Junk (measured) Cemented 200 SX CS II Measured depth 116 ' 770 SX PF E & 370 SX PF C, True vertical depth 116' 272O 2720' Production 6 6 31' 7" 350 SX CLASS G & 250 SX PFC 6631' 6230' Liner Perforation depth: measured 6376'-6396', 6414'-6458'M D true vertical 6068'-6081 ', 6093'-6122'TVD Tubing (size, grade, and measured depth) 3-1/2" 9.3# J-55 @ 6231' Packers and SSSV (type and measured depth) RECEIVED J UN 2 3 199 Alaska Oil & Gas Cons. CommissiOn BAKER HRP-4-SP RETR PKR @ 6204', CAMCO TRDP-4A-RO SSSV @ 1824' MD Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Water Injector__ Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Form 10-40'4 Rev ¢5/1 Title Area Drilling Engineer Date ¢~/~,~ SUBMIT IN DUPLICA ~ b ARCO ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 2G-02 NORTH SLOPE KUPARUK RIVER KUPARUK RIVER ADL 25656 50-029-21153 84-121 ACCEPT: SPUD: 08/03/84 12:01 RELEASE: OPERATION: DRLG RIG: DOYON 9 WO/C RIG: NORDIC 1 Workover: 05/18/93 05/26/93 05/19/93 (1) TD: 6675 PB: 6554 05/20/93 (2) TD: 6675 PB: 6554 05/21/93 (3) TD: 6675 PB: 6554 NU BOPS 7"@ 6631' MW: 9.4 NaCl PREP R~G FOR OPERATIONS, SPOT CAMP, ACCEPT RIG @ 1730 5/18, PULL VR PLUG AND BPV WHILE FILLING PITS W/SEAWATER, RU HARDLINE F/ CHOKE TO FLOWLINE AND F/PUMP TO TREE, PRESSURE TEST LINE BETWEEN PUMP AND TREE TO 3000 PSI. TEST HARDLINE TO FLOWLINE TO 1000 PSI. DISPLACED DIESEL FROM WELLBORE TO FLOWLINE W/220 BBLS OF 8.5 PPG SEAWATER @ 3 BPM. SHUT CHOKE AND BULLHEADED 8 BBLS SEAWATER PAST OFIVICE TO PERFORATIONS. SI WELL TBG PRESS @ 175 PSI, FREEZE PROTECT FLOWLINE. CIRC WELL W/275 BBLS OF 9.4 PPG BRINE. HOLE DRANK 36 BBLS. MONITOR WELL-WELL DEAD. RD PUMP LINE. SET BPV, ND TREE, SET BLANKING PLUG. NU BOPS, WEIGHT UP PITS. POH W/3-1/2" TBG 7"@ 6631' MW: 9.4 NaCl CENTER RIG OVER WELL, MU CHOKE LINE, TEST PUMP, MU KILL LINE, NU FLOW NIPPLE, TEST BOPE, TEST WITNESSED BY DOUG AMOS AOGCC, RU GBR. BOLDS, PU & WORK PIPE 120K-130K, CIRC @ 1/2 BPM, 250 PSI. UNABLE TO PULL PIPE FREE. WAIT ON APR, SWS, & TRISTATE. RU SWS. WELL TAKING 6-7 BBLS/HR BRINE, RD FLOW NIPPLE, MU SCSSV CONTROL LINE FROM TEST PUMP TO TOP OF TBG HGR. PRESS TO 5000 PSI TO OPEN SCREW, RECONNECT FLOW NIPPLE AND REVERSE CIRC 2 BBLS TO ENSURE SCSSV OPEN, MU & CALIBRATE FREE POINT TOOLS. RUN FREEPOINTS, TAGGED OBSTRUCTION @ 5840' TBG STILL FREE, POOH, RIH W/ SWS JET CUTTER, TAGGED @ 5758', CUT TBG @ 5737', POH W/ SWS & PU ON TBG, BROKE FREE @ 66K LBS, PULL TBG HGR TO FLOOR, CBU, RU TONGS, POH W/3-1/2" TBG STRAPPING, DRIFTING, & CHANGING CONNECTORS ON EACH JOINT. RIH W/ FISHING ASSEMBLY 7"@ 6631' MW: 9.7 NaC1 FPOH W/3-1/2" TBG, RD GBR, RU TO RUN DP, RIH W/12 DCS & 25 JTS DP, BULLHEAD 25 BBLS 9.6 BRINE DOWN DP, CIRC ADDITIONAL 25 BBLS 9.6 PPG BRINE, RIH W/3-1/2" DP TO 5710', DISPLACE WELL TO 9.7 PPG BRINE, CHECK FOR FLOW, WELL DEAD, MILL 1-1/2' OF TBG STUB 5729'-5730', POH W/MILLING ASSY, MU & RIH W/FISHING ASSY REEEIVED JUN 199 Alaska Oil & Gas Cons. Commissior~ Anchorage WELL: 2G-02 API: 50-029-21153 PERMIT: 84-121 PAGE: 2 05/22/93 (4) TD: 6675 PB: 6554 05/23/93 (5) TD: 6675 PB: 6554 05/24/93 ( 6) TD: 6675 PB: 6554 05/25/93 ( 7) TD: 6675 PB: 6554 DISPLACING HOLE & PITS 7"@ 6631' MW:10.1 NaCl/Br SERVICE RIG, RIH W/3-1/2" FISHING ASSY, TAG ON FISH @ 5730', PU KELLY AND MILL OVER FISH, JAR ON FISH - PULL FREE. CBU, SLIP AND CUT DRILLING LINE. POH SLOWLY, DRAG 30K LBS OVER UP WEIGHT, LD FISHING TOOLS, RU & PULL TBG, GLM, PBR, TBG BADLY CORKSCREWED. KINKED AND SPLIT JUST ABOVE PBR. NO INDICATION OF KICKOVER TOOL FISH IN RECOVERED TUBING. BREAK DOWN OVERSHOT, MU PKR RETREIVING TOOL, BUMPER SUB, OIL JARS & PUMP-OUT SUB. RIH W/BHA ON 3-1/2" DP, TAG PACKER @ 6247', PULL PACKER GREE. CBU, GAS IN BRINE AT BOTTOMS UP. CBU, SHUT DOWN PUMP-WELL FLOWING. DISPLACE HOLE AND PITS TO 10.1 PPG BRINE PRIOR TO POH W/PACKER. POH 7"@ 6631' MW:10.1 NaCl/Br CONTINUE DISPLACING HOLE & PTIS TO 10.1 PPG BRINE, POH NO PKR, LD PACKER RETREIVING TOOL, WAIT ON TRI STATE, MU FISHING OVERSHOT & RIH, MU CIRC HEAD, WASH DOWN & LATCH FISH (SLICK STICK ON PACKER) AT 6275', JAR & ROTATE ON FISH - PULLED FREE (PULLING 30M OVER STRING WT), CBU, LD CIRC HEAD, START POH, PKR HUNG @ 6243', JAR & ROTATE, LOST PACKER, POH, RECOVER SLICK STICK, MU FISHING SPEAR & RIH, JAR ON PKR, SPEAR PULLED LOOSE & WOULD NOT RE-ENGAGE. PKR STILL IN PLACE, TAKES WEIGHT IN SAME LOCATION, CBU IN PREP TO POH 7"@ 6631' MW:10.1 NaCl/Br SERVICE RIG. POH, GRAPPLE GONE FROM SPEAR, INSTALL LARGER GRAPPLE ON SPEAR, RIH W/FISHING ASSY, MU CIRC HEAD & TAG PKR @ 6251', JAR @ 180K, PULL @ 290K PULLED PKR LOOSE. WORK PKR WHILE CBU, POH SLOWLY TO MINIMIZE SWABBING. RECOVERED PKR & REMAINING COMPLETION ASSY. LD FISHING TOOLS & FISH, RIH W/CLEANOUT BIT, TAG FILL @ 6407', PU KELLY, CO SAND & JUNK F/6407'-6525' CIRC HOLE CLEAN 7"@ 6631' MW:10.1 NaCl/Br CONT TO CLEAN OUT SAND & JUNK TO 6522' PBTD (6535' DOYON 9 RKB). CIRC HOLE CLEAN. BLOW DOWN & STAND BACK KELLY. LD 10 JTS DP. SLIP & CUT DRILLING LINE. POH. MU 7" CSG SCRAPER. RIH. MU KELLY, REAM F/6100'-6522' CIRC HOLE CLEAN. BLOW DOWN & STAND BACK KELLY. POH. LD CSG SCRAPER. MU RTTS. RIH. CRUDE FLOWING OUT DP. CIRC OUT. RIH TO 6200'. SET RTTS @ 6200'. MU CIRC HEAD. PRESS TEST 7" CSG TO 2500 PSI FOR 30 MIN-OK. RELEASE RTTS & CIRC HOLE CLEAN. Alaska Oil & Gas Cons. 6ommissioo Anchorage WELL: 2G-02 API: 50-029-21153 PERMIT- 84-121 PAGE: 3 05/26/93 (8) TD- 6675 PB: 6554 05/27/93 (9) TD: 6675 PB: 6554 RUNNING 3-1/2" COMPLETION 7"8 6631' MW:10.1 NaCl/Br CIRC OUT CRUDE & MONITOR WELL. SOME WELL PRESSURE OBSERVED. WEIGHT UP BRINE TO 10.4 PPG. CIRC 10.4 PPG BRINE AROUND. LOST 17 BBLS. CIRC & WEIGHT UP BRINE TO 10.4 PPG. MONITOR WELL. POH & LD DP. PULL WEAR RING. STAND BACK DC. LD RTTS. RD DP EQUIP. RU TO RUN 3-1/2" TBG. LOAD 45 JTS NEW 3-1/2" TBG IN THE PIPE SHED. DRIFT & STRAP TBG. WEIGHT UP PILL PIT VOLUME TO 10.4 PPG. MU CAMCO SOS, 8' PUP, D NIPPLE, 8' PUP, CAMCO HRP-4-SP PKR, PBR, 6' PUP, CAMCO 3-1/2" X 1-1/2" MMG GLM WITH 3/4" CHECK, 6' PUP. CONT RUNNING COMPLETION W/4-1" CAMCO KBUG GLM'S TO SSSV. HOOK UP & TEST CONTROL LINE TO 5000 PSI. BAND CONTROL LINE TO EVERY OTHER JT. RELEASED RIG 7"8 6631' MW:10.4 NaC1/Br SERVICE RIG. DROP SHEAR BALL. TBG STRING WT UP=59 K, DOWN=54K. MU HGR & LANDING JT. HOOK UP SSSV CONTROL LINE TO HGR & TEST TO 5000 PSI. LAND TBG & RUN IN LOCK DOWN SCREWS. PRESS TBG TO 2500 PSI & SET PKR. HOLD FOR 30 MIN. BACK OUT LOCK DOWN SCREWS. PU & SHEAR PBR 8 98K. RELAND & RUN IN LQCK DOWN SCREWS. TEST SSSV TO 1000 PSI. TEST ANN & TBG TO 2500 PSI. INCREASE TBG PRESS TO 3000 PSI FOR 15 MIN. SHEAR OUT BALL 8 4200 PSI. CLOSE SSSV. PULL LANDING JT. SET BPV. RD FLOW RISER. ND BOP. Nil TREE. CLEAN PITS. RD HARDLINE. PULL BPV. SET TEST PLUG. TEST UPPER TREE TO 250 & 5000 PSI. TEST PACKOFF TO 5000 PSI. PULL TEST PLUG. OPEN SSSV. MU CIRC JT & HOSE. CONT CLEANING PITS. PMP 12 BBLS DIESEL IN ANN & 4 BBLS IN TBG. SICP=0 PSI, SITP=200 PSI & DROPPING. RD CIRC HOSE. SECURE WELL. CLEAN UP WELL AREA. RELEASE RIG 8 1430 HRS ON 05/26/93 FROM 2G-02. SIGNATURE: (drill-ing ~hperintendent)' - DATE: Cons. Oommissio~ ~ 'MEMORANDUM STATE O, ALASKA ALAS~ OIL AND GAS CONSER VA TION COMMISSION TO: David Johnst~~ Chairmar¢~ THRU: Blair Wondzell P.I. Supervisor ~/at 173 FROM: Doug Amos ~ Petroleum Inspector DA TE: May 19, 1993 FILE NO: DA-51993. DOC PHONE NO.' 279-1433 SUBJECT: BOPE Test Nordic 1 AAI KRU 2G-2 Kuparuk Rv. Field PTD No. :84-t21 Wednesday May 19, 1993: I traveled this date to AAI's KRU 2G-2 well to witness the BOPE test on Nordic No. 1 Rig. Rig 1 has been stacked out for approximately eight months despite this fact I found the rig in good repair and all equipment in good working order. All the floor, choke and kill line, and manifold vales had been rebuilt prior to rigging up on this well. The original crew was in charge of the rig and knowledgeable about their equipment and the test procedure. The location was very clean and organized with amble room on the pad for other equipment should the need arise. As the attached AOGCC BOPE Test Report indicates there were no failures and the test went smoothly. IN SUMMARY, Tested the BOPE on Nordic 1, test time 3 1/2 hours, no failures. Attachment DA-51993.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Workover: X Drlg Contractor: NORDIC DRILLING Rig No. Operator: ARCO ALASKA, INC. Well Name: KRU 2G - 2 Casing Size: 7" Set @ 6,631 Test: Initial X Weekly Other 1 PTD # Rep.: Rig Rep.: Location: Sec. DATE: 5/19/93 84-121 Rig Ph,# 659-7115 BILL PINROSE PAUL HAYN ES 31 T. 11N R. 9E Meridian UMIAT MISC. INSPECTIONS: FLOOR SAFETY VALVES: Location Gen.: OK Well Sign YES Upper Kelly / IBOP Housekeeping: OK (Gen) Drl. Rig OK Lower Kelly/IBOP Reserve Pit N/A Ball Type Inside BOP BOP STACK: Quan. Annular Preventer 1 Pipe Rams 1 Pipe Rams Blind Rams 1 Choke Ln. Valves 2 HCR Valves 1 Kill Line Valves 2 Check Valve 0 Test Pressure P/F 2,500- P 3,000 P N/A 3,000 P 3,000 P 3,000 P 3,000 P N/A N/A M U D SYSTEM: Visual Alarm Trip Tank OK OK Pit Level Indicators OK OK Flow Indicator OK OK Gas Detectors OK OK Test Quan. Pressure P/F N/A N/A N/A N/A 1 3,000 P 1 3,000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 12 3,000 P 26 3,000 P 1 P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained 0 Blind Switch Covers: Master: Nitgn. Btl's: 2 @ 2,200 3,050 I P 2,450 P minutes 17 sec. minutes 53 sec. YES Remote: YES Psig. Number of Failures: NONE Test Time: 3 1/2 Hours Number of valves tested 19 Repair or Replacement of Failed Equipment will be made within N/A 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 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: The Rig has been stacked for approximately 8 months. All the equipment is in good condition and the crew is very experienced and knowledgeable about the BOP equipment and the test procedure. Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c -Inspector STATE WITNESS REQUIRED? YES YES NO 24 HOUR NOTICE GIVEN YES YES NO Waived By: N/A Witnessed By: Signed: Doug Amos FI-021L (Rev. 2/93) DA-51993.XLS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: 2. Name of Operator ARCO Alaska, In(;;. 3. Address Operation Shutdown m Stimulate X Plugging Perforate Pull tubing Alter casing Repair well Pull tubing Other P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 487' FSL, 44' FEL, Sec. 31, T11N, R9E, UM At top of productive interval 1193' FSL, 884' FEL, Sec. 31, T11 N, R9E, UM At effective depth 1289' FSL, 908' FEL, Sec. 31, T11N, R9E, UM At total depth 1350' FSL, 1068' FEL, Sec. 31, T11N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 6 6 7 5' feet Plugs (measured) 6 2 5 8' feet 6. Datum elevation (DF or KB) RKB 139' feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2G-02 Producer 9. Permit numbedapproval number 84-121 / ~-' 7.7 ~ 10. APl number 50-029-211 53 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 6554' feet Junk (measured) true vertical 6 1 8 1 ' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 1 1 6' 1 6" 200 Sx C.S. II 1 1 6' 1 1 6' Surface 2720' 9-5/8" 770 Sx Permafrost E 2720' 2720' Intermediate 370 Sx Permafrost C Production 6 6 3 1' 7" 350 Sx Class "G" 6 6 31 ' 6 2 3 0' Liner 250 Sx Permafrost C 13. Perforation depth: measured 6376'-6396', 6414'-6458' MD true vertical 6068'-6081' 6093'-6122' TVD Tubing (size, grade, and measured depth) 3 1/2", J-55 9.3 Ib/ft, EUE, 6702' MD Packers and SSSV (type and measured depth) -- Packer: Camco Hydro-Set @ 6280' MD, SSSV: OTIS FMX_IR @ 1920' Stimulation or cement squeeze summary Intervals treated (measured) 6376'-6396', 6414'-6458' MD Treatment description including volumes used and final pressure 1178 bbls Gelled Diesel, 71300#16/20 M Carbo-Lite Proppant, WHTP = 3880 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 923 592 0 400 180 2200 2261 0 300 166 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form l(~-404-Rc~rv 06/~5/88 ~' SUBMIT IN DUPLICATE ' 'WELL ARCO Alaska, Subsidiary of Atlantic Richfield Compa.. CONTRACTOR t~MARKS IPBDT WELL SERVICE REPORT FIELD-DISTRICT-STATE OPERATION AT REPORT TIME IDATE / o,'fo /,Z$7 - /.~OO - 15oo - I-'] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather RePOrt J Temp. milesI Wind Vel. REMAR. KS CONTINUED:. DESCRIPTION . DAILY ACCUM. TOTAL CAMCO 'OTIS SCHLUMBERGER DRESSER.ATLAS DOWELL HALLIBURTON ;~O~ 000. O~ ARCTIC COIL TUBING FRACMASTER B, J. HUGHES -- Roustabouts Diesel Methanol Supervision -- Pre-Job Safety Meeting AFE TOTAL FIELD ESTIMATE ~ O~ O~o~, ~ -- " STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI,SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend . ' Operation Shutdown ~ } Re-enter suspended well :-; Alter casing El TIme extension Change approved program Plugging "? Stimulate )~ Pull tubing Amend order .r Perforate [' Other 2 Name of Operator ARCO Alaska, ]]nc. 3 Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 487' FSL, 44' FEL, Sec. At top of productive ~nterval 1193' FSL, 884' FEL, Sec. 31, T11N At effective depth 1289' FSL, 908' FEL, Sec. 31, T11N At total depth 1350' FSL, 1068' 31, T11N, R9E, UM , R9E, UM , R9E, UM 5. Datum elevation (DF or KB) 139' RKB feet 6. Unit or Property name Kuparuk River Unit 7. Well r~_t~e~ Producer FEL, Sec. 31, T11N, R9E, UM 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 6675' 6258' feet Plugs (measured) feet 6554' feet Junk (measured) 6181' feet Casing Length Structural Conductor 116 ' Surface 2720' Intermediate Production 6631' Liner Perforation depth: measured 8. Permi~U_TL~r 9. APl number 50-- 029-21153 10..POOlKuparuk River Oil Pool Size Cemented Measured depth True Vertical depth 16" 200 Sx C.S. II 116' 116' 9-5/8" 770 Sx Permafrost E 2720' 2720' 370 Sx Permafrost C 7" 350 Sx Class "G" 6631' 6230' 250 Sx Permafrost C 6376'-6396' 6414'-6458' MD true vertical 6068'-6081', 6093'-6122' TVD " Co , Tubing (size, grade and measured depth) 3 1/2", 0-55 9.3 Packers and SSSV (type and measured depth) Packer: Camco Hydro-Set ~ 6280' HD~ SSSV: OTiS FHX-TR ~ 1920' HD 12.Attachments Description summary of proposal Fracture stimulate the C Sand w/ge]led diesel and 16/20 Carbo-Lite proppant. 13. Estimated date for commencing operation 05/20/88 14. If proposal was verbally approved ~~[ Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to thei3best of my knowledge _ Signed /~O,~,~ j'~ ~ .~ Title Commission Use Only Conditions of approval ORIGINAL SIGNED BY LONNIE C, SMITH Notify commission so representative may witness ~ Plug integrity [] BOP Test ~-, Location clearance Approved Copy Returned Commissioner Approval No. ~) . ~.~ ~; the commission Date Approved by Form 10-403 Rev 12-1-85 Submit in triplicate Kuparuk Well 2G-2 Well 2G-2 is currently an 'A' Sand-only producer. The 'A' Sand will be re-fractured to improve flow efficiency. A copy of the proposed procedure is attached. The fracture stimulation will utilize Carbo-Lite proppant and will use gelled diesel as the carrying fluid. A 10,000 psi 'tree saver' will be used during the fracture stimulation. Wellhead pressure/fluid level analysis indicates an average reservoir pressure of 2800 psig in the 'A' Sand. There is no gross C Sand interval present in this well. Messrs. Lyden and Wade May 12, 1988 Page2 Kuparuk Well 2G-2 'A' Sand Re-Fracture Procedure Charge Code: 230DS28GL 1. Obtain an 'A' Sand 24 hour well test. . MIRU Slickline unit. Tag bottom. Pull GLV's and Run DV's. Set blanking plug in Camco 'D' nipple at 6290' MD-RKB. Pressure test the tubing. Pull blanking plug. 3. Pump Diesel/10% Musol per the attached schedule. Shut down overnight to soak. 4. RU fracture equipment. Install "Tree Saver". Pressure up 7" annulus to 3500 psi. . Se Check diesel for contamination prior to gelling for frac. Obtain a sample of the proppant and of the gelled diesel with breaker. Check the prOppant for fines. Record proppant weight prior to pumping. After frac, verify and record weight of remaining proppant. Pump fracture treatment per the attached schedule. Record the 5, 10, and 15 minute pressures following the ISIP. Expected wellhead treating pressure: WHTPE = 3950 psig Fracture Gradient = 0.72 psi/ft (6094' TVD) Tubing Friction -- 270 psi/1000 ft (6302' MD) * If treating pressure during the job exceeds 6000 psi, shut down job and confer with engineering. 7. Rig down frac equipment. Follow attached flowback schedule. RECEIVED Alaska Oil & Anchorage KUPARUK WELL 2G-2 'A' SAND FRACTURE PUMP SCHEDULE 5112188 STAGE FLUID DESCRIPTION 1 DIESEL/10% MUSOL 50.0 2 DIESEL FLUSH 55.0 3 GD PRE-PAD 100.0 4 GDPAD 650.0 5 GD w/2 PPG 87.3 6 GD w/4 PPG 80.8 7 GD wi6 PPG 79.1 8 GD w/8 PPG 77.6 9 GD w/10 PPG 79.8 1 0 , GD FLUSH . , 55.4 +SV TOTAL UNGELLED DIESEL= 100.0 BBLS +SV TOTAL GELLED DIESEL = 1210.0 BBLS TOTAL MUSOL = 5.0 BBLS CLEAN VOLUME PUMP RATE PROP. COl'~. PROPPANT BBLS BPM PPG DESCRIPTION 5 0 - - 5 0 -- SHUT DOWN OVERNIGHT 25 0 - - SHUT DOWN FOR ISIP 2 5 0 16/20 M CARBO-LITE 0 25 2 16/20 M CARBO-LITE 7334 2 5 4 16/20 M CARBO-LITE 13568 2 5 6 16/20 M CARBO-LITE 19930 25 8 16/20 M CARBO-LITE 26084 25 1 0 16/20 M CARBO-LiTE 33525 25, , o ...... -- ,, 0, , 16/20 M CARBO-LITE -- 100440 LBS PROPPANT WT LBS DIRTY VOLUME STG/CUM HIT PERFS BBLS 0 50/ 50 0 55/ 1 05 57 107 0 1 00/ 1 00 57 650/ 750 1 57 95/ 845 807 95/ 940 902 100/ 1040 997 105/ 1145 1097 115/ 1260 1202 55.4/ 1315.4 1317 Stage 1 is Diesel with 10% Musol Stages 3 and 4 are Gelled Diesel with 40 lbs/1000 gal silica flour and enough breaker for an 8 hour break. Stages 5 through 9 are Gelled Diesel with 6 hour breaker and without silica flour. Stage 10 should include a volume adjustment for surface equipment between the wellhead and densitometer and Iow temperature breaker (6 hour break). This job is intentionally underflushed by 2 bbls. The blender tub should be bypassed at flush. All fluids should be maintained at 70° to 90° F on the surface. ARCO Alaska, Im Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 11, 1985 Mr. C. V. Chatterton Commissioner ' State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Well Completion Reports Dear Mr. Chatterton- Enclosed are Well Completion Reports for the following wells' 2F-10 2G-2 2G-8 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU5/LIO Enclosures RECEIVED Alasi(a 0il & Gas Cons. commission Anchorage ARCO Alaska, Inc. is a Subsidiary el AtlanticRichfieldCompany ~ STATE OF ALASKA .~'-~ ' ALASKA ~ AND GAS CONSERVATION C£ .~IlSSION W LL COMPL TIO# OR RECOMPLETIOI',I REPORT Al,ID LOG 1. Status of Well Classification of Service Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-121 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21153 4. Location of well at surface 9. Unit or Lease Name 487' FSL, 44' FEL, Sec.31, TllN, R9E, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1193' FSL, 884' FEL, Sec.31, TllN, R9E, UM 2G-2 At Total Depth 11. Field and Pool 1350' FSL, 1068' FEL, Sec.31, TllN, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 139' RKBI ADL 25656 ALK 2582 12. Date Spudded08/03/84 13. Date T.D. Reached08/08/84 14' Date C°mp" Susp' °r Aband' 115' Water Depth' if °ffsh°re 116' N°' °f C°mpleti°ns09/17/84 N/A feet MSL 1 17. Total Depth (MD+TVD) 18. PlugBack Depth (MD+IA/D) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 6675'MD,6258'TVD 6554'MD,6181'TVD YES [~[X NO []I 1919 feet MD 1500' (Approx) 22. Type Electric or Other Logs Run DIL/SFL/GR/SP/FDC/CNL/Cal, Gyro (GCT), CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 116' 24" 200 sx Cold Set; II 9-5/8" 36.0# J-55 Surf 2720' 12-1/4" 770 sx Permafrost E & ~70 sx Permafrost C 7" 26.0# J-55 Surf 6631' 8-1/2" 350 sx Class G & 250 s Permafrost C 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) 6434' - 6458' 3-1/2" 6300' 6271' 6414' - 6434' w/4 spf 6376' - 6396' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED See attached Addendum. 27. . N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO TEST PERIOD ~ I OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Flow Tubing Casing Pressure CALCULATED Press. 24-HOUR RATE ]~ 28. CORE DATA 3 1985 Al~"~,a u~l & Gas Cons. Cornrnissior~ Anchorago Form 10~407 GRU4/WC63 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate .. . NAME Include interval tested, pressure data, all fluids recover~ and gravity, MEAS. DEPTH TRUEVERT. DEPTH.~ GOR~ and time of_each phase. . .. . . , .. ,. Top Kuparuk B 6288~ 6008~ N/A Top Lower Sand 6360'.. 6057t Base Lower Sand 6564' 6188' . .: . . . .. . . . I "~ - ' - .... : . _. 31. LIST OF ATTACHMENTS , Addendum 32. I hereby certify that the foregoing is true and correct to the bes% of my knOwledge _ .. Signed ~~~ Title AssocSate EngSneer Date INSTRUCTIONS General: This form is designed for submitting a cOmplete and correct well completion report and log on all types of lands and leases in 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 sh°w 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". ADDENDUM WELL: 8/18/84 8/28/84 8/29/84 11/13/84 11/23/84 2G-2 Arctic Pak w/42 bbls PF "C", followed by 56 bbls Arctic Pak. Rn CBL/6" JB f/6549'-4275'. Rn GCT gyro f/surf-6510'. Begin frac@ 1534 hrs, 11/13/84. Howco frac'd Kup "A" perfs 6376'-6396' & 6414'-6458' in 10 stages per 11/12/84 procedure using gel diesel, 100 mesh & 12-20 sand. Pressured ann to 1000 psi w/diesel. Tst Ins to 5000 psi; OK. 1. Pmp 40 bbls of 135° diesel w/5% musol pad @ 10 BPM w/2350 psi 2. Pmp 44 bbls gel @ 18 BPM w/2400 psi 3. Pmp 32 bbls gel w/2 ppg of 100 mesh (2520#) @ 18 BPM w/2300 psi 4. Pmp 75 bbls gel @ 18 BPM w/2340 psi 5. Pmp 20 bbl gel @ 18 BPM w/2400 psi 6. Pmp 37 bbls, 1 ppg 100 mesh (1470#) @ 18 BPM w/2300 psi 7. Pmp 35 bbls gel @ 18 BPM w/2260 psi 8. Pmp 26 bbls 12-20 sand (2016#) @ 18 BPM w/2350 psi 9. Pmp 46 bbls, 7 ppg, 12-20 sand (10,290#) 10. Pmp 39 bbls (of proposed 62 bbls flush). Screen out @ 5000 psi Pmp'd 3990 psi of 100 mesh and 7150# of 12-20 in formation, leaving 5150# of 12-20 sand in casing. Load to recover 367 bbls of diesel. Job complete @ 1701 hrs, 11/13/84. RU Dowell, press tst @ 4000 psi. RIH, pmp'g .2 BPM gel diesel to 6300'. Inc rate to 1.6 BPM & start N~ w/350 SCF @ 3800 psi. Wrk CT f/6300'-6529'. Displ w~diesel, POH, RD. Secure well. ECEIVEb ,41~Ska ~Ct~orage (cont'd) WELL: 2G-2 11/24/85 6529' PBTD RIH w/2" bailer to 6306', jar dn to 6330', POH, found rubber in btm of bailer. RIH w/ 3/4" spear, set dn @ 6330', jar dn; unable to pass. Pull up to 6303', att to move tls past 6303' w/o success. Drop cutter bar; did not cut wire. Jar on wire; broke line @ counter. SI well. RU & RIH w/2-1/8" blind box to 6300', jar dn on fsh to 6459', POH. RU & RIH w/wire grabber, POH w/wire. RU fsh'g tls, RIH, set dn @ 6459'; unable to latch, POH. Add 2 knuckle its, RIH, att to latch fsh w/o success, POH. RIH w/2-1/2" impression block, POH; no indication of fsh visible. Will turn over to Production to flow w/TOF @ btm perf. PBTD w/CTU - 6529' - TT @ 6391' - Top Perf @ 6376' Btm Perf @ 6458' - TOF @ 6459' RECEIVED 1 1985 Alaska Ol~ & Gas Cons. Commission Anchorage DrillingfSuperint endent · Date ARCO Alaska, Ine" Post Office ...ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Date: 1/23/85 Transmittal No: 4925 RETURN TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 smitted herewith are the following items. Please acknowledge receipt return one signed copy of this transmittal. BHP REPORTS & SEQUENCE OF EVENTS 2B-l~ 10/16/84' "Static" SBHP 2B-i~~ 10/17/84 " " 2B-2)~ ..... _10/17/84 " " 2B-6~- .... 6/02/84 " 2B-10~~ 6/02/84 " 2B-11~ 6/03/84 " 2B-12N~ 6/02/84 " 2B-14~ 10/28/84 " " 2B-13y~~ 10/28/84 " " 2D-5-A .... 10/05/84· " ,,- 2G-l~ 9/21/84 "Static/G. Ring" 2G-2 +-~ 9/22/84 " " 2G-3 .~ ~ 9/23/84 " " 2G-4 ~ 9/23/84~ " " 2G-8 %--- 9/30/84 2F-15, -~ 4/13/84 2X-13~--12/18/84 2X-14~ 12/21/84 2X-15.~-12/23/84 2X-16)~12/21/84 Receipt Acknowledged: B. Currier BPAE Chevron D&M "St~tic/G. Ring/Tag;' SBHP lB-3 ~ ~':' .6126184 lB-4 ;~;: .~,-6/26/84 lB-6 Y: ::' .. 7 / 01/84 1E-2 ~" 6/22/84 1E-7 ~ ~-~ ~/14/84 1E-4 ~-- 10/15/84 1E-12 ~:.~ 6/24/84 1E-20~--' 6/23,22 1E-22f-~ 4/23/84 1E-25 ~.~ 6/23/84 1E-25g 11/09/84 1E-29-~ .... 6/23/84 1E-29~' 10/14/84 1F-4 x~-. 9/14/84 1F-4 ~-- 9/14/84 . 1;F-7 '~ -'- 7 / 05/84 1F-11t'~ 4/.25/84 1F-14~ ...... 2/07/84 1F-15%~ 2/14/84 10-1. ..... 6/29/84 ¢IG-i~ -- 9/13/84 /10-3~.~ ~/~6/s4 ~ 1G-5 -- 6/29/84 1H-4 ~' 6/24/84 1Y-3 ~ 1/21/84 1Y-5 T-- 5/06/84 1Y-9~'~ 5/06/84 1G-14.--' 1/12/84 1L-2e-- 10/21/84 iL-3 -~- Date: Drilling Geology Mobil NSK Ops. DISTRIBUTION W, Pasher G. Phillips Phillips Oil J. Rathmell SBHP " "Static" /84 " " "Static" II ,I II I! 11 11 II II II " "Static" 11 II II ,I ,I II II II II II II II II ,I II --_ State Union Well Files ARCO Alaska, InC?_.. Post Office : 360 Anchorage~ ,.,aska 99510 Telephone 907 277 5637 Date: 12/12/84 Transmittal No: 4911 RETURN TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 an ~°rage, AK 99510 ' smitted hereWith-are the following items. Please acknowledge receipt and return one signed copy of this transmittal. OH LIS 'TAPES -- Schlumberger #69837 2~112 7/10/84 #69835 2G-2 8/08/84 Run 1 3994.5 - 8476.5 Run 1 2707.5 - 6627 (Recomputed 12/10/84) (Recomputed 12/10/84) z..#69779 2W-7 11/15/84 ~-#69782 2E-15 11/17/84 Runs 1, 76.5 - 6358 (Reco~puted 12/10/84) 2 · . Runs 2, 2603 - 6956 (Rec6mputed 12/11/84) 3 · , /cat Receipt Acknowledged: B. Currier BPAE Chevron% D&M ;-, ~ v f~]L'k' -il'l ~c, ~:1~',~:3. u'~';'~ ....... 1 , Anchorage Date: Drilling Geology Mobil NSK Ops. DISTRIBUTION W. Pasher G. Phillips Phillips Oil J. Rathmell State of AK Sohio Union Well Files ARCO Alaska, Inc. ~ . · -'-,":~.,.. ,&=¢.:_.i,',:~ 9.[":51C ', ~,..:'.~,,:'r,c 9-C,." 277 $~37 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Date: 10/~84 Transmittal No: 4786 PAGE 2 of 2 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~2G-2 2"/5" DIL-STL/GR 2"/5" FDC-f/NL/GR "Poro" 2"/5" " ""Raw" CPL Cyberlook c,/os/ z cmo 8/08/84 " 6090 - 6570 8/08/84 " 6090 - 6570 8/08/84 " 6090- 6570 v/ 2D-9 2"/5" DIL-SFL/GR 8/08/84 :~m l 2"/5" Density Neutron Poro 8/08/84 " 2"/5" " " Paw 8/08/8~ " CPL Cyberlook 8/09/84 " 3895 - 7834 7250 - 7809 7250 - 7809 7450 - 7710 Anchor&:? /cat Receipt Acknowledged: B. Adams F.G. Baker P. Baxter BPAE Date: DISTRIBUTION D & M W.V. Pasher G. Phillips Drilling Phillips Oil Geology Mobil J.J. Rathmell State of Alaska Sohio Union Chevron R & D Well Files NSK Operations ~-7~ ~;%. ~K/t -~.--~ ...~-> _,~..~ .¢ , ARCO Alaska, Inc. ~, :,: ;..':cr.¢ 9[..- 277 $C37 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Date: Transmittal No: 4786 PAGE 1 of 2 Transmitted herewith are the following items. Please acknowledge zeceipt and return one signed copy of this transmittal. OH FINALS Schlumberger [,/2G-3 2"/5" DIL-SFL/GR 2"/5" FDC-C~qL/GR "Raw" 5"/2" " " '~Poro" RFr Quicklook CPL Cyberlook 8/17/84 Run 1 5C40 -- °=m~' 8/16/84 " 7950 - 8578 8/16184 " 7950 - 8578 8/16/84 " 8148 - 8311 s/16/s " s14s - s311 8/16/°-o4_ " ( 79 - 8580 1L-5 2"/5" DIL-SFL/GR ,~orO,' , , / ' F'OC-C / 2"/5" " ""Raw" CPL Cyberlo0k . 8/.CW-'3/C4 _-rkm 1 ...,.,,:,,.,'~'"-~ - 7750 8/06/84 "' 2323 - 7750 8/06/84 " 2323 - 7750 8/06/84 " 7750- 7100 8/06/84 " 7306- 7506 84 7306 ~06 2"/5" DIL-SFL/~ 8/14/84 2"/5" Density Neutron Raw 8/14/84 2"/5" " "Poro 8/14/84 CPL Cyberlook 8/14/84_ Run 1 ' 3162 - 8419 " 3162- 8395 " 3162 - S419 ' 7900- 8350 AFI~O Alaska, Ir~' ~:- Post Offic. Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 November 6, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2G-2 Dear Mr. Chatterton' Enclosed are the Well Completion Report and the gyroscopic survey for the subject well. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU2/L72 Enclosures RECEIVED b ov 0 819 4 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~ ---. ,'---- STATE Of ALASKA ..... ' - ~-~ ALASL ~..-- AND GAS CONSERVATION .. MISSION WI:LL COMPLETIOI'i OR RECOMPLETIOI'i REPORT AND LOG 1. Status of Well Classification of Service Well OIL I~x GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO A1 aska, I nc. 84-121 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21153 4. Location of well at surface 9. Unit or Lease Name 487' FSL, 44' FEL, Sec.31, T11N, R9E, UN ' LOCATIONS~' Kuparuk River Unit At Top Producing Interval VERIFIED 1 10. Well Number 1193' FSL, 884' FEL, Sec.31, T11N, RgE, UH u . 2G-2 At Total Depth . . _. 11. Field and Pool 1350' FSL, 1068' FEL, Sec.31, TllN, R9E, uM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) .I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 139' RKBI ADL 25656 ALK 2582 12. Date Spudded 13. Date m.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 08/03/84 08/08/84 09/17/84 N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.PlugBackDepth(MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set I21.Thickness°fPermafr°st 6675'MD,6258'TVD 6554'MD,6181 'TVD YES [] NO [] 1919 feet MD 1500' (Approx) 22. Type Electric or Other Logs Run D IL/SFI_/GR/SP/FDC/CNL/Cal, Gyro (GCT), CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 116' 24" 200 sx Cold Set II 9-5/8" 36.0# J-55 Surf 2720' 12-1/4" 770 sx Permafrost E & ;70 sx Permafrost C 7" 26.0# J-55 Surf 6631'~ 8-1/2" 350 sx Class G & 250 s: Permafrost C 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) 6434' - 6458' 3-1/2" 6300' 6271' 6414' - 6434' w/4 spf 6376' - 6396' 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO TEST PERIOD I~ I Flow Tubing Casing Pressure ~ !CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr} Press. 124-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE Alaska ,:,a.$ bo,qs. Oor_;Irn ss!o,q A~chora~e Form 10-407 GRU2/WC05 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ' ..... : : ." i' -:'~:~:" :'¥' ' " ........... ' ' ' ' ~' .... "'GEOLOGIC;UARKERS .... ~':-'- ~' '-:i! .-:?-' ::!': :'?' :" - : :~ '" :' -~'":' ,' '{' ::C:Fo~MATION TE~T~ '-.' ' .-? ": . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUEVERT. DEPTH . GOR, and time of each phase. Top Kuparuk B 6288' 6008' N/A Top Lower Sand 6360' 6057' Base Lower Sand 6564' 6188' . 31. LIST OF ATTACHMENTS W~ll Hi~nry (incl,,ding ~dd~nd,,m); Worknv~r Well 32. I hereby certify that the foregoing is true and correct to the best of my knowledge . Signed .~ Title Area Drilling Engr. Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals-for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". ARCO Oil lind Gee Company ~) Wall Hietory- Initial Report- Dally In~/~i~k)lll: PrepL'l Ind ~ubmlt t~e '.'InilIM Rel~' on the fll~t WedneKlay after a well is apudded or workover operatlona ere ~tarted. Dally wo~ prior to spudding Ihould be summarized on the form giving inclualve datel only. ICounty, paril~t or borough Istata DistrictAlaska I North Slope Borough I Alaska Field ILeue or Unit JWell no. Kuparuk River I ADL #25656 I DS 2G-2 ITItla I Drill, Complete & ?erforate Auth. or W.O. no. AFE 901059 Doyon #9 AP1 50-029-21153 O~rator ARCO Alaska, Inc. SpuddedorW.O. begun IDate IHour Spudded 8/03/84 0800 Hrs. Date and depth aa of 8:00 a,m. 8/03/84 8/04/84 thru 8/06/84 8/07/84 8/08/84 8/09/84 Complete record for each day reported IARCO W.I. · 56 24% IPrior status if a W.O. 16" @ 116' Accept rig @ 0530 hfs, 8/03/84. NU diverter sYs. 9-5/8" @ 2720' 5510', (5405'), Drlg Wt. 9.2+, PV 11, YP 11, PH 9, WL 7.8, Sol 6 Spud well @ 0800 hrs, 8/03/84. Drl 12¼" hole to 2740', C&C, 16 std short trip. RU & rn 68 jts, 9-5/8", 36#, J-55 BTC csg'w/FS @ 2720' w/FC @ 2638'. Cmt w/770 sx PF "E" @ 12.3 ppg, followed by 370 sx PF "C". Displ cmt using rig pmps, bump plug. CIP @ 0745 hrs, 8/04/84. ND diverter sys, NU & tst BOPE to 3000 psi. TIH w/BHA to 2638', tst csg to 1500 psi. DO cmt, FC, FS + hole to 2710'. Conduct formation tst to 12.5 ppg EMW. Drl & surv 8½" hole to 5510'. 3500', Assumed vertical 3670', 6.2°, N15.8W, 3669.47 TVD, 7.07 VS, 8.84N, 2.50W 4171', 13.9°, N28.7W, 4161.70 TVD, 74.69 VS, 98.16N, 23.14W 4785', 18.4°, N63.7W, 4755.13 TVD, 227.81VS, 184.57N, 149.58W 5334', 28.7°, N56W, 5258.93 TVD, 443.68 VS, 294.59N, 335.84W 9-5/8" @ 2720' 6290', (780'), Drlg Wt. 10.3, PV 12, YP 14, PH 9.5, WL 4.8, Sol 11 Drl & surv 8½" h~le to 6290'. 5667', 34.4°, N56W, 5542.59 TVD, 617.84 VS, 391.89N, 480.23W 6130', 42.6°, N53.3W, 5904.11TVD, 906.34 VS, 557.96N, 716.23W 9-5/8" @ 2720' 6610', (320'), Logging Wt. 10.2, PV 10, YP 12, PH 10, WL 4.8, Sol 11 Drl 8½" hole to 6610', 10 std short trip, C&C f/logs. RU Schl, RIH w/triple combo, unable to get past 6345', POOH, RD Schl. RIH to 6340', rm 6340'-6610', CBU, POOH. RU Schl, RIH w/triple combo. 6350', 47.25°, N50.5W, 6059.84 TVD, 1061.34 VS, 653.79N, 838.44W 6570', 52.8°, N50.5W, 6200.57 TVD, 1229.73 VS, 760.93N, 969.12W 7" @ 6631' , (65'), Cmt 7" Wt. 10.2, PV 13, YP 12, PH 9.5, WL 4.8, Sol 12 Rn DIL/SFL/GR/SP/FDC/CNL/CAL f/6602' WLM - 2717' WLM. Drl 8½" hole to 6675', circ, POH. Rn 165 jCs, 7", 26#, J-55 BTC w/FS @ 6631', FC @ 6554'. M&P 350 sx C1 "G" w/1% CFR, .5% KC1 & .3% Halad-24. Displ w/10.3 ppg NaC1/NaBr. A!aska Anchorage The above is correct Signature Ioate 8/30/84 ITM Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Inetruction$: Prepare and submit the "Final RIpo~t" on the first Wednesday alter allowable has been assigned or well is Plugged, Abandoned. or Sold. "Final Rel~rt" should be submitted also when operations are suspended for an indefinite or appreciable length ol time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Rl~ert" form may be used for reporting the entire operation il space is available. Accounting cost center code District ICounty or Parish Islate Alaska I North Slope Borough I Alaska Field ~Lease or Unit Well no. Kuparuk River I ADL 25656 DS 2G-2 Auth. or W.O. no: ~ Title AFE 901059 I Drl, Complete & Perforate Doyon #9 API 50-029-21153 Operator I A.R.Co. W.i. I ARCO Alaska, Inc. Spudded or W.O. begun I O.~t9 Spudded I 8/03/84 Oate and depth as o! 8:00 a.m. Complete record for each day reported Old TD Released rig Iotalnumber of wells (active or inactive) on this, ostcenterpriort0pluggingand ~w .5 bandonment of this well 6.24~ our IPri°r status if a .O I 0800 hrs 8/10184 thru 8/13/84 8/20/84 1000 hrs 7" @ 6631' 6554', (0'), RR 10.3 NaCl/NaBr Fin dispt'g cmt w/250 bbls 10.3 ppg brine. Bump plug. CIP @ 0700 hrs. 8/09/84. ND BOPE, NU tbg head, tst packoff to 3000 psi. RR @ 1000 hrs, 8/9/84. Operations suspended - wait on completion rig. Arctic Pak w/250 sx PF "C", followed w/57 bbls Arctic Pak. INew TO PB Depth 6675' (8/8/84) Kndofrig JDate 8/09184 Rotary Classifications (oil, gas, etc.) Oil Producing method Flowing Type completion (single, duel, etc.) Sin$1e Official reservoir name(s) Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effeclive date corrected The above is correct For form preparati;n and ~lstribution, Drilling Superintendent ADDENDUM WELL: 8/18/84 8/28/84 8/29/84 2G-2 Arctic Pak w/42 bbls PF "C", followed by 56 bbls Arctic Pak. Rn CBL/6" JB f/6549'-4275'; good cmt bond. Rn GCT gyro f/surf-6510'. Drilling Superintendent Gas Company .Daily Well - Illllllliml~i- ~ ~ ~ ~e "FII~I I~' on t~ fl.rl~ Wldnelday m~er mll~ll h~ ~ ~ or w~l I~ ~ug~, Aban~, ~ ~ld.' ~ ~ ~ ~ ~ml~ ~ ~ ~~~ f~ ~ In,tinge or =~l~e I~ ~ time. On wo~ wh~ ~ omcl~ t~ Il ~ ~-~ ~~~-cm~ ~ ~.~ In'bloc~ pm~ ~ '~ ~ fo~ mw ~ u~ for m~l~ ~e ~tlm ~ If Ip~l Ii ~. -... OIItrlct ICounty or Pad~ Lease or Unit Tltle IAccountlng coat.center code State. Alaska IWall no. 2G-2 Fleld Kuparuk Auth. or W.O. no. A~. 901059 Operator North Slope Borough ADL 25656 Drill, Complete & Perforate IA.R.Co. W.I. 56.24% IOat, 9/15/84 $~dded or W.O. begun Complete Date and depth as of 8.-tX3 a.m. Complete record for each day reported Old TD Released rig 9117/84 0600 hfs Iotal number of wells (active or inactive) on thi% oat center prior to plugging and / bandonment of this well our l prior ~tatua If a W.O. I 1900 hfs Classifications (o11, gas, etc.) Oil Producing method Flowing Potential teat data 7" @ 6631' 6554' PBTD, RR 10.3 ppg NaCl/NaBr Accept ri~ @ 1900 hfs, 9/15/84. ND tree, NU &tst BOPE; OK. RU Schl, perf 6434'-6458', 6414'-6434', 6376'-6396', RD Schl. RD_& rn 195 its, 3½" tbg w/SSSV @ 1919', Pkr @ 6271', "D" Nipple @ 6290'. ND BOPE, NU &tst tree to 5000 psi. Displ well w/30 bbls diesel, followed by 190 bbls crude. Set pkr. Tst ann to 1500 psi. Repressure tbg-to 4100 psi. Shear out ball. Set BPV. RR @ 0600 hfs, 9/17/84. INew TD I PB Dap,h 6554' Date Kind of rig 9/17/84 Rotary IType campletlm~ (single, dual, etc.) Single Official re~ervoir name(a) Kuparuk Sands Well no. Date Resewolr Producing Interval O11 or gas Teat time Production Oil on teat Gat per day · Pump size, SPM X lengtIi Choke size ~T.P. C.P. Water % GOR Gravity Allowable Effective date corrected O~!%!NAL $ UB-$ URFA CE DIRECTIONAL SURVEY r-'~l UIDANCE F~ONTINUOUS r-~ OOL Company Well Name Field/Location ATLANTIC RICHFIELD £0HPA.NY 2G-2 (S31.TllN. Rqr= U~,) KUP~RUK, NORTH SLOPE, -ALASKA Job Reference No. 69507 Logged By: G. JOHNSON Date 26-SEP-84 Computed By: P,.. KRUWELL Anchorage ~ SCHLI, iNBERGER ~ GC~J DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC, 2G-2 KUPARUK N. SEOPE, AbASKA SURVEY DATES 28-AUG-84 ENGINEER: RETHOD$ OF COMPUTATION TOOL 'LOCATION: TANGENTIAL- averaged deviation and azimut~ INTERPOLATIONs LINEAR VERTICAL SECTION: HORIZ, DIST, PROJECTED ONTO A TARGET AZIMUTH OF NORTH 55 DEG 27 MIN WEST ARCO AI,.ASKA, INC. 2G'2 KUPARUK N. SLOPE, AhASKA PAGE I , DATE OF SURVEYI 28-AUG-84 KEhhY BUSHING Eb£VATIONI COMPUTATION DATE: 24-SEP-84 ENGXNEER~ G JOHNSON I'N'rENPOI, ATED VALUES FOR EVEN 100 FEET (,)F MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAb VERTXCAb DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEC; 0 O0 00 O0 O0 O0 300 O0 4OO O0 500 00 600 00 700 O0 8O0 O0 900 O0 2O0 299 399 499 599 699 799 899 0 O0 '139.00 0 0 100 O0 '39~00" 0 16 139,00 FT N 0 0 E oo ooo 99 260i9999 0 14 N 56 41 E 99 360 0 10 N 56 57 E 99 460.99 0 9 N 55 2 E 99 560.'99 0 .110 N 50 6 E E 99 760.'99 0 36 N 1000 O0 VERTICAl, DOGLEG RECTANGULAR COORDINATES HORIZ, D_E_PARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST FEET DEG/IO0 FEET FEET FEET ,1 MIN 0 O0 '0i06 -0 44 -0 77 ~0' -1.08 -1,19 -1.28 -1,37 -1.49 1300 1400 1700 1800 1900 999 98 860 98 98 96O 98 98 1060 98 98 1160'i.~8 98 1260 8 98 1360 98 '98 1460 98 96 1560 96 95 1660 95 93 1760,93 O0 1099 O0 1199 OO 1299 O0 1399 O0 1499 O0 1599 oo O0 17 O0 1899 0 33 N 19 12 E -1.39 0 24 N 9 57 E -1,13 0 19 N 9 51 E -0.85 0 8 N 21 24 E -0.71 0 6 $ 15 55 E -0.62 0 3 N 28 36 w -0.52 0 24 N 32 15 W -0.19 1 1 N 31 33 W 1,06 1 8 N 30 1 W 2.85 0 45 N 29 32 W 4,40 h 53 49 W 5.40 N 49 47 W 6.34 N 57 51 W 7 10 N 84 39 W 7:81 S 80 51 W 8,55 S 52 47 W 8,92 $ 42 6 W 9,08 S 50 49 W 9,22 S 61 5 w 9.34 S 83 8 W 9.44 2000 O0 1999 93 1860,93 2100 O0 2099 92 1960,92 299 2400 O0 2399 2500 O0 2499 2600 O0 2599 27O0 O0 2699 2800,00 2799 2900,00 2899 0 32 0 3O 92 2060,92 0 21 92 2160,92 0 33 91 2260,91 O 25 91 2360,91 0 23 91 2460,91 0 23 90 2560.90 0 19 90 2660.90 0 7 90 2760.90 0 4 0 3 o 2 O 1 o 3 0 2 0 8 3'10 b 51 9 21 3757.. 71 11 41 N 43 20 w 9.53 N 45 7 W 9.61 N 18 1E 9.64 N 71 8 E 9,61 N 68 0 E 9.56 N 60 31 g 9.52 N 23 59 w 11,38 N 13 32 ~ 18,38 N 10 3 W 28,48' N 4 59 a 41.07 0 O0 0 33 0 1,5 0 14 0 03 o 03 0,04 0,07 0,20 0,23 0 21 0 04 0 13 0 14 0 06 0 15 0 64 0 22 0 21 0 69 0,09 0.16 0.35 0,10 0,26 0,19 (),16 0,19 0,12 0,13 0.07 0,25 0.05 0.26 0,06 0.46 4,76 3,54 2,91 2.86 0,00 N 0,07 N 0 34 N 0 62 a 0 85 N 1 04 a 1 20 N 1,38 N ,65 N ,25 N 3.18 N 3 91N 4 55 N 4 93 N 5 14 N 5 28 N 5 58 N 6 75 N 8 40 N 9 91N 10,66 N 11,23 N 11,72 N 11,88 N 11,88 N 11.64 N 11,15 N 10,70 N 10,48 N 10,43 N 10 46 N I0 52 N 10 55 N 10 57 N 68 N 12 68 N 21 11N 35 09 N 53,31 N 0,00 E 0,12 E 0.77 E 1,36 E 74 g O3 E 2 28 E 2 51E 2 80 E 3 35 g 3,87 E 4,07 g 4,16 E 4,26 E 4,29 E 4,27 E 4,08 E 3,36 E 2,33 g 1,48 g 0,78 E 0.03 E 0,55 W 1.30 W 2,20 W 2,81 W 3,34 W 3.82 W 4,12 w 4,28 W 4.37 4.42 4,44 4,39 20 5,08 7,78 10,41 13,16 o E 33 E N)~ 59 E 4~ ~ ~0 E 2S N ~'9 31 E 5 O1 N 50 37 E 5 6 6 6 6 6 7 8 10 64 N 46 8 E 17 N 42 27 E 52 m 40 50 E 0 N 39, ~ E ~9 N 38 E 91 N 36 9 E 54 ~ 26 29 E 2 N 8 E 10 b8 ,~ 4 9 E Il 74 N 2 41W 11 95 N 6 14 W 12 08 N lO 30 W 11 97 N 13 35 W 11 64 s 1639 ~ 11 ~6 S 19 39 W s 21 29 ~ ). 11~26 11.27 S 22 18 ~ 11,34 N 22 38 W 11,41 N 22 48 w 11,45 N 22 49 W 11,45 ~ 22 32 W 1.45 N ~ 4 W ~1,48 N 28 W && 13,66 N 21 50 W 22.50 N 20 ,4 w 36,61 h 1631 W 54.91 h 13 51 W 3000 O0 2999 90 2860,90 3100 32O0 3500 36O0 37O0 38O0 39OO O0 3099 90 2960,90 O0 3199 90 3060,90 90 3260,90 O0 3499 90 3360,90 · 00 3599 87 3460,8~ O0 3699.45 3560,45 O0 3798.43 3659.'43 O0 3896.71 ARCO ALASKA, INC, 2G-2 KUPARUK N, SLOPE, AEASKA COMPUTATION DATE: 24-SEP-84 DATE OF 6URVEY= 28-AUG-84 KELbY BUSHING EhEVATiON: 139.00 FT ._ ENGINEER: G JOHNSON ,INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH VERTICAl,, DOGLEG SECTION SEVERITY FEET PEG/lO0 TRUE SUB-SEA COUR6E MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MI'N DEG RECTANGU[,AR COORDINATES HOR~Z, DEPARTURE NORTH/SOUTH EAST/WEST FEET FEET FEET' 4000 O0 3994 29 3855,29 13 31 4100 O0 4091 20 4200 O0 4187 93 4048,93 14 4 4300 O0 4285 14 4146,14. i. 3 ,17 4400 O0 4382 39 4243,39 13 37 4500 00 4479 39 4340,39 14 48 4600 00 4575 52 4436,52 17 4 4700 O0 4670 69 4531.69 18 31 4800 O0 4765 24 4626~24 19 28 4900 O0 4859 22 4720.22 20 21 N 1 6 E 53,57 1,90 N 9 31W 68.82 3.35 99 N 25 18 W 88 69 3,88 123 N 39 45 W 110123 3 26 143 N 53 29 W 133 16 3:36 159 N 62 16 W 157~40 2,49 172 N 63 59 W 184,66 2,05 184 N 62 58 W 215.04 0.92 198 N 60 49 W 247,35 1,62 213 N 58 10 W 281,46 0,56 230 5000 O0 4952 61 4813.61 21 50 5100 O0 5044 79 4905',79 23 48 5200 O0 5135 45 4996.45 26 5300 O0 5224 36 5085,36 28 28 5400 O0 5311 34 5172.34 30 38 5500 O0 5396 45 5257.45 32 43 ~600 O0 5479 68 5340.68 34 700 O0 5561 79 5422,79 35 5800 O0 5642 58 5503.58 36 48 5900 O0 5721 73 5582',73 38 47 N 57 27 W 317.15 N 56 59 W 355,90 N 56 59 W 398.06 N 5b 59 W 443,79 N 56 48 W 493,12 N 56 19 W 545,60 N 55 21W 601,02 N 54 39 W 658.08 N 53 50 W 717,01 N 53 18 '~ 778.08 2,33 2.38 2,18 2,19 1,85 2,08 1,04 1,73 1,26 2,66 1.99 1,55 1,26 64 0,00 §:oo O0 N 52 57 W 842.18 N 52 20 W 908,72 N 50 41 W 977,31 N 49 6 W 1048,17 N 49 6 W 1121,69 N 49 40 W 1197.94 N 49 40 W 1275,17 N 49 40 W 1333,09 75 15 N 68 N 86 N 22 55 N 34 54 N 51 O9 N 7 49 N 9~ Ol N 124 16 N 153 13 29 W 76 14 92 W 10 0 40 W 125 16 W 54 W 72 N 182 0 1 W 86 W 294 40 N $8 2 W 270,74 N 245,68 W , N 42 N , w . ia . 318,70 N 319,38 W 451,19 N W 345 62 N 360.73 W 499.58 N 4~ 13 W 374 49 N 404,57 W 551,29 N47 12 W 405 61N 450.43 W 606.14 N 47 ~9 W 438 36 N 497,16 W 662,82 N 48 35 W 472 72 N 545,04 W 721.48 N 49 3 W 509 10 N 594,15 W 782,43 N 49 24 w 547 55 N 645.49 W 846.45 N' 49 41 630 69 N 752,31 ~ 981.70 N50'1 676 57 N 806 76 W 1052,90 N 50 0 725 14 N 862 58 w 1126,88 N 49 56 77~ 03 N 920~ W 1203.~6 N i~ ~ 82~ 25 N 979 .. w 1281. 8 N 862 92 N 1024 38 W 1339.39 N 4953 6000 O0 5798 44 5659,44 40 48 oo:oo ol 6200 O0 5945 61 5806.61 44 22 58764 82 , 6300,00 6015 82 46 35 6400.00 6083 08 5944,08 4~ 55 6500.00 6147 26 6008.26 50 54 6600,00 6210 31 6071,31 50 54 6675.00 6257 59 6118,59 50 54 ARCO AL, A,.SKA, INC, 2G-2 KUPARUK N. SLOPE, ALASKA COMPUTATION DATEC 24-SEP-84 ,, ENGINEER~ G JOHNSON INTERPDL'ATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPT .. TRUE SUB-SEA COURSE MEASURED VERTICAL YERT'IC'A'5 DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN o oo o oo -~ oo o o ,ooo oo ~ ~ ,~o ~ooo oo ~9~ ~ ~6o ~o ~ ~ooo oo ~ ~o ~o~o o ~ 4000 O0 3994 5000 O0 4952 481~ 61 21 50 6000 O0 5798 44 5659.44 40 48 6675 O0 625759 6118.59 50 54 N 0 o E N 19 12 E N 53 49 W N 43 20 w N ! 6 E N 57 27 W N 52 57 w N 49 40 W 1333,09 PAGE DATE, OF SBRVE¥~ ~8,,,AUG~IiI~ KE;I~LY iitUSHING E~EVATIONI~ 1~9,00 FT VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST FEET DEG/IO0 FEET FEET FEET DEG 0 O0 0,00 0 O0 N 0,00 E O, I0 N 0 0 E -1:39 0.21 3 18 N 3.87 E 5, 37 E 5 40 0,09 10 66 N 0,78 E 10 9 E 9:53 0,07 10 46 N 4,37 W 11 53,57 1,90 75 15 h 13,29 W 76 317,15 2,33 249 74 N 213.10 W 328 842,18 1,99 547 55 N 645 49 W 846 41 0,00 862 92 N 1024:38 W 1339 ARCO ALASKA, INC,' IG'2 UPARUK N. SLOPE, ALASKA COMPUTATION [)ATE: 24-$EP-84 TRUE SUB-SEA COURSE MEASURED VERTICAL 'VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MI~ : 0 O0 '139,00 0 0 39 O0 -100,,00 9 139 O0 0,,00 0 23 239 O0 100,00 0 23 339 O0 200,,00 0 15 439 O0 300,00 0 12 539 O0 400,00 0 10 639 O0 500.00 0 10 739 O0 600,00 0 12 839 O0 700,'00 0 26 0 38 0 25 O0 1000 0 23 O0 llO0 O 14 0 5 0 1400 0 10 0 44 I 6 ! 2 0 34 0 32 0 8 o 0 32 0 23 0 24 0 24 0 14 0 6 0,00 54,32 139 O0 239 O0 339 O1 439 01 539 O1 639 O1 119.01 9,01 939 O0 800 O0 O0 900 00 O0 O0 O0 O0 O0 gg oo 00 O0 1700,00 939,01 1039.02 101~ ! 39o02 11 239,02 1239 i339.02 1339 1439 1439 02 1539 02 1539 17 04 1739 1839 06 1839 07 1939 O0 1800,00 08 2039 O0 1900 O0 oo .,oo 08 39 0 ' 08 39 210 .00 09 2339 O0 2200,00 09 2439 O0 2300,'00 09 2539 O0 2400,00 10 2639 O0 2500,00 0 2739 O0 2600,00 0 2839 O0 2700,00 2339 2639 2739 2839 2939,00 2800,00 0 3 lO 3039,00 2900,00 0 2 0 3139,00 3000,00 0 1 0 3239,00 31~0,00 0 1 ~0 3339,00 3200,00 0 3 10 3439,00 3300,00 0 4 10 3539,00 3400,00, 0 45 24 3639,00 3500,00 4 43 89 3739,00 3600,00 8 2 19 3839,00 3700.00 10 27 DATE OF SURVEYI 28-AUG-84 KELLY BUSHING ELEVATION: ENGINEER: G jOHNSON 'INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB'SEA DEPTH VERTICAl.. DOGLEG RECTANGULAR COORDINATES HORIZ SECTION SEVERITY NORTH/SOUTH EAST/WEST DX~! DEG MIN FEET DEG/IO0 FEET FEET FEE~ N 0 0 g 0,00 N 64 30 E 0.00 N 68 47 E -0,19 N 66 3 E -0.58 ~{ 59 3 E -0 85 N 55 53 E -1' N 57 33 E -1'01 ,12 N 52 46 E '1,23 N 47 45 E -1,32 N 43 16 g -1.41 N 31 33 g -1.49 N 17 38 E -1.29 N 7 31 E '1,02 N 13 4 E '0.77 N 10 8 E '0,69 N 12 34 W -0,58 N 31 38 W "0,46 h 31 34 W 0,16 N 32 46 W 1,72 N 29 24 w 3.52 N 42 40 W 4.81 N 53 0 W 5,77 N 48 30 W 6,67 N 78 8 W 7,34 N 89 38 W 8.13 S 72 22 w 8,73 S 48 22 W 8,99 S 4b 33 W 9,12 S 51 59 W 9,27 $ 70 33 W 9,38 N 80 2 W 9,47 N 54 21 w 9.56 N 23 48 W 9,63 N 55 27 g 9,64 N 61 22 E 9,59 N 77 4 E 9.54 N 20 15 W 9,68 N 19 17 W 13.64 N 10 36 w 22.16 N 9 30 W 33.46 0 O0 0 04 0 24 0 13 0 16 0 14 0 02 0 04 0 08 0 55 0,22 0,51 0,12 0 31 0 10 0 31 0 39 0 91 0 19 o,28 0,25 0,07 0,17 0,34 0,10 0,16 0,18 0,12 0,27 0,13 0 11 0 03 0 O6 0 12 0 11 0 17 ,92 ,44 2,26 2,37 0 O0 N 0 O0 N 0 15 N 0 46 N 0 71 N 0 94 N lION 1 27 N ,47 N ~,82 N 2,60 3,50 4,18 4 75 N 5 O1 N 5 22 N 5 34 N 5 90 N 7 36 N 9 05 N 10,27 10.87 11.45 11.81 11.90 11.81 11.47 10,96 10,58 10,44 10,43 N 10,48 N 10,53 N 10,56 N 10,58 N 10,62 N 10,90 N 15,22 N 2b,21 N 42,09 N 0,00 0,00 0,34 1,03 2 13 E 2 37 E 2 61 2 97 3 60 3 98 4 11 4 20 E 4 29 E 4 29 E 2 97 E 1 96 E 1 24 E 0 48 g 0 22 0 78 I 67 2,46 3,02 3,53 3,97 4,20 4,32 4,39 4,44 4.44 4,35 4,27 4,25 6,09 8,85 11,65 0 0 0 2939 10 3039 3139 3239 3339 3439 3539 3639 3739 3841 PAGB '4 139,00 FT :PARTURE MUTH 0 E 0 E 49 E 4i E 57 E 24 E 1 2 2 33 E 3 48 N 58 29 E 5,30 h E 5,86 N 44 32 E 6,34 N 41 30 E 76 ~ 39 g 4 N 21 59 E N I 13 E 10 34 N 6 51 E 10 88 N 2 30 E 11 45 N I 5 W 11 84 N 3 46 W 12 02 N8 0 W 11 51 N 17 49 W 11 30 ~ 20 34 W ,t, 11,25 N 21 53 W , 11, N W 11,43 N 22 50 W 11,46 N 22 46 W 11.44 N 2¥ }I W 11,45 N 2 W 11,70 N 21 {8 W 16,39 N 2! 48 W 27,66 N 18 40 W 43,67 N15 28 W ARCO AbASKA~ INC, 2G-2 KUPARUK N, SEOPE~ AbASKA COMPUTATION [)ATE; 24-SEP-84 PAGE DATE OF SURVE¥I 28-AUG-84 KELLY BUSHING EbEVAT1ON{ 139,00 FT ENGINEER: G JOHNSON 'INTERPOLATED VALUES F'OR EVEN 100 FEET OF SUB-SEA DEPTh TRUE SUB-SEA CDLJRSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG SIN DEG Mlu i5 3939 O0 3800,.00 ii 29 5 4039:00 3900,'00,, 11 48 4139,00 4000,00 ~4 47 58 4239,00 4100,00 13 30 36 4339 O0 4200,00 '13 3! 30 4439 O0 4300,00 14 7 87 4539 O0 4400,00 16 15 62 4639 O0 450.0,00 18 8 19 4739 O0 4600,00 19 13 44 4839 00 4700,00 20 14 3943 4046 41.49 4252 4355 4458 4561 4666 4772 4878 VERTICAL Dr]GLEG SECTION SSVERZT¥ FEET PEG/lO0 $ 4 15 E 46.53 N 3 16 W 59.94 N 17 4 W 78,25 N 33 3 W 99.86 N' 46 57 W 122 74 N 59 44 ~ 147~08 N 63 17 W 173.80 N 63 42 W 204.63 N 61 50 W 238,20 N 58 24 W' 273,98 N 57 34 W 311.74 N 57 1 w 353,34 N 56 58 W 399,79 N 56 58 W 451,80 N 56 43 W 509.72 N 55 50 W 573 48 N 54 50 W 642:06 N 53 53 W 714,34 k 53 17 W 792.10 N 52 41 W 877,84 4985 35 4939 O0 4800,00 21 30 O0 4900,'00 23 39 O0 5000,00 26 7 O0 5100,00 28 50 O0 5200,00 31 15 O0 5300,00 33 43 O0 5400,90 34 59 O0 5500,.00 36 45 O0 5600,00 39 21 00 5700,00 41 54 67 5039 95 5139 69 5239 26 5339 88 5439 14 5539 54 5639 25 5739 04 5839 5093 5203 5316 5432 5550 5672 5795 54 76 5939 O0 5800 §0 44 13 96 6039 00 5900:, 0 47.21 90 6139 O0 6000 ~)0 50 54 51 6239 O0 6100:' 0 50 54 O0 6257 59 6118,59 50 54 6486 6645 6675 N 50 49 W 970.87 N 48 56 w 1072,83 N 49 40 ~ 1187.83 N 49 40 W 1310.32 h 49 40 W 1333,09 RECTANGULAR COORDINATES HORIZ, DEPARTURE NORTH/SOUTH EAST/WEST FEET FEET FEET ~IN 2,82 3,22 4 ~5 3 41 3 35 2 25 2 34 I 58 ! 39 0 69 62 35 N 86 112 134 152 167 179 193 208 226 13,56 w 63 ~ W 17 N 13,44 W 87 W 13 N 17 80 w 113 N I W 73 N 28 48 W 137 56 W 84 N 43 78 ~ !58 59 W 11N 63 50 W 178 48 W 62 N 87 34 W 199 55 W 29 N 115 35 W 225 49 W 76 N 145 46 W 254 44 N 34 52 ~ 78 N 176 50 W 287 37 N 37 53 W 2,25 2 3O 2i17 2 17 2,05 1,89 0,88 1,27 2,47 1,95 246,83 N 208,54 W 323 13 N 40 1~ W 269 35 N 243 54 w 363 13 N 42 W 282:48 W 408 1 N 43 47 W 294 69 N 323 06 . 326 lO w 459 354 72 N 374 61 W 515 390 05 N 427 71 W 578 429 12 N 48407 w 646 471 15 N 542 88 w 718 517 47 N 605 40 ~ 796 569 13 N 673 93 w 882 03 N 45 16 W 9i N 46 33 ~ 86 N 47 38 W 89 N 46 26 w 82 N 49 2 W 42 N 49 28 W 10 N 4949 W 1.94 2 53 0:00 0,00 0,00 626,61 N 747,30 W 975 24 N 50 I W 692".b N 825,48 w 1077 72 N 49 59 . 768;45 N 913,05 w 1193 39 N 49 54 W 848.11 N 1006,92 W 1316 50 N 49 53 W 862;92 N 1024,38 ~ 1339 39 N 49 53 W ARCO ALASKA, INC, 2G-2 KUPARUK N, SbOPE~ ALASKA NARKER TOP K, UPARUK B TOP bOWER SAND PBTD BASE LOWER SAND TOTAL DEPTH COMPUTATION DATE: 24-SEP-84 iNTERPOLATED VA6UE6 FOR CMO,SEN HURIZ(3NS .MEASURE[) DEPTH SEt, OW ~B 6288 O0 6360 00 6554 00 656400 6675 00 PAGE 6 DATE OF SURVEY: 28-AUG-84 KELLY BUSHING ELEVATION~ 139.00 FT' ENGINEER: G JOHNSON SURFACE 60CATION TVD RECTANGULA FROM KB SUB-SEA NORTH/SOUTH b007,55 5868 55 670 88 N 6056.54 59i7:54 705 51 N 6181,3~ 6042,3~ 802 [5 N 6187.6~ 6048.b~ 807 ~7 N 6257.59 61~8.59 862 92 N EST 7 W 9 W , UM ARCO ALASKA, IN¢, 2G-2 KUPARUK Nm SLOPE, ALASKA MARKER TOP KUPARUK B TOP bOWER SAND PBTD BASE LONER SAND TOTAL, DEPTH COMPUTATION DATE: 24-SEP-84 MEASURED DEPTH BELOW Kh 6288 00 6360 O0 6554 O0 6564 00 6675 0o PAGE 7 DATE OF SURVEY= 28-AUG.,84 KELLY BUSHING EbEVATIONI ,139,00 FT ENGINEER: G jOHNSON SUMMARY FEb.SEC R9E RECTANGUCA~ ?ES' NORTH/SOUTH EST ORIGIN= 487' FSL, 44' TVD ?'RO~ KB SUB-SEA 5868 55 5917 54 6042 31 6048 61 6118 59 670 88 N 705 51 N 8 17 N 862 92 N 6007,55 6056,54 618 61 6257 59 76 W 8 W 8 W FINAL WELL LOCATION AT TDI TRUE SUB-SEA MEASURED VERTICAL' VERTICAL DEPTH DEPTH DEPTH 6675,00 6257,59 6118,59 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG 1339,39 N 49 53 W UM SCHLUMBERGER ARCO ALASKA INC. 9'0-2 KUPARUK NORTH SLOPE, ALASKA 28 AUOUST 1984 TVW PLOT FROM OCT DATA JOB REFERENCE 89S07 WELL. 2G-2 SURFACE LOCATION: 487' FSL, 44'-FEL, S31, T11N, RgE, UM HORIZONTAL PROJECTION NOi~TH 800 6OO 400 2OO -200 -4O0 -600 ~'~H .-QO0 WEST REF 6~? 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L-..=--.-=-.-~ ....... ~ ....................... ~ .............. .-~--T .... ~-~ ...... . . . 1'400 - 200 - 10~ -800 -~00 -400 -200 O 200 EAS' SE WELL. 2G-2 SURFACE LOCATION- 487' FSL, 44' FEL, S21,'TllN, R9E, UM VERTICAL PROJECTIO)! -400 -200 0 0 200 400 600 800 1000 ! 200 NW - Suggested form to be inserted in each "Active" well folder to d~.eck for timely compliance with our regulations. ' - O~erat°r, /Vel 1' Name and Number Reports and Materials to be received by: Required Date Received Remarks . Ccmpletion Re~ort Yes //--~F-~ ~c~ _. Well History Yes P/ Core Chips -' · Core Description -///~-/~'?~.~ .Registered Survey plat y~___..~ . Inclination Survey -~/~ . Digitized Data ye:5 ARCO Alaska. Inc. - - - ,-:; .,.;kc.. _o~'51C ', ~: ;.r:c.r.c 95~ 277 5C37 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk AT0-1115B P.O. Box 100360 Anchorage, AK 99510 Date: 10/18/84 Transmittal No: 4786 PAG~ 1 of 2 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. OH FINALS Schlumberger 2G-3 2"/5" DIL-SFL/GR 2"/5" FDC-C~qL/GR "Raw" 5"/2" " " '~oro" RFr Quicklook CPL Cyberlook 8/17/s4 8/16/84 8/16/84 8/16/84 8/16/84 8/16184 Run 1 3240 - 8598 " 7950 - 8578 " 795O - 8578 " 8148 - 8311 " 8148 - 8311 " 79 - 8580 1L-5 2-"/5" DIL-SFL/GR 8/06/g4Run 1 2323- ?750 .,) 2,~.'/~c;c~l~ "row' s/~/~ " 23~3- 77~o ~"/5" "~w" 8/~/~ " 2323- 7750 ~L ~berl~k 8/~/~ " 7750 - 71~ ~ 8/~/~ " 73~ - 7506 ~ ~~l~k 8/~/~ " 73~ - 7506 2B-3 2"/5" DIL-SFL/GR 8/14/84 Run 1 3162 - 8419 2"/5" Density Neutron Raw 8/14/84 " 3162 - 8395 2"/5" " " Poro 8/14/84 " 3162 - 8419 CPL Cyberlook 8/14/84 ' 7900 - _ - _. , ~ ~-~;,~ ,? . ~-"M.-'"- ..~.:>:" .- ,,., B. Adams F.G. Baker P. Baxter BPAE D & M W.~;. Pasher G. Phillips Dzilling Geology Mobil J' J' Rathmell C. R. smith State of Alaska Sohio Union Chevron NSK Operations R&D Well Files ARCO Alaska. Inc. · - '-,";~ ~'.-. a 99,51C -,.,.;;:cnc ~,. ,,77 5[37 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Date: 10/18/8~ Transmittal No: 478~ PAGE 2 of 2 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2C~2 2"./5" DIL-SFL/GR 2"/5" FDC-~/C~ '~Poro" 2"/5" " ""Raw" CPL Cyberlook 8/0S/C/~ Run 1 C(Y30- 2717 8/08/84 " 6090 - 6570 8/08/84 " 6090 - 6570 8/08/84 " 6090 - 6570 2D-9 ' DIL-SFL/GR ' ~)ensity Neutron Poro CPI, Cyberlook 8/08/84 Run 1 3895- 7834 8/08/84 " 7250 - 7809 8/08/84 " 7250 - 7809 8/09/84 " 7450- 7710 /cat Receipt Acknowledged: B. Adams F.G. Baker P. Baxter BPAE Chevron Date: DISTRIBUTION D & M Drilling Geology Mobil NSK Operations W.V. Pasher G. Phillips Phillips Oil J.J. Rathmell R & D State of Alaska Sohio Union Well Files ARCO Alaska, Inc .... --' ,':;. .--:a~ka · - ;''-c:,; ~-['? £T7 Date: 1.0./~84 Transmittal No: 4765 Return To: · ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 ! ' Anchorage, AK 99510 Transmitted herewith are the following it~-.s. and return one si~ned copy of this transmittal. Please acknowledge receipt CBL' s FINALS/Schlumberger 2V-8A "Variable Density" "GCT" 2G-1 ~ " " " 8/01/84 Run 1 8/27/84 " 7400 - 8909 5151 - 7991 8/27/84 " 8/27/84 ~" 4275 - 6536 5950 - 8526 2G-4 .._ " " " 8/27/84 " 5070 - 7650 7/31/84 " 6500 - 7830 2H-13 " " " " 2H- " " " 7/30/84 " 7/30/84 " 6100 - 7720 7200 - 8732 2H-16 . " " " · 2D-11 J " " " 2D-9 "' " " " 2D-12 /' " " '" 2D-10 --- " " " Receipt Acknowledged: B. Adams F.G. Baker P. Baxter BPAE Chevron 7/30/84 " 6100- 7422 7/30/84 " 8/25/84 " 8/25~84 " 8/25/84 "~ 8/25/84 " DISTRIBUTION D&M W.V. Pasher G. Phillips Drilling ~' Phillips Oil Geology ,' ~-" Mobil J' J' Rathmell 7000 - 8410. 5900- 7588 6700- 7768 6900 - -,,.,,., ,--:;-? ~ ~- ~;,z ~i ~ 4850 '-'~' " ' ' ' ' ~.~as~a 0il & ~as Cons. Commissk C, R, Smith .... Sohio Union NSK Operations R & D Well Files ARCO Alaska, Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 14, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Enclosed are the Monthly State Reports for the following wells: 2G-2 1L-5 2G-3 1L-6 2G-4 1L-7 2D-9 2B-3 2D-8 2B-2 2D-7 2B-1 Thank you. Sincerely, Area Drilling Engineer JBK: ih L01 06/28/84 Enclosures $EP 1 9 lgg ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OFALASKA ~' ~ ALASK,. ,)~L AND GAS CONSERVATION L,.,,...~IISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [~-'~ Workover operation [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 4. Location of Well at surface 99510 487' FSL, 44' FEL, Sec. 31, TllN, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) Pad 102, RKB 138 6. Lease Designation and Serial No. ADL 25656 ALK 2582 7. Permit No. 84-121 50- 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 2G-2 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of August ,19 84 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spud well @ 0800 hrs 08/03/84. Drld 12-1/4" hole to 2740'. Ran, cmtd & tstd 9-5/8" csg. Drld 8½" hole to 6610'. Ran logs. Drld 8½" hole to 6675'TD as of 8/08/84. Ran, cmtd & tstd 7" csg. Secured well and released rig @1000 hrs, 8/09/84. Performed Arctic Pak. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 9-5/8" 36# J-55 BTC csg w/shoe @ 2720' cmtd w/770 sxs PF "E" & 370 sxs PF "C". 7" 26# J-55 BTC csg w/shoe @6631'. Cmtd w/350 sxs class "G". 14.l~D/b~ng resume and brief description 15'~-][%s/g~'Ln/~P~§F~JS~CNL/CAL f/6602' to 2717' RECEIVED 6.~E)/~ data, perforating data, shows of H2S, miscellaneous data SEP 1 9 -,984 Alaska 0il & Gas Cons. Commission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ Area Drilling Engineer SIGNED TITLE DATE · NOTE--Repo~ o~t~j~/xf~rm is required for each calendar month, regardless of the status of operations, and must be f~fed in duplicate with the Alaska Oil and G~~j~'n Commission by the 15th of the succeeding month, unless otherwise directed· ¢,,,,~ ~n_ar~z~ v Submit in duplicate ARCO Alaska~'' ~-:.- ,D _ ~,-~ 36C' ~'.::c~;orag,::. Aiaska 99510 T~!ephone 9C7 277 5637 Date: 8/20/84 Transmittal No: 4695 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 ~ed herewith are the following items. and return one signed copy of this transmittal. Please acknowledge receipt TAPES Schlumberger /~~OH RFT #69441 8/06/84 Run 1 1L-5 H LIS #69441 8/06/84 " 1L-5 #69442 8/08/84 " 2G-2 /OH,LIS #69375 7/21/84 2D-11 ~~OH LIS #69414 8/04/84 " 2B-4 /cat Receipt Acknowledged: 2294 - 7825.5 2707.5 - 6627 3566.5 - 7611 3524 - 9424 Date: DISTRIBUTION B..Adams D & M W.V. Pasher G. Phillips F.G. Baker Drilling Phillips Oil P. Baxter Geology BPAE Mobil J.J. Rathmell R&D Chevron NSK Operations C. R. Smith Sohio Union Well Files ARCO Alaska,~ Post Oh,,.~ box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 21, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - 2G Pad, Wells 1-4 Dear Elaine' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, O. Gruber Associate Engineer JG/tw GRU8/LI08 Enclosure If ARCO Alaska, inc. is a Subsidiary of AtlanticRichfieldCompany SEC 31 o5 o6 o8 SEC 6 NOT TO SCALE 32 TIIN TION LOCATION MAP I, SCALE' I :IMILE D.S. 2.G SEC $2 TilN T ION SEC 5 · I ~ ~..~ I I DR SITE 2, G CONDUCTORS AS' BUILT LOCATIONS LOCATED IN T I I N, R 9 E, SEC. 31, UMIAT MER.. WELL NO. I EL. 102.90', O.G. 98.8' Y = 5 944 015.121 LAT. 70° 15' 29.7334" X = 508 649.964 LONG. 149°55'48.314-'' 45' FEL 427' FSL WELL NO. 2 Y: 5 944 075.037 X = 508 649.9920 44' FEL EL. 102.73', O.G. 98.6' LAT. 70015'30.3228" LONG. 149°55'48.311" 487 FS L WELL NO. 3 Y = 5 944 135.052 X: 508649.9700 ! 44 FEL EL. 102.51' ' , O.G. 99.0 LAT. 70015' $0.9131" LONG. 149°55'48.310" 547' FSL '.. WELL NO. 4 Y = 5 944 195.029 X = 508 649.9880 44' FEL EL. 102. I0', O.G. 99.2 LAT. 70°15'31.5030'' LONG. 149055'48.307'' 607' FSL -'""' 4' . --... ... - . ~ NE~LdY CERTIFY THAT i AM PROPERLY REGISTERED L;CE%SE" TO PRACT;CE LAND 5UR~'EYING IN THE STATE OF ALASKA ~ THAT TH~5 PL~T REPRESENTS A SURVEY MADE UNDER MY ~iRFCT SUPERVISION ~ THAT ALL OETAILS ARE 'CORRECT AS OF ~ , ~,~5~ 'ARCO "Ai~ko,' Inc. ~ ~'~'t ~-~' Kuporu, Project North Slope P. ~,m,,~))'~' OR1LL SITE-2. G ~.~U~ ~:~ CONDUCTOR AS-BUILT ~d~'~]~a,.,. ~ ~- ~ LOCATIONS , -,,,, ,'-' , ii Drouahtsman:m i ~,~.~M~ Dwg. no.: NSK 9.O5.207d4 i . . THRU: Lonnie C. Smith ~-- FMOM~ Edgar W. Sipple, Jr Petroleum Inspector MEMORANDUM Sta e of Alaska : AIASF-A OIL A~D GAS CONSERVA~O~ ~IO~-~ lO: C. tom August 9, 1984 ~""~- '~ FILE NO: TELEPHONE NO: SUBJECT: Witness BOPE Test on ARCO's Kuparuk 2G-2 Sec. 31, TllN, R9E, UM. Permit No. 84-121 Doyon Rig 9 Saturn.day, ~t 4, 1984- I traveled this date from AR00's Kuparuk 2D-9, (subject of anothe?-report) to ARO0's Kupa~ 2G-2, Doyon Rig 9 to witness a ~OPE test. The drilling contractor ~ms in the process of The BOPE test ~nced at 12:30 p.m. and w~s concluded at 2:00 p.m. There ~m one failure. ~bm irmide valve on the kill line ~s leaking. ~he A.O.G.C.C. office will be notified ~hen the valve is repaired and tested to 3,000 pounds. I filled out the A.O.G.C.C. BOPE test report mb_ich is attached to this report. In s~, I witnessed tbm HOPE test on ARGO's Kup~ 2C--2, Doyon Rig ~'b. 9. Attachment: Mm. Bill bbrman called and t~he valve has been repaired and tested to 3,000 pounds satisfactorily. 02-001A(Rev. 10!79) ~ .. O&G 5/$4 STATE OF ALASKA ALASKA 0IL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Date ~-(~ ; Well Operator Location: Sec ~1 TI/N R~& U, M Drillin~ Contractor ~ ~J Ri t~ ~ Location, General ~ ~ Well Sign O ~< General Housekeeping ~)~[ Rig O~_ Reserve Pit -.O -,'~ Mud Systems Visual Audio Trip Tank Pit Gauge Flow Monitor Gas Detectors BOPE Stack a~ Preventer Pipe Rams Blind Ra~ms cfo% Valves H.C.R. Valy~ Kill Line Valves Check V~lve ~/~ Test Pressure ~ooo Test Results: Failures Representative Permit q ~f~ Casing Set Representative ACCUMULATOR SYSTEM Full Charge Pressure ~d)OO psig Pressure After Closure /~O psig Pump incr. clos. pres. 200 psig ~ ~ ~min~ sec. Full Charge Pressure Attained: ~ min ~P~-sec. N21~ ,~l~q~ ~--~ ~o~ ~?,~ psig Controls: Master ~,~ o~ ~o Remote ~ Blinds switch cover Kelly and Floor Safety Valves Upper Kelly ~'~ Test Pressure Lower Kelly O ~ Test Pressure Ball Type ~/~< Test Pressure Inside BOP ~ ~Test Pressure Choke Manifold ,~.~ Test Pressure No. Valves I,~ (~. ~1~)(~, _ No. flanges ~ '~ Adjustable Chokes / A~U Hydrauically operated choke / rs. Repair or Replacement of failed equipment to be made within days and Inspector/ Commission office notified. .... Distribution orig. - AO&GCC cc - Operator cc - Supervisor Inspector ~ } //' / July 24, 1984 Mr. Jeffrey B. Kewin Area Drilling Engineer ARCO Alaska, -Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Kuparuk River Unit 2G-2 ARCO Alaska, inc. Permit No. 84-121 Sur. Loc. .487' FSL, 44' FEL, Sec. 31, TllN, RgE, UM. Btmhole Loc. 1423' FSL, !404' FEL, Sec. 31, TllN, RgE, UM. Dear Mr. K~win: Enclosed ~_~ the aPproved application for permit to drill the above referonced well. 'If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.05-0(b)(5)o If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. ~ny rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, ArtiCle 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Co~troi Act, as amended. PriOr to commencing operations you may be contacted bY a representative of the'Department of Environmental Conservation. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention Kuparuk Ri~er Uni~ 2G-2 equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testi~ before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, C. V. Chatterton Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COP~.~ISSION lc Enc lo sure cc: Department of Fish & Game, Habitat Section w/o encI. Department of Environmental Conservation w/o encl. ARCO Alaska, Ira' ' ~"~-~, Post Offic._ .100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 18, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Kuparuk 2G-2 Dear Mr. Chatterton' Enclosed are: An application for Permit to Drill Kuparuk 2G-2, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore o A proximity plat o A diagram and description of the surface hole diverter system o A diagram and description of the BOP equipment Since we estimate spudding this well on July 29, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, Area Drilling Engineer JBK/JG/tw GRU8/L63 Attachments RECEIVED JUL 1 9 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany la. Type of work. STATE OF ALASKA ALASKA _ ,L AND GAS CONSERVATION C~.aMISSION PERMIT TO DRILL DRILL REDRILL DEEPEN 20 AAC 25.005 lb. Type of well EXPLORATORY [] SERVICE [] ST~i~TiG '~'~ RAPHIC J~ DEVELOPMENT OIL [~X DEVELOPMENT GAS [] SINGLE ZONE I~X MULTIPLE ZONE [] 9. Unit or lease name Kuparuk River Unit 10. Well number 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 487' FSL, 44' FEL, Sec.31, T11N, R9E, UM At top of proposed producing interval 1283' FSL, 1200' FEL, Sec. 31, T11N, RgE, UM At total depth 1423' FSL, 1404' FEL, Sec.31, TllN, RgE, UM 2G-2 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. RKB 138', PAD 102' I ADL 25656 ALK 2582 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse 2G-1 well 60' @ surface feet 16. Proposed depth (MD & TVD) 6875' MD, 6376' TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 3500 feet. 21 14. Distance to nearest property or lease line miles 487 feet 17. Number of acres in lease feet 2491 20. Anticipated pressures MAXIMUM HOLE ANGLE 36 o (see 20AAC25.035(c) (2) Proposed Casing, Liner and Cementing Program 18. Approximate spud date 07/29/84 2761 psig@ 80°F Surface 3170 psig@ 6215 ft. TD (TVD) SIZE ~ Hole i Casing 24" I 16" 12-1/4". 9-5/8" 8-1/2" ! 7" 22. Describe proposed CASING AND LINER Weight Grade I Couplingl 62.5# H-40 | WeldI 36.0# J-55 HF1ERW BtCI 26.0# J-55 HF-IERW BTCI program: Length SETTING DEPTH MD TOP TVD 80' 36' I 36' 2663' 35' I 35' I MD BOTTOM TVD 116'11 116' 2698'I 2698' I QUANTITY OF CEMENT (include stage data) ± 200 cf 720 sx Permafrost E & ~ 370 sx Permafrost C 6842' 33' I I 33' 6875'1 6376' 295 sx Class "G" I ARCO Alaska, Inc., proposes to drill a KuParuk River Field development we]] to approximately 6875' MD (6376' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and week]y thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure is 2761 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 2000 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 2G-2 will be 60' away from 2G-1 at the surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus wi]l be left with a non-freezing fluid during any interruptions in the disposal process. The well will be completed by the (see attached sheet) 23. I hereby certify that the foregoing is true and correct to the best of my knowledge The space b~'ow' ~or/orr~miss[on us~'- f v ,/-. / DATE Samples required Mud log required Directional Survey required APl number []YES .,~O i--I YES /~.O .~--Y E S [-INO 50--0 ~- ~?- 7.../t E 3 SEE COVER LETTER FOR OTHER REQUIREMENTS Permit number APPROVED BY Form 10401 I;R~-8/16D31 Approval date ,//O 9,717,41,2,4 I ,COMMISSIONER DATE T,,~.. ')/, 1984 by order of the Commission Submit in triplicate Permit to Dril 1 2G-2 workover rig using 3-1/2", 9.2#/ft, J-55, 8rd tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has been moved off location, this well will be fracture stimulated. RECEIVED JUL 1 91~4 Alaska Oil & Gas Cons. C~mmissior~ .~nchorage .............. >nnn............... _ .... ~ .......... ~t 0~ ===================== .................... . .... ~.,,,,.,~.:~: oO:::,Li ~OO ;~;i 50'0,' ; I I ,r f 'r [ ~= ~.--- -'~"-r-'--~--,~, ~--*.---.....m, ~"'-t-'ff'~- ~ ,,--~ ,--,',t .... ; z ~ J., ; ,~(._..L. J ; ; ' ; ' ' , I ' t , t , t1.1,)1 II"ldill,lllIl I'rl:lilUt,K.~ 1~. ; : i ~ O.l:L .' "~i ' + ~ ' ' , ~ 1. 2. 4. $. Surface Diverter System 16"-2000 psi Tankco starting head. Tankco quick connect assy. 16" X 20" 2000 psi double studded adapter. 20" 2000 psi drilling spool w/lO" si de outlets. 10" ball valves, hydraulically actuated, w/lO" lines to reserve pit. Valves to open automatically upon closure of annular preventer. 20" 2000 psi annular preventer. 20" bell nipple. Maintenance & Ooeration 1. Upon initial installation close annular preventer and verify ~hat ball valves have opened properly. 2. Close annular preventer and blow air through diverter lines every 12 hours. 3. Close annular preventer in the event that gas or fluid flow to surface is detected. If necessary, manually override and close ball valve to upwind diverter line. Do not shut in well under any circumstances. 16" Conductor RECEIVED JUL ! 9 Alaska Oil & Gas Cons. Commission Anchorage I ' ANNIJ[.AR 9 PIPE BLIND ' ~ 3 ~ 2 DIAGRAM ¢1 13-5/8" 5000 PSI RSRRA BOP STACK 1. 16" - 2000 psi Tankco starting head 2. 11" - 3000 psi casing head 3. I1' - 3000 psi x 13-$/8# - 5000 psi spacer spool 4. 13-5/$" - 5000 psi x 13-5/8" - 5000 psi drilling spool 5. 13-5/8" - 5000 psi pipe rams 6. 13-5/8" - 5000 psi drilling spool w/choke and kill lines 7. 13-5/8" - 5000 psi pipe rams 8. 13-5/8" - 5000 psi blind rams 9. 13-5/8" -.5000 psi annular ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC R. UID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON NADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 13-5/8" BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACT- ED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND VAL¥]~S Ll~S~ OF CHOK]~S. DON-~T TBST AGAINST CLOSED CHOKES 4. TEST ALL COMPONENTS .TO 250 PSI AND HOLD 'FOR 10 MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLE FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR I0 S. ~~'PRESSUI~E DOWN$"~RE, AH OF CHOIO~ ISOLATION ~ALV]~S~. TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD.VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN TOP SET OF PIPE RAMS AND CLOSE BOTTOM SET OF PIPE RAMS. 10. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 1D MINUTES BLEED TO ZERO PSI. 11. OPEN BOt'FOM SET OF PIPE RAMS. BACK OFF RUNNING jOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLING POSITION. 13. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCK.% AND INSIDE BOP TO 3ODD PSI WITH KOOMEY PUMP. 15. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. TIONALLY OPEFLATE BOPE DAILY. JUL 1 9 lgB4 Alaska Oil & Gas Cons. Commission Anchorage ( 1 ) Fee (2) Loc ~ tl{ru '8) (3) Admin. (~~' 7--[~'e~ (~_ ,thru 11) (10 and 11) (4) Casg ~ 7-~l~ ~ (12 thru 20) (21 thru 24) (6) aaa...k/f',q Me 5. 6. 7. 8. e 10, ,I 1. 12. 13. 14. 15. 16~ 17. 18. 19. 20. 21. 22. 23. 24. 25. .is'i!~'the pe'~it fee attached'.................'" :~" ..' ' ' ' ~s well to be.located in a defined pool ......... , .................. ~--~ Is iwell located proP&r distance from property line ................. Is-well-located proper distance from other wells ................... Is Sufficient undedicated acreage available in this pool ............ Is well.to be deviated and is well bore plat included ............... Is operator the only affected party ................................. Can pe~it be approved before ten-day, wait .......................... Does operator have a bond in force ................... Is administrative approval needed .............. Is conductor st~ing provided ........................................ Is enough cement'used to circulate on conductor and surface ......... Will cement tie in surface and .intermediate or production strings ... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be'kicked off from an existing weilbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... Is a diverter system required .................................... ~?~,z Are necessary diagrams of diverter ;nd'~OP equipment attached ~fr~-/ Does BOPE have sufficient pressure rating - Test to ~~ psmg .. Does the choke manifold comply w/AMI RP-53 (Feb.78) .................. /t/o T' xu£M I TT~ D Additional requirements ............................................. · 0 Geology: Engi~ering: HWK~ LCS ~____~BEW / HJH JAL ~{~m., rev: 12/08/83 6.CKLT INITIAL GEO. .UNIT oN/OFF POOL CLASS STATUS' AREA NO. SHORE o r , -, p-od ,) , 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. ",!' / .... }~'~ ~ ~,. ~, ~,.,,,% M :N ,~ H C :.; N T .z N T S ., N Z 'T 'F Y ? E 8 A TiE S Z ,i E d f3 3 f: UNIT [;, 0 0 0 O 0 0 3 .'l O a .5 2 Z T 3.kP T 3P N P n ,. 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