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201-106
ORIGINATED ALASKA E -LINE SERVICES 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION 201106 TRANSMITTAL DATE: TRANSMITTAL #: r FIELD BP North Slope 0 0 0 ECA, PBOC, PRB-20 (Office 109) D&C Wells Project Aids 900 E. Benson Blbd. - Anchorage, AK 99508 Conoco Phillips Alaska Inc. -.L. %0 L—I r `I 1 0 0 Attn: NSK-69 MAY 2 4 2019 700 G Street AOGCC Anchorage, Alaska 99501 40GCC 0 1 0 1 1 4TTN: Natural Resources Technician 11 4laska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501-3539 Attn: Garrett Brown -Geologist I DNR, Division of Oil & Gas 550 West 7th Ave. Suite #1100 - AK 99501 0 1 0 re Please return via e-mail a copy to both Alaska E -Line Services and qo' n co Phillips Alaska: 1 1v Date STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION "M.#L1VtU APR 2 2 2019 WELL COMPLETION OR RECOMPLETION REPORT A la.Well Status: Oil❑ Gas❑ SPLUG❑ Other ❑ Abandoned I] - Suspended ❑ 20AAC 25.105 20AAC 25.110 GINJ❑ WINJ❑ WAG[] WDSPL❑ No. of Completions: 1b. Well Class: Development 0 Exploratory ❑ Service El Stratigraphic Test [-1 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: 4/7/2019 14. Permit to Drill Number/ Sundry: 201.106 ' 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded: 6/15/2001 15, API Number: I µCs 50.103.20136-D�8'-00 4a. Location of Well (Governmental Section): Surface: 2538' FNL, 145' FEL, Sec 23, T12N, R8E, UM Top of Productive Interval: 1712' FNL, 1718' FEL, See 26, T12N, RIIE, UM Total Depth: 1860' FNL, 2097' FEL, See 26, T12N, R8E, UM 8. Date TO Reached: 6/17/2001 16. Well Name and Number: KRU 3G -19A 9. Ref Elevations: KB:26 ' GL: BF: 17. Field / Pool(s): Kuparuk River Field/Kuparuk River Oil Pool . 10. Plug Back Depth MD/TVD: AT SURFACE 18. Property Designation: ADL 25648 1 Ab L `LS 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 498235. y- 5988560 Zone- 4 TPI: x- 496664 y- 5984108 Zone- 4 Total Depth: x- 496285 y- 5983959 Zone- 4 11. Total Depth MD/TVD: - 8301/6016 'ALK 19. DNR Approval Number: 2662 S' " 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MD/TVD: 1600/1535 5. Directional or Inclination Survey: Yes ❑ (attached) No Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: NIA 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 NIA 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT FT. TOP BOTTOM TOP BOTTOM PULLED 16 62.5 H40 36 115 36 115 24 216 sx ASI 9.625 36 J-55 35 3879 35 3149 12.25 845 sx ASIII, 545 sx Glass G 7 26 J-55 35 7524 35 5670 8.5 485 sx Glass G, 200 sx Class 4.5 12.6 L-80 7401 8300 5584 6015 6.125 262 sx Class G 24. Open to production or injection? Yes ❑ No ❑� If Yes, list each interval open (MDlfVD of Top and Bottom; Perforation Size and Number; Date Perfd): All PERFS PLUGGED BACK AIow44m DATE ZO f 5 VERIFIED 17384 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 3 112 7412 7401/5584 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. S Was hydraulic fracturing used during completion? Yes No ❑ Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED to Surface 315bbis of 15.8 Class G 27. PRODUCTION TEST Date First Production: N/A Method of Operation (Flowing, gas lift, etc.): PLUGGED Date of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press. Casinq Press: I Calculated 24 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (torr): Form 10407 Revised 5/2017 Vr� s/�/� y CONTINUED ON PAGE 2 Submit ORIGINIAL only ���,�� RBDMSI•IF-APR 2 3 2019s=zg.,y JU 28. CORE DATA Conventional Core(s): Yes ❑ No ❑� Sidewall Cores: Yes ❑ No ❑+ If Yes, list formations and intervals cored (MD1TVD, From7ro), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No Fv] If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1600 1535 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval information, including reports, per 20 AAC 25.071. Formation @ TPI - N/A N/A Formation at total depth: N/ 2/A 31. List of Attachments: Daily Operations Summary, , Schematic, P&A Photos Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontolouical report. production or I test results, per 20 AAC; 25,070, 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: G.L. Alvord Contact Name: Jill Simek Authorized Title: A4ska Drilling Manager Contact Email: Jill.Simek oo . Authorized j Contact Phone: 263-4131 '�_ `F(u Z"� t Signature: -'� Date: 1 INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 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 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate forth for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only KUP PROD WELLNAME 3G -19A WELLBORE 313-19A ConocoPhillips Alaska, Inc. Li�:] Wmim CaUXAS e:ms2AN Cement Squeezes vwaulvJmlmm(euw) ITaplrvOl TaP IXKB) BIm IXXB) (XNBI a'. ('a' ml(B) Oes Sbrt Oah Com CsreM I'JS.S c.m.w w,e, Tuhp:lNSMre McMw vaM; 1e5 a85 ),384.0 48.5 5,5)2.3 PBA Cemem W19I2019 Plug, Tubing Mandrel Inserts at an CONWCTQ2:tlS11S0 H TopjNel Valve T"Me) MB) 2,60 Mate Mc0¢I OO(I1) SM Type rwk PObod"' TRO flan bad) Run BBle Com NIPPLE;1mp 3, 0 2,6050 CAMCO KBUG 1 GAS LIFT GLV LV BK 01 0156 1.296.0 ]1122001 2 4802.8 ],802.8 CAMCO KBUG 1 IGAS LIFT jGLV IRK D 1881 1,333.0 1711W001 5,978.5 461]0 CAMCO KBUG 1 GAS LIFT GLV BK 0250 i,d3].0 ]/122001 GAs LIFT sem° 4 6,748.1 5,139.3 CAMCO KBUG 1 GAS LIFT DMY BK 0000 00 31102019 5 ),356] 5,553.) ICAMCO 1.S LFT I,ReY IF, 0.000 I 0.0 I4/612005 Notes: General & Safety EM p Io IMnOb1bN 1252001 NOTES PUMPED GRAVEL PACK (OIH) su..E.48.sasn.t— 6202001 NOTES WELL SIDETRACKED TO' A' u 1/172011 NOTE'. View Scbematc wl Alaska Sclremated,I) 4/12019 NOTE: Cut 8 removed 121- of well slab. DAL well removed 12'-]" GAs uET:1.em.e 4122019 NOTE: AOGCC INSPECTOR(JEFF JONES) witnessed TOC and Marker plane >4' below original tundra. Gas UFT: ead,a w GRS LIFT: B]1a,1 TUBING LEAK E050 G'Su".].Sa] (d TSOE:].SW0F731w0 aeP:Tomo NIPPLE:],,0Q3 FISX;],W20 SEALASSY;],i106 PACKER:].<NO WE:].13til PIm cEon Prm1sn 18.5 7.0 7,=sob: ],110.0 t s^ND: 7 M0 SCREEN', 805.0 SAND, 0150 MC:9,MSo IPERF', lat ettevo cwuelmRa.bodo SCWEN:BDYIO Zi SCREEN: A. vwD:eo2so eN'.8015.0 SCREE SCREEN. e.G9EARD.a S FRAC IPERE:n80]0 SCREN.REENI B.D3].0 CaeWm.: A.,0 MUG;Emo JAR$', AM0 Re4iav TW:a.Bn.9 PLuc:aomo R.Stan', E.. LRER:].W]]9,9A0 RSN:8.30to� Well Service Daily Summary - No Costs 3G-19 Job: PUMPING TRACKING ONLY Report Date: 3/3/2019 Rig: LRS PUMPING 21 Job: PUMPING TRACKING ONLY Actual Start DateEnd Data Ob AFE / RE/ Mainto 3/3/2019 3/3/2019 Non -We s Expense - 10413517 Rig: LRS PUMPING 21 Rig Accept Date Rlg Release Dale RI9 Supervisor =Mont 313/201913:00 3/3/20191530 SUMRALL. SHELBY,DHD Field Supervisor Daily Operations Report Start Date Report End Dom General Remarks 3/3/2019 13:00 3/3/2019 15:30 CMIT 3G-19 to 1650 psi Starting T/I/0= 525/500/0 Final TNO= 525/500/0 Last 24hr Summary CMIT 3G-19 TO 1650 PSI. PUMPED 1.1 BBLS DSL OWN TBG. Report Contacts Supervisor Tde Company SWETT, SCOTT,Pump Supeiv' Pump Supervisor LRS Time Log Stan Tme End❑me our operation 13:00 13:30 0.50 Start ticket, travel to location 13:30 13:48 0.30 Arrive on location, spot in unit, drag out equipment. 13:48 13:54 0.10 PJSM, Verify barriers, Rig up to SV, PT Lines, FTN, CV test pass 13:54 14:03 0.15 TIME BPM BBLS FLUID TBG IA OA Comments 14:07 .05 Start DSL 525 500 0 Online down TBG 14:12 .05 1.1 DSL 1650 1600 0 Shut down at test 14:27 1620 1570 0 tat 15 min 30/30 loss 14:42 1610 1560 0 2nd 15 min 10/10 loss n 14:45 Bleed down TBG/IA 14:57 Bled back- 1.4 bbis, RD 14:03 15:30 1.45 End tiket. Well Fluids Fluitl To (bbl) From (101) Noo-recov (bbl) Note DIESEL 0.0 Discharges Disch Type 104 Sheen4 Material Note Safety Incidents owe Type Subtype Cam Page 111 Report Printed: 5/2012019 Well Service Daily Summary - No Costs %-0 313-19 Job: ABANDONMENT Report Date: 3/412019 Rig: AES WELL INTEGRITY DHD Job: ABANDONMENT Actual Start Date End Date Objective AFE/ RFE / Maint# 3/4/2019 4/2/2019 Expense Special 10413517 Rig: AES WELL INTEGRITY DHD Rig Accept Date Rig Release Date Rig Supervisor Comment 3/4/2019 06:00 3/4/2019 18:00 SUMRALL, SHELBY,DHD Field Supervisor Daily Operations Report Stan Date Report End Date General Remarks 3/4/2019 06:00 3/4/2019 18:00 Initial TA/0= SI 560/560/0. Final TA/0= SI 0+/0/0 Last 24hr Summary T X IA DDT TO 0 PSI FOR UPCOMING PSA (PASS) Report Contacts supervisor I Tile Campeny AREND,GRANT,DHD Tech DHD Tech AES VANCAMP, PAT,DHD Tech DHD Tech AES Time Log Start Time End Time Dur (hr) Operation 06:00 0700 1.00 Sync computer, travel from KOC to 3G pad. 07:00 07:30 0.50 Rig up hoses and manifolds. 07:30 16:30 9.00 T X IA DDT TO 0 PSI FOR UPCOMING P&A (PASS) Initial TA/0= SI 560/560/0. T FL @ SF. IA FL Q BE Rigged up jumper line from T to IA to simultaneously bleed to 0 psi. Bled T & IA to 0+ psi in 1 hr 50 min (fluid). 2.5 BELS Moved to a bucket drip/open bleed for 1 hr approx 2 gal. (Only the T had pressure coming out. IA was dead). am SI for 1 hr BUR. 15 min TA/0= 0+/010 30 min TA/0= 0+75/0/0 45 min TA/0= 1/0/0 60 min TA/0= 1+/0/0. Bled back to 0+ psi 5 min. < 2 gal. Continued to on open bleed for 2 hours (dripping decreased throughout open bleed). $I for 1 hr BUR. 15 min TA/0= 0+/0/0 30 min TA/0= 0+/0/0 45 min TA/0= 0+/0/0 60 min TA/0= 0+/0/0 Final TNO= 51 0+/010 16:30 1700 0.50 Rig down hoses and manifolds. 17:00 16:00 1.00 Travel from 3G pad to KOC Well Fluids Fluid To (bbl) F.. (bbl) Norrrecov (hbp We Discharges If DisonType Oil Sheen? Matenal Note Safety Incidents Date I Type subtype I Com Page 111 Report Printed: 5/20/2019 Well Service Daily Summary - No Costs 3G-19 Job: ABANDONMENT Report Date: 3/5/2019 Rig: AES WELL INTEGRITY DHD Job: ABANDONMENT Actual Start Date End Date Objective AFE I RFE I Ma lnt# 3/4/2019 4/2/2019 Expense Special 10413517 Rig: AES WELL INTEGRITY DHD Rig Accept Date Rig Release Date Rig Supervisor Comment 3/5/2019 06:00 3/5/2019 10:30 SUMRALL, SHELBY.DHD Field Supervisor Daily Operations - Report Start Date Report End Date General Remarks 3/5/2019 06:00 3/5/2019 10:30 INITIAL TATO = SI 1017010 FINAL TWO = SI 500/500/0 Last 24hr Summary ESTABLISHED T X IA LLR OF 6.8 GPM @ 500 PSI Report Contacts Supervisor Title I Company VANCAMP. PAT.DHO TechDHD Tech AES AREND.GRANT,DHD Tech MOHDTech AES Time Log Stan Time Ertl Time Dur (hr) Dperalbr, 06:00 06:45 0.75 Moming mtg , sync computer , Travel to location 06:45 07:15 0.50 Spot equipment, Rig up 07:15 10:15 3.00 ESTABLISHED T X IA LLR OF 6.8 GPM @ 500 PSI Initial TA/O = SI 10!701) Pressured T X IA to 300 psi with -0.5 bible TA/0 = 300/250/0 Opened IA bleed to adjacent flowline Pressured T X IA to 500/360 with 2.2 bbls Pumped 1.62 bbls for 10 minutes @ TA/0 = 500/360/0 for average of 6.8 GPM SI pump and IA bleed T/110 = SI 500/500/0 Final TATO = SI 500/500/0 10:15 10:30 025 Rig down Well Fluids Fluid I TO(bbl) From (bbl) INrnrecov (bbi) Nab Discharges DiscM1 Type Oil Sheens Material Note Safety Incidents Data Type subtype cam Page 1/1 Report Printed: 5/20/2019 Well Service Daily Summary - No Costs 313-19 Job: ABANDONMENT Report Date: 3/10/2019 Rig: HES SLICK LINE 774 Job: ABANDONMENT Actual Start Date End Date Objective AFE I RFE I MalntA 3/4/2019 4/2/2019 Expense Special 104 17 Rig: NES SLICK LINE 774 Rig Accept Date Rig =Date Rig Suparvlsor 3/10/2019 06:00 3/10/2019 19:30 FAMA, JAKE.Wells Supervisor _ Daily Operations Report Start Date Report End Date General Remarks 3/10/2019 06:00 3/10/2019 19:30 INITIAL= 900/920/0 FINAL= 1000/900/0 Last 24hr Summary IDENTIFY LEAKING OV @ 6748' RKB WITH HOLE FINDER, SET CATCHER ON CIBP @ 7395' RKB. PULLED OV (CHECK AND SEAL FLOWCUT) @ 6748' RKB & SET DV ATTEMPT MITT (FAIL) WITH COMMUNICATION TO IA. LRS ON LOCATION TO ESTABLISH LLR. IN PROGRESS. Report Contacts Supervisor Tee Company WATKINS, KRIS, Slickline Su -. Slickline Supervisor IHES Time Log Steri Tme End Time Dur mo Dperetiao 06:00 08:18 2.30 PU FILE / CPU, GET SPARE UNIT FROM SHOP, WLS FOR TOOLS, ONTO LOCATION, CONTACT DSO, MOVE EQUIP, INSPECT AREA, JSSM. 08:18 10:18 2.00 REPACK, (ALL O-RI NGS CHANGED) RU .125" WIRE AND 1.875" TS= 6', KJ. 5',OJ,KJ, LSS (27' OAL) (((START TICKET @ 10:00))) 10:18 10:36 0.30 RU LRS, PT TO 2500. 10:36 11:00 0.40 RIH W/ 2.5" RB, 3.5" F-STOP HOLEFINDER w/ CENT BTM TO SD @ 182' SLM, POOH. RE-PIN F-STOP. 11:00 1248 ._ 1,80 SAME PT RIH W/ SAME TO SD ON CIBP @ 7360' SLM (7395' RKB), NO TEST, TEST @ 7321' SLM (7357' RKB) & 6725' SLM (6761' RKB), TESTS FAIL, SET @ 6713' SLM (6748' RKB, ABOVE OV), PSI TBG it 900 TO 1800 w/ 0.3 BELS, IA @ 980. GOOD TEST, BLEED BACK AND POOH. CONFER W/ CO REP. 12:48 14:01) 1.20 SAME PT. RIH W/ 3.5" GS (3/16" ALUM), 2.77" x 2.84' AVA CATCHER TO SET ON CIBP @ 7360' SLM (7357' RKB), _ POOH W/ SHEARED GS. 14:00 1530 1.50 SAME PT. RIH Wl 3.5" OK-1, 1.25" JD TO STA #4 @ 6719' SLM (6748' RKB), WORK TOOLS 10 MIN TO LOCATE, SO AND LATCH. HIT OJs 15 MIN AND POOH W/ OV CHECK & NOSE SEVERELY FLOW CUT, HALF OF SEAL MISSING. 15:30 17:00 1.50 SAME PT. RIH W13.5" OK-1, 1" BK-DV TO STA#4, LOCATE, SD AND SET. PSI TBG f/ 1050 TO 2500 w/ 1.3 BBLS. IA @ 890. POOH W/ VLV GONE AND TOOLS GOOD. IA UP TO 1380. PSI TBG BACK UP TO 2500 w/ 0.2 BBLS. TBG DOWN 250 PSI IN 5 MIN, IA UP 200. CONFER W/ CO REP. 17:00 18:00 1.00 (((END TICKET @ 17:00))) RDMO, INSPECT AREA, PJSM, NOTIFY DSO OF WELL STATUS AND DEPARTURE. (LRS REMAINS TO ESTABLISH LLR) 18:00 19:30 1.50 1 SWAP OUT UNITS @ KIC, TRVL TO CAMP, DOWNLOAD, PAERWORK. Well Fluids Fluid T. (WI) From (bbl) NGo-Mcml (bbl) Note DIESEL MENIM Discharges Dlech Typa I Dil Sheem9 I Material Nme Safety Incidents Date Type Subtype Com Page 1/1 Report Printed: 5/20/2019 } <1 Well Service Daily Summary - No Costs 3G-19 Job: ABANDONMENT Report Date: 3112/2019 Rig: HES DIGITAL SLICK LINE 764 Job: ABANDONMENT Actual Start Dale End DateJOE bjective AFE / RFE I Malnt.# - 3/4/2019 4/2/2019 Expense Special 10413517 Rig: HES DIGITAL SLICK LINE 764 Rig Accept Date Rig Release Date Rig Supervisor Comment _ 3/12/2019 06:00 1311 /12/2019 2000 FAMA. JAKE.Wells Supervisor Daily Operations Report Start Date Report End Date General Remarks 3/12/2019 06:00 3/12/2019 20:00 INITIAL= 975/900/0 FINAL= 475/75/0 Last 24hr Summary IDENTIFY TBG LEAK WITH HOLEFINDER BETWEEN 6796'- 7371' RKB. PERFORM LDL: NO FLOW PAST PLUG, IDENTIFY LEAK Q APPROX 6855' RKB, PERFORM UP / DOWN PASSES OVER LEAK AND STATION STOPS Q 6849' & 6859' RKB. PERFORATE WITH 2" x 4' TBG PUNCH (4 spf, 0° PHASE) FROM 7380' TO 7384' RKB. CORRELATE TO TBG DETAIL 6-20-01. PUMP 15 BBLS DOWN TBG @ 2 BPM, 1600 PSI TBG. READY FOR CEMENT PLUG. Report Contacts Supervisor Title I Company WATKINS, KRIS,Slickline Supervisor Slickline Supervisor HES ESSICK. WADE,E-Line Engineer E -Line Engineer HES ZINDA, SHADE -Line Engineer E -Line Engineer HES Time Log Siad Time End Tlme Dur(h4 Operation 0600 07:18 1.30 PU FILE / CPU, ONTO LOCATION, CONTACT DSO, INSPECT AREA, JSSM 07:18 0900 1.70 RU RELAY AND 2" TS= 5',5',OJ,KJ,LSS (24.7' CAL) (((START TICKET Q 9:00))) 09:00 09:30 0.50 RU LRS, PT TO 2500. 09:30 10:54 1.40 RIH W/ 2.5" RB, F-STOP HOLEFINDER TO TEST ON CIBP @ 7356' SLM (7395' RKB), 7317' SLM (7357' RKB), TEST FAIL, SET @ 6757' SLM (6797' RKB), PSI TBG H 400 TO 1400 w/ 0.3 BBLS (BLEEDING IATHRU BLEED HOSE DURING TESTS), GOOD TEST. POOH. CONFER W/ CO REP. 10:54 11:24 0.50 LRS RU JUMPER FROM IA. 11:24 12:36 1.20 ESTABLISH LEAK RATE. PUMP DOWN TBG 1 BPM, 1825 TBG, 2001A. CONFER W/ CO REP. CHANGE 2" TS= 5',5',LFTJ,SRT,KJ,KJ,CENT,PCH,PPU,CORE,IFM,CCL, 2.60" SWAGE (36.2' OAL). 12:36 1324 0.80 SAME PT. RIH TO CATCHER ON CIBP g 7395' RKB, CORRELATE TO TBG DETAIL 6-20-01. 1324 1454 1.50 BOP @ 1/2 BPM, 950 TBG TAKING RETURNS OFF IA. NO FLOW PAST PLUG, LOG UP LOOKING FOR LEAK, IDENTIFY LEAK @ APPROX 6855' RKB, PERFORM UP I DOWN PASSES OVER LEAK AND STATION STOPS @ 6849' & 6859' RKB. CHANGE 2" TS= 5',5',OJ,KJ,LSS (24.7' OAL). 14:54 16:30 1.60 SAME PT RIH W/ 3.5" GR TO SD @T 7356' SLM, TAP DOWN AND POOH W/ EMPTY CATCHER. CHANGE CHANGE 2" TS= 5',5',LFTJ,SRTPCH,PPU,CORE,CCL (26.5' CAL) 16:30 17:42 1.20 RIH W/ CMDFIRE, 2" x 4' TBG PUNCH (4 spf, 0" PHASE), DE -CENT. CORRELATE TO TBG DETAIL 6-20-01. CCL TO TOP SHOT- 9.3', CCL STOP DEPTH- 7370.7', SHOOT TBG PUNCH FROM 7380'- 7384' RKB. POOH. PUMP 5 BBLS Q 1 BPM (950 TBG), PUMP 15 BBLS @ 2 BPM (1600 TBG). 17:42 1900 1.30 (((END TICKET Q 18:00))) RDMO, INSPECT AREA, PJSM, NOTIFY DSO OF WELL STATUS AND DEPARTURE. 19:00 20:00 1 1.00 1 STAGE UNIT Q 1Y PAD, TRVL TO CAMP, DOWNLOAD, PAPERWORK, Well Fluids Fluid To obb From (bbp Noo-recov (bol) Note DIESEL _ -= TBG Discharges Dlsch Type Oil Shee0 Matenal We Safety Incidents Date Type Subtype ICom Page 111 Report Printed: 5/20/2019 Well Service Daily Summary - No Costs 3G-19 Job: ABANDONMENT Report Date: 3/19f2019 Rig: SLB PUMPING MISC Job: ABANDONMENT Actual Start DateEnd Date Objective AFE / RFE I Malnl.# 3/4/2019 4/2/2019 Expense Special 10413517 Rig: SLB PUMPING MISC Rig Accept Date Rlg Release Date Rig Supervisor C 3/191201912:00 3/19/201918:30 KENNEDY. CHRIS,Wells Supervisor Daily Operations Report Sun Date Report End Date General Remarks 3/19/201912:00 3/19/201918:30 INITIAL TA/0=300/900/0 FINAL T/I/0=0/0/0 Leat 24hr Summary PERFORMED FULLBORE CEMENT P&A CIRCULATING 315 BBLS OF 15.8# CLASS "G" CEMENT DOWN TUBING, UP IA @ 4 BPM. NOTE: SCALED CEMENT AT RETURN TANKS NEVER ACHIEVED GREATER THAN 15 ppg. Report Contacts Supervisor Title Company COLE, DALE,Pump Supervisor Pump Supervisor SLB Time Log StartTime End Tare Dur(hr1 Operation 12:00 14:00 2.00 ARRIVE LOCATION. PJSM. RIG UP SLB CEMENTING EQUIPMENT. CONDUCT SIM-OPS WITH CONDUCTOR CREW WORKING NEXT DOOR. 14:00 14:45 0.75 P/T HARDLINE LOW/HIGH TO 4000 PSI. BEGIN BATCHING CEMENT. 14:45 15:15 0.50 ONLINE W/ FW @ 2.0 BPM, 275 PSI. 5 BBLS AWAY, SWAP TO 15.8 CLASS "G' CEMENT. INCREASE RATE TO 3.0 BPM. 15:15 15:30 0.25 90 CMT AWAY, INCREASE RATE TO 4.0 BPM, 270 PSI PMP PRESS, IA=100 PSI, SLIGHT MISTING AT TANKS, SPLIT FLOW BETWEEN 2 TANKS. 15.8# CMT. 15:30 16:00 0.50 260 BBLS AWAY, 4.0 BPM, 1125 PSI PMP PRESS. 15.77# CMT GOING IN. CMT AT TANKS, WAIT TO CLEAN UP, BEGIN CHECKING WGT AT WITH SCALE AT TANKS. 16:00 16:45 0.75 OUT OF CMT; 315 BBLS AWAY, SAW STABLE WGT OF 15# AT TANKS AT SD. 16:45 18:30 1.75 RDMO SLB. Well Fluids Fluid I To(bbl) I F..(bbp Nan-recov(bbl) Note Discharges Dech Type Oil Sheen? Material Note Safety Incidents Date Type Subtype Com Page 111 Report Printed: 5/20/2019 Well Service Daily Summary - No Costs 3G-19 Job: ABANDONMENT Report Date: 3/23/2019 Rig: AES WELL INTEGRITY DHD Job: ABANDONMENT Actual Start DateEnd Date A. / MaInL# 3/4/2019 4!2!2019 Rig: AES WELL INTEGRITY DHD Rig Accept Date Rig Release Date RI9 Supervisor - - - 3/23/2019 12:30 3/2312019 18:00 SUMRALL, SHELBY,DHD Field Supervi Daily Operations Report Start Date Report End Date General Remarks 3/23/2019 12:30 3/23/2019 18:00 Initial T/l/O = SI 2/1/2 Final TA/O = SI vacNac/3 Last 24hr Summary (P&A) DDT-T (IN-PROGRESS) DDT-IA (IN-PROGRESS) DDT-OA (IN-PROGRESS) Report Contacts Supervisor TNe I Company CAUDLE, BRANDON,DHD Tech DHD Tech AES VANCAMP. PAT, DHD Tech DHD Tech AES Time Log Stan Time End Time Dur(hr) owaxn 12:30 13:00 0.50 Travel to 3G pad. 13:00 1315 0.25 MIRU 13:15 17:15 4.00 (P&A) DDT-T (IN-PROGRESS) DDT4A(IN-PROGRESS) DDT-OA (IN-PROGRESS) Initial TA/0 = SI 2/1/2 Bled T,IA, & OA to 0 psi (gas) left of open bleed for 90 min. Shut in for DDT. Starting TA/0 = SI vac/vactvac 15 min TA/0 = SI vadvacJvac 30 min TA/O = SI vadvarJO 45 min TA/O = SI vac/vac(3 60 min TA/O = SI vadvac/3 Final TA/0 = SI vac/vac/3 17:15 1730 0.25 RDMO 17:30 1800 0.50 Travel to camp,sync computers, night meeting. Well Fluids FWin I To (bbl) From (bbl) NorFrecov (bbl) Nob Discharges Disch Type Oil Sheenp Material Note Safety Incidents Date Type Subtype Com Page 1/1 ReportPrinted: 5/20/2019 Well Service Daily Summary - No Costs 313-19 Job: ABANDONMENT Report Date: 3/24/2019 Rig: AES WELL INTEGRITY DHD Job: ABANDONMENT Actual Start Date Eno Date Objective AFE I RFE / Malnt.9 3/4/2019 4/2/2019 Expense Special 110413517 Rig: AES WELL INTEGRITY DHD Rig Accept Date Rlg Release Date Rig Supervisor Comment 3/242019 06:00 3/24/2019 12:00 SUMRALL. SHELBY,DHD Field Supervisor Daily Operations Report Start Date Report End Date General Remarks 3/24/2019 06:00 3/242019 12:00 INITIAL TA/O = Sl VACNACNAC FINAL TWO = SI 0/0/0 Last 24hr Summary (P &A) TWO DDT (PASS) , T TOC @ SF, IA TOC @ SF, REMOVED IA VR PLUG, OA TOC @ SF Report Contacts supervisor Tlee 1 Cam n M Y VANCAMP, PAT,DHD Tech DHD Tech AES CAUDLE, BRANDON,DHD Tech DHD Tech AES Time Log Stan Time EndTime Dur(hr) o"abon 06:00 0645 0.75 Morning mtg , sync computer, Travel to location 06:45 07:00 0.25 Rig up 07:00 11:45 4.75 (P & A) T/I/O DDT (PASS). T TOC @ SF, IA TOC @ SF, REMOVED IA VR PLUG, OA TOC @ SF Initial Ti1/0 = SI vac/vac/vac IA gate valve opens 4 turns only Open bleed all annuli for 1 hour, SI for monitor 15 min TWO = SI 0/vad0+ Stung into IC PO with 7 psi bled to 0 psi (fluid/gas) 30 min TA/O = SI 0/vac/0+ ( IC PO 0 psi) 45 min TA/0 = SI O/vac/O+ 60 min TA/O = SI OIvado+ Open all annuli T TOC @ 10.9' down from tree cap, no fluid Removed IA companion flange and VR plug with cement to surface, reinstalled IA companion flange Removed OA VR plug and verified cement to surface, re installed OA VR plug Final T/1/0 = SI 0/0/0 11:45 12:00 1 0.25 1 Rig down Well Fluids Fluid I T. M" I From(bbl) I Non-recov feel) Note Discharges Disch Typa Oil SheenO Materiel NOte Safety Incidents Data Type Subtype Gom Page 1/1 Report Printed: 5/20/2019 Well Service Daily Summary - No Costs 3G-19 Job: ABANDONMENT Report Date: 3/28/2019 Rig: AES WELL INTEGRITY MISC Job: ABANDONMENT Actual Start Date End DateObJee[ive AFE / RFE / Maim.0 , 3/4/2019 4/2/2019 Expense Special 10413517 Rig: AES WELL INTEGRITY MISC Rig Accept Date I Rig Release Date Rig Supervisor Comment 3/28/201906:00 3/281201920:00 MOUSER, ROGER,WI Field Supervisor Daily Operations Report Start DateReport Entl Date General Remarks 3/28/2019 06:00 3/28Y2019 20:00 NIA Last 24hr Summary (P&A PREP) IN PROGRESS CUT AND REMOVED WELLHEAD AND 31" OF CONDUCTOR. RETURN IN AM TO BEGIN EXCAVATION FOR SHORE PIPE INSTALLATION. Report Contacts Supervisor TWO I campeny VANCAMP. PAT,DHD Tech .. _ .. _. - DHD Tech AES CAUDLE, BRANDON,DHD Tech DHD Tech AES MOUSER, ROGER,WI Field Supervisor WI Field Supervisor CPAI Time Log Sart Time End Tlme Dur(hr) operation 06:00 06:45 0.75 Travel from KOC to 3G-19A. 0645 0845 2.00 Obtain hotwork permit, Hold PJSM with DSO,NES, GBR, D&W Safety. 0845 19:15 10.50 (P&A PREP) IN PROGRESS CUT AND REMOVED WELLHEAD AND 31" OF CONDUCTOR. RETURN IN AM TO BEGIN EXCAVATION FOR SHORE PIPE INSTALLATION. TUBING TOC = 56'. Verified 0 psi on IA/OA and conductor. Marked out 20" below conductor top for GBR welder to begin cutting windows. NES chipped out and removed cement exposing SC. GBR welded weld-c-let and installed 3/4" full opening valve. Drilled pilot hole thru valve bore. Had small amount of fluid and cement come from pilot hole. Using 4 gas meter LELs was 50%. Welded second Weld-c-lel to purge thru on opposite side of SC. Drilled pilot hole and purged SC until 02 dropped below 15% and LEL's at 0 %. Cut windows in SC to access ICAA. NES chipped out and removed cement (solid-good) exposing IC/IA GBR welded weld-c-let and installed 3/4" full opening valve to ICAA. Drilled pilot hole thm valve bore. Checked ICAA with 4 gas meter with LEL's at 20%. Purged with N2 until 02 was less than 13% and LEL's 0%. Cut windows in ICAA to expose tubing. NES removed bad cement exposing the tubing. GBR welded weld-c-let and installed 3/4" full opening valve to T Drilled pilot hole thru valve bore. Checked tubing with gas meter, 02 at 20.9% LELS 0%. GBR proceeded to cut tubing, IC/IA, SC and 31" of conductor. NES removed wellhead and staged over containment for norm testing prior to removal from drilisite. Tubing had a 56' void to TOC (top of Cement). .5 bbl FUV. Used super sucker around conductor area checking for stand/stabilzation. No stand plate within 5' below original conductor top. Safe out the area with barricades and metal plate over open cellar. 19:15 20:00 1 0.75 lTravel 3G-19A to KOC Well Fluids FIdd I To (bbl) I From (bbl) I Noo-rewv (bbti Nate Discharges Disch Type 011 ahe.n9 Materiel Note Safety Incidents Det. Type Subtype Com Page 111 Report Printed: 5/20/2019 t Well Service Daily Summary - No Costs 313-19 Job: ABANDONMENT Report Date: 3/29/2019 Rig: AES WELL INTEGRITY MISC Job: ABANDONMENT Actual Stan Date Entl Data / RFE / MainL# 3/4/2019 41212019 Rig: AES WELL INTEGRITY MISC Rig Accept Date Rig Release Date Rip Supervisor - 3/29/2019 06:00 I 3/2912019 18:00 MOUSER, ROGER.WI Field Supervisor Daily Operations Report Start Date Repon End Date General Remarks 3/29/2019 06:00 3/29/2019 18:00 N/A Last 24hr Summary PBA PREP (IN PROGRESS) ADDED ^19' GALLONS OF PORTLAND 15.8 # CEMENT TO TUBING VOID. TUBING TOC @ —3'. REMOVED CELLAR BOX. BEGAN EXCAVATION USING TRIMMER ATTACHMENT AND EXCAVATOR. ACHIEVED T OF EXCAVATION,TARGET DEPTH 14'. Report Contacts Supervisor I TMe I Company MOUSER, ROGER.WI Field Supervisor WI Field Supervisor ICPAI Time Log Sun Time End Time Dur (hr) Operation 06:00 06:45 0.75 Travel KOC to 3G Pad 06:45 07:45 1.00 Obtain unit work permit, crew PJSM 07:45 16:45 9.00 PBA PREP (IN PROGRESS) ADDED —19' GALLONS OF PORTLAND 15.8 # CEMENT TO TUBING VOID. TUBING TOC @ -3'. REMOVED CELLAR BOX. BEGAN EXCAVATION USING TRIMMER ATTACHMENT AND EXCAVATOR. ACHIEVED 8' OF EXCAVATION,TARGET DEPTH 14'. Encountered corrugated cellar @ V and stand/stabilization plate @7'. Shut downtc discuss plan forward with CPAI safety. 16:45 17:15 0.50 Place barricades around excavation and equipment in front of excavation. 17:15 18:00 0.75 Travel 3G•19Ato KOC Well Fluids Fluid To (bbl) I Fran mb0 Non-recov (bid) Nab Discharges D,.N Type Oil Sheen? Material Nob Safety Incidents Dale Trp. subtype cam Page 111 Report Printed: 512012019 Well Service Daily Summary - No Costs 3G-19 Job: ABANDONMENT Report Date: 3/30/2019 Rig: AES WELL INTEGRITY MISC Job: ABANDONMENT Actual Start Date 3/4/2019 End DateJOE 4/2/2019 blectivs Expense Special AFE / RFE I Main.# 10413517 __ Rig: AES WELL INTEGRITY MISC Rig Accept Date 3/30/2019 06:00 Rig Release Date 3/302019 18:00 Rig Supervlsor MOUSER, ROGER.WI Field Supervisor C Daily Operations Report Start Date 3/30/2019 06:00 Report End Date 3/302019 18:00 General Remarks 1 N/A Last 24hr Summary P&A PREP (IN PROGRESS) CUT AND REMOVED STAND/STABILIZATION PLATE AND GUSSETS FROM THE CONDUCTOR. RESUMED EXCAVATING. PROGRESSING SLOWLY DUE TO CORRUGATED CELLAR. ACHIEVED DEPTH OF 8' -TARGET DEPTH—14'-15'. COVERED EDGES OF EXCAVATION WITH INSULATION BLANKETS TO PRESERVE THE FROZEN SOIL. Report Contacts supervisor rAb Company MOUSER, ROGERWI Field Supervi WI Field Supervisor IGPAI Time Log Stan Time Entl Time Dur(hr) Operation 06:00 06:45 10:00 17:15 06:45 10:00 17:15 18:00 0.75 3.25 7.25 0.75 TRAVEL KOC TO 3G PAD OBTAIN PERMITS, PJSM WITH CREW. OBTAIN PERMISSION FROM CPAI CIVIL STRUCTURAL ENGINEER MIKE CUTLER FOR VARIANCE TO EXCAVATION STANDARDS. P&A PREP (IN PROGRESS) CUT AND REMOVED STAND/STABILIZATION PLATE AND GUSSETS FROM THE CONDUCTOR. RESUMED EXCAVATING. PROGRESSING SLOWLY DUE TO CORRUGATED CELLAR. ACHIEVED DEPTH OF 8' -TARGET DEPTH—14'-15'. COVERED EDGES OF EXCAVATION WITH INSULATION BLANKETS TO PRESERVE THE FROZEN SOIL. TRAVEL 3G-19 TO KOC. Well Fluids Fluid To (bbl) From (bbl) N,ecoa (bull NOW Discharges or Dlsch Type Oil Sheen! Material Nota Safety Incidents Date Type subtype com Page 1/1 Report Printed: 5 /2 012 01 9 Well Service Daily Summary - No Costs 3G-19 Job: ABANDONMENT Report Date: 3/31/2019 Rig: AES WELL INTEGRITY MISC Job: ABANDONMENT Actual Start Date 3/4/2019 End DaleAFE 4/2/2019 Expanse Special / RFE / Malnt# 10413517 Rig: AES WELL INTEGRITY MISC Rig Accept Date 3/31/201906:00 Rig Release Date 3/31/201918:00 Rig Supervisor MOUSER, ROGER.WI Field Supervisor Comment Daily Operations Report Start Date 3/31/201906:00 Report End Date 3/311201918:00 General Remarks N/A Last 24hr Summary P&A PREP (IN PROGRESS) CONTINUED EXCAVATION TO 12'-13'. Report Contacts Supervisor TNN Company MOUSER, ROGER,WI Field Supervisor IWI Field Supervisor JCPAI Time Log Stan T,me End Time cut (hr) Opened. 06:00 06:45 10:00 17:15 06:45 10:00 17:15 18:00 0.75 3.25 7.25 0.75 Travel KOC to 3G pad. Obtain permits, and two 30' wide dg mats from DTH. P&A PREP (IN PROGRESS) CONTINUED EXCAVATION TO 12'-13'.TARGET DEPTH 15' Contacted Drilling tool house for two dg mats (30' wide), to continue excavation. NES continued excavation operations to 12'-13'. Target Depth 15'. Environmental came out to inspect soils removed from excavation. Wendy stated it was good for reuse. Contacted Lounsbury for reference point to Original pad and tundra. Return In AM to finish excavation and set shore pipe. Travel 3G-19A to KOC Well Fluids Fluid To (bbli Fee. nal, Nor reu v (bbtl Nine Discharges Disco Type Note Safety Incidents Date Type Subtype Com Page 111 Report Printed: 5/20/2019 Well Service Daily Summary - No Costs ILL 313-19 Job: ABANDONMENT Report Date: 4/1/2019 Rig: AES WELL INTEGRITY MISC Job: ABANDONMENT Actual Start Date 3/4/2019 End Date 4/2/2019 Objective E / RFE I Malnt# Expense Special 4 13517 Rig: AES WELL INTEGRITY MISC Rig Accept Date Rig Release Date Rig Supervisor 4/1/2019 06:00 4/1/201920:00 MOUSER. ROGER,WI Field Supervisor Daily Operations Report Start Date 411/201906:00 Report End Date 411/201920:00 General Remarks NIA Last 24hf Summary P&A PREP (IN PROGRESS) OBTAINED TARGET DEPTH 14'1 INSTALLED PIPE SHORING. LOUNSBURY MARKED ORIGINAL TUNDRA REFERENCE. GBR/NES CUTAND REMOVED 10'-1"WELL STUB. PREPPED FOR MARKER PLATE. Report Contacts swemieor T#e cenWOY MOUSER, ROGER,WI Field Supervisor WI Field Supervisor IGPAI Time Log SartTime End Time Our (hi Opruri 06:00 06:45 08:00 19:00 0645 0800 19:00 20:00 0.75 1.25 11.00 1.00 Travel KOC to 3G -Pad Obtain permits, PJSM with crews. P&A PREP (IN PROGRESS) OBTAINED TARGET DEPTH 14'+.AND INSTALLED PIPE SHORING. LOUNSBURY MARKED ORIGINAL TUNDRA REFERENCE. GBR/NES CUT AND REMOVED WELL STUB. Travel 3G -19A to KOC update and well files Well Fluids Fluid To (clop From (bell Noo-recov (ebp Nob Discharges Disch Type Oil Sheen? Matenal Note Safety Incidents Dale Type Subtype Com Page 1/1 Report Printed: 5/20/2019 Well Service Daily Summary - No Costs 3G-19 Job: ABANDONMENT Report Date: 4/2/2019 Rig: AES WELL INTEGRITY MISC Job: ABANDONMENT Actual Stan Date 3/4/2019 End Date 4/2/2019 Objective Expense Special AFE I RFE! Mal 10413517 Rig: AES WELL INTEGRITY MISC Rig Accept Date 4/2/2019 06:00 Rg Release Date 4'2/20191800 Rlg Supervisor MOUSER. ROGER.WI Field Supervisor C - Dally Operations Report Start Date 4/212019 06:00 Report End Dab 412/2019 18:00 General Remarks NIA Last 24hr Summary P&A (COMPLETE) AOGCC INSPECTOR JEFF JONES WITNESSED TOP OF CEMENT AND MARKER PLATE. 14' BELOW TUNDRA.. GBR WELDER JOSE WELDED MARKER PLATE. NES BACK FILLED AND PULLED THE SHORE CAN. Report Contacts Supervisor Tft Company MOUSER, ROGER,WI Field Supervisor r WI Field Supervisor ICPAI Time Log Stan Time EnETime Dur(hn Operated 06'00 06:45 11:00 17:00 06:45 11:00 17:00 18:00 0.75 4.25 6.00 1.00 TRAVEL KOC TO 3G PAD. Begin rigging down equipment and mobilizing from 3G to 1C pad. P&A (COMPLETE) AOGCC INSPECTOR JEFF JONES WITNESSED TOP OF CEMENT AND MARKER PLATE. 14- BELOW TUNDRA.. GBR WELDER JOSE WELDED MARKER PLATE. NES BACK FILLED AND PULLED THE SHORE CAN. Travel 3G to KOC update well files. Well Fluids Fluid I T.(bbil F.nd(bbl) Nonrecov(WQ I We Discharges Ditch Type OlShd.n?T Material Note Safety Incidents Date Type Subtype Com Page 111 ReportPrinted: 5/20/2019 P&A WELL EVENTS SUMMARY Date Well Event 4/7/2019 AGOCC INSPECTOR LOU LAUBENSTEIN WAVIED WITNESSING OF FINAL SITE CLEARANCE. 4/2/2019 P&A (COMPLETE) AOGCC INSPECTOR JEFF JONES WITNESSED TOP OF CEMENT AND MARKER PLATE. >4' BELOW TUNDRA.. GBR WELDER JOSE WELDED MARKER PLATE. NES BACK FILLED AND PULLED THE SHORE CAN. 4/1/2019 P&A PREP (IN PROGRESS) OBTAINED TARGET DEPTH 14'+.AND INSTALLED PIPE SHORING. LOUNSBURY MARKED ORIGINAL TUNDRA REFERENCE. GBR/NES CUT AND REMOVED 10'-1"WELL STUB. PREPPED FOR MARKER PLATE. ni prn II 1pf .th of .11 fpmn,,/ l = 17r 7" 3/31/2019 P&A PREP (IN PROGRESS) CONTINUED EXCAVATION T012'-13'.TARGET DEPTH 15' Contacted Drilling tool house for two rig mats (30' wide), to continue excavation. NES continued excavation operations to 12'-13'. Target Depth 15'. Enviromental came out to inspect soils removed from excavation. Wendy stated it was good for re -use. Contacted Lounsbury for reference point to Original pad and tundra. 3/30/2019 P&A PREP (IN PROGRESS) CUT AND REMOVED STAND/STABILIZATION PLATE AND GUSSETS FROM THE CONDUCTOR. RESUMED EXCAVATING. PROGRESSING SLOWLY DUE TO CORRUGATED CELLAR. ACHIEVED DEPTH OF 8' -TARGET DEPTH—14'-15'. COVERED EDGES OF EXCAVATION WITH INSULATION BLANKETS TO PRESERVE THE FRr17FN gnI1 3/29/2019 P&A PREP (IN PROGRESS) ADDED —19' GALLONS OF PORTLAND 15.8 # CEMENT TO TUBING VOID. TUBING TOC @ `T. REMOVED CELLAR BOX. BEGAN EXCAVATION USING TRIMMER ATTACHMENTAND EXCAVATOR. ACHIEVED 8' OF EXCAVATION,TARGET DEPTH 14'. Encountered corrugated cellar @ 6' and stand/stabilization plate @7'. f 4...� I...... ... A:.n......ln.. 1........M ... ..1.'A......1..w. 3/28/2019 (P&A PREP) IN PROGRESS CUT AND REMOVED WELLHEAD AND 31" OF CONDUCTOR. RETURN IN AM TO BEGIN EXCAVATION FOR SHORE PIPE INSTALLATION. TUBING TOC = 56'. Verified 0 psi on IA/OA and conductor. Marked out 20" below conductor top for GBR welder to begin cutting windows. NES chipped out and removed cement exposing SC. GBR welded weld -o -let and installed 3/4" full opening valve. Drilled pilot hole thru valve bore. Had small amount of fluid and cement come from pilot hole. Using 4 gas meter LELs was 50%. Welded second Weld -o -let to purge thru on opposite side of SC. Drilled pilot hole and purged SC until 02 dropped below 15% and LEL's at 0 %. Cut windows in SC to access IC/IA. NES chipped out and removed cement (solid -good) exposing IC/IA GBR welded weld -o -let and installed 3/4" full opening valve to IC/IA. Drilled pilot hole thru valve bore. Checked IC/IA with 4 gas meter with LEL's at 20%. Purged with N2 until 02 was less than 13% and LEL's 0%. Cut windows in IC/IA to expose tubing. NES removed bad cement exposing the tubing. GBR welded weldo-let and installed 3/4" full opening valve to T. Drilled pilot hole thru valve bore. Checked tubing with gas meter, 02 at 20.9% LELS 0%. GBR proceeded to cut tubing, IC/IA, SC and 31" of conductor. NES removed wellhead and staged over containment for norm testing prior to removal from drillsite. Tubing had a 56'void to TOC (top of cement)..5 bbl FUV. ILMrv.nn..... Ln.an..nd--- A ... t...... .6....L:nn 1n..*n_A/..nMn.+dnh+n...aF:n-'k...... n.:nlnnl ..nnA.n�n.♦nn 3/24/2019 (P & A) T/1/0 DDT (PASS) , T TOC @ SF, IA TOC @ SF, REMOVED IA VR PLUG, OA TOC @ SF Initial T/I/O = SI vac/vac/vac IA gate valve opens 4 turns only Open bleed all annuli for 1 hour, SI for monitor 15 min T/I/O = SI 0/vac/O+Stung into IC PO with 7 psi bled to 0 psi (fluid/gas) 30 min T/1/0 = SI 0/vac/0+ ( IC PO 0 psi) 45 min T/I/O = SI O/vac/O+ 60 min T/I/O = SI 0/vac/0+ Open all annuli TTOC @ 10.5" down from tree cap, no fluid Removed IA companion flange and VR plug with cement to surface, reinstalled IA companion flange Removed OA VR plug and verified cement to surface, re installed OA VR plug 3/23/2019 (P&A) DDT -T (IN -PROGRESS) DDT -IA (IN -PROGRESS) DDT -OA (IN -PROGRESS) Initial T/I/O = SI 2/1/2 Bled T,IA, & OA to 0 psi (gas) left of open bleed for 90 min. Shut in for DDT. Starting T/1/0 = SI vac/vac/vac 15 min T/I/O = SL vac/vac/vac 30 min T/I/O = SI vac/vac/0 45 min T/I/O = SI vac/vac/3 60 min T/I/O = SI vac/vac/3 3/19/2019 PERFORMED FULLBORE CEMENT P&A CIRCULATING 315 BBLS OF 15.8# CLASS "G" CEMENT DOWN TUBING, UP IA @ 4 BPM. NOTE: SCALED CEMENT AT RETURN TANKS NEVER ACHIEVED GREATER THAN 15 ooR. 3/12/2019 IDENTIFY TBG LEAK WITH HOLEFINDER BETWEEN 6796'-7371' RKB. PERFORM LDL: NO FLOW PAST PLUG, IDENTIFY LEAK @ APPROX 6855' RKB, PERFORM UP / DOWN PASSES OVER LEAK AND STATION STOPS @ 6849' & 6859' RKB. PERFORATE WITH 2" x 4' TBG PUNCH (4 spf, 0" PHASE) FROM 7380' TO 7384' RKB. CORRELATE TO TBG DETAIL 6-20-01. PUMP 15 BBLS DOWN TBG @ 2 BPM, 1600 RCI TRr: RFAnY FnR rFMFNT RI I Ir. 3/10/2019 IDENTIFY LEAKING OV @ 6748' RKB WITH HOLE FINDER. SET CATCHER ON CIBP @ 7395' RKB. PULLED OV (CHECK AND SEAL FLOWCUT) @ 6748' RKB & SET DV. ATTEMPT MITT (FAIL) WITH COMMUNICATION TO IA. LRS ON LOCATION TO ESTABLISH LLR. IN PROGRESS. 3/5/2019 ESTABLISHED T X IA LLR OF 6.8 GPM @ 500 PSI Initial T/I/O = SI 10/70/0 Pressured T X IA to 300 psi with -0.5 bbls T/I/O = 300/250/0 Opened IA bleed to adjacent Bowline Pressured T X IA to 500/360 with 2.2 bbls Pumped 1.62 bbls for 10 minutes @ T/I/O = 500/360/0 for average of 6.8 GPM SI pump and IA bleed T/I/0 = SI 500/500/0 3/4/2019 TX IA DDTTOO PSI FOR UPCOMING P&A (PASS) Initial T/I/0= SI 560/560/0. T FL @ SF. IA FL @ SF. Rigged up jumper line from T to IA to simultaneously bleed to 0 psi. Bled T & IA to 0+ psi in 1 hr 50 min (Fluid). 2.5 BBLS Moved to a bucket drip/open bleed for 1 hr approx 2 gal. (Only the T had pressure coming out. IA was dead). SI for 1 hr BUR. 15 min T/I/0= 0+/0/0 30 min T/I/0= 0+75/0/0 45 min T/I/0= 1/0/0 60 min T/I/0= 1+/0/0. Bled back to 0+ psi 5min. <2 gal. Continued to on open bleed for 2 hours (dripping decreased throughout open bleed). SI for 1 hr BUR. 15 min T/I/0= 0+/0/0 30 min T/1/0= 0+/0/0 45 min T/I/0= 0+/0/0 fin min T11/0= O+/n/n 3/3/2019 RIH WITH 2.75" CIBP FOR 3.5" TUBING. SET CIBP AT A DEPTH OF 7395'. SW (BOB NOBLE) CMIT-TxIA TO 1500 PSI (PASS) Initial T/I/O = 525/500/0 Pumped 1.1 BELS down tbg. to 1600 psi. Tbg. shows clear communication with IA. Starting T/1/0 = 1650/1600/0 15 min T/I/O = 1620/1570/0 (-30/-30) 30 min T/I/0 = 1610/1560/0 (-10/-10) Bled black 1.4 BBIS SUNDRY NOTICE 10-407 ConocoPhillips Well 3G -19A Plug and Abandonment April 8, 2019 ConocoPhillips Alaska, Inc. performed Plug and Abandonment operations on 3G -19A, commencing operations on March 3, 2019 and completing the Plug and Abandonment on April 7, 2019. A cast iron bridge plug was set at 7,395ft KB and tested to 1,500psi. Tubing was punched at 7,380ft-7,384ft KB and 315 bbls of 15.8 Class "G" cement was pumped to the tubing and IA, from punch depth to surface. The well was then excavated to 4 ft below original ground level, tree and wellhead removed, well capped, and excavation backfilled. Pictures below show cement to surface, marker plate installed, and final site condition after backfill. The field Well Service Report is attached �., r . —may � /�► {� �� {�. �v\t �"'�Q * }�� r� �� ;� �1 �� _ .3'• 11,1 4 9 H 2019. All rights re e r Is provided to .ii c n to copy for its own use. Copying for any other pur Vpart)tixgrohibited without the express consent of Conoc, -! W 14, 1y,_ t / , - .15•. ,Sl} "Copyright 2019. �A1i ngbts reserved, This photograph is provided to the AOGCC with permission to copy for its own use. Copying for amt .1",,purpose or by other party is prohibited without the express consent of Conoco Phillips Alaska, Inc" A kD 0 e -I 0 N v a C, (1 v M L L r Z D` J ` O N Y Y M Q a CL Y o Y o: k W > t U � CCo Z ? G 1 OC Y a Y Q N a J J CL O Z O v Barrels of Oil per Month or Barrels of Water per Month O O O O O O o O O O O O O O p N N N N N N N 0 0 0 0 0 o s 0 0 0 0 oO o ., 0 0 opeki 110-se9 ao gluoiM jad („j:)vy,,) seO;o;aaj :)iqn:) puesnogl N A N 1 Le PT/7 a d/ — /'9 G Loepp, Victoria T (DOA) From: Simek, Jill <Jill.Simek@conocophillips.com> Sent: Tuesday, May 7, 2019 11:29 AM To: Loepp, Victoria T (DOA) Subject: RE: [EXTERNAL]KRU 3G-19A(PTD 201-106); KRU 1C-125(PTD 201-199) 10-407 Abandonments Attachments: Well Events Summary 1C-125.xlsx; Well Events Summary 3G-19A.xlsx Follow Up Flag: Follow up Flag Status: Flagged Victoria, I normally just send in the summaries (see attached). If you want full WSRs I can download and send them this afternoon. Jill From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Tuesday, May 07, 2019 11:23 AM To: Simek, Jill <Jill.Simek@conocophillips.com> Subject: [EXTERNAL]KRU 3G-19A(PTD 201-106); KRU 1C-125(PTD 201-199) 10-407 Abandonments Are there Well Service Reports for these abandonments? 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(a),alaska.00v CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCCI, 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)7931247 or Victoria Loeoo`aalaska.aov MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO:Jim Regg I 31 DATE: Thursday, March 7, 2019 P.I. Supervisor ^/C( qtq SUBJECT: Mechanical Integrity Tests l( CONOCOPHILLIPS ALASKA, INC. 3G -19A FROM: Bob Noble KUPARUK RIV UNIT 3G -19A Petroleum Inspector Sre: Inspector Reviewed By..ry:� P.1. Supry I NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3G -19A API Well Number 50-103-20136-01-00 Inspector Name: Bob Noble IOSp Num: milRCN 190304163113 Permit Number: 201-106-0 Inspection Date: 3/3/2019 Rel Insp Num: Packer Depth Well — 3G -19A Type Inj N TVD Tubing I;TDT 201 1060 Type Test sl't Testpsi IA BBL Pumped: ' BBL Returned: IA OA Interval L___— OTHER—P/F I P Notes: P&A plug test, Sundry #319-008, MIT -T x IA, Plug was set at 73951. 1 Pretest Initial I5 Min 30 Min 45 Min 60 Min 1650 1620 1 1610 1 500 IGoo 1 570 1560 o 0 0 Thursday, March 7, 2019 Page 1 of I ,TATE ASKA -4111E DUNLEAyy lntegrity Engineer ,)Phillips Alaska, Inc. riox 100360 .anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, Permit to Drill Number- 201-106 KRU 3G -19A Sundry Number: 319-008 Dear Ms. Simek: Copse Alaska Oil alid Gas a ion OMMisss on 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.009 cc.Oloska. go v Enclosed is the approved application for the sundry approval relating to the above referenced Please note the conditions of approval set out in the enclosed form. As provided in AS 31 .05.080 well. time as the AOGCC within 20 days after written notice of this decision, or such an application for reconsideration cause shown, a person affected by it may file with the AOGCC received b A request for reconsideration is considered timelyfurther the i rd day falls on a n the 23rd day weekend. g the date of this letter, or the next workingif it is Sincerely, day if Cathy . Foerster Commissioner DATED this day of February, 2019. SCANNED FER 6 7 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 9n AAr 09 Ion 1 ' R 1 1 2019 Z /7//q 075 F1 v 1. Type of Request: Abandon 4 ' Plug Perforations ❑' Fracture Stimulate ❑ Repair Well ❑ Operations shutdown Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhflll sAlaska Inc. Exploratory ❑ Development ] • Stratigraphic ❑ Service ❑ 201-106 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20136-01-6c) 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A I ' n /r` Will Planned perforations require a spacing exception? Yes ❑ No 21KRU 313-19A 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25548, ALK 2662 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): 8,301' 6,016' - 8203 5976 1750psi 8073, 8078 7402, 8300 Casing Length Size MD TVD Burst Collapse Conductor 79' 16" 715' 115' Surface 3,844' 95/8 3,879' 3,149 Production 7,489' 7" 7,524' 5,670' Liner 899' 41/2 8,300' 16,015' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8015-8025,8060-8070 15898-5902,6917-5921 3.500" L4 7,412' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): PACKER - RETRIEVABLE GRAVE PACK PACKER MD= 7424 TVD= 5600 PACKER - BAK R ZXP CKE MD= 7401 D= 55 12. Attachments: Proposal Summary 0 Wellbore schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development I] , Service ❑ 14. Estimated Date for 1120/2019 15. Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned - 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Jill Simek Jill Simek Contact Name: Authorized Tide: Staff Well Integrity Engineer Contact Email: JiILSimek@cep.com Authorized Signature:Contact Phone: (907) 2634131 11tolil Date: COMMISSION USE ONLY Conditions of approval: Notiommission so that a representative may witness Sundry Number: �)J G0 0 Plug Integrity L7 BOP Test ❑ Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes ❑ No I—/ � Spacing Exception Required? Yes ❑ No 15 Subsequent Form Required: 10-407— APPROVED BYApproved by: COMMISSIONER THE COMMISSION Date: car. UKIUINA,! RBDMS►"'FEB0i2019 Submit Form and Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. /✓-��p Attachments in Duplicate ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 8 January 2019 Commissioner, State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7s' Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to Plug and Abandon Kuparak Producer 3G -19A (PTD#: 201-106). 3G -19A was drilled (sidetrack) and completed in 2001 as a tracked A sand producer. Two weeks after the frac, rocks were found in the choke and tubing, and the well was cycling lift gas. A 2005 through -tubing gravel pack installation was unsuccessful in restoring production and the well was shut-in. In 2016, CTD laterals from neighboring 3G-04 successfully targeted the resources from 3G -19A. Kuparuk rotary deve opment is targe mg a western peep ery o e gel in the 3G area wi t e well pair, injector 3G-27 and producer 3G-28 scheduled for Q2 2019. The P&A of 3G -19A will provide a drilling slot for 3G- 28 with the required surface production facilities. The well has 9-5/8" surface casing to 3,879ft KB and 7" production casing to 7,524ft KB. There is 3-1/2" tubing with a packer at 7,401ft KB. A 4-1/2" liner is set from 7,401ft to 8,300ft KB. Two sets of Kuparuk perforations are at 8,015.0-8,025.Oft KB and 8,060.0-8,070.Oft KB. A coil tubing fish, left behind during the gravel pack installation, is at approximately 7,402ft KB. Fishing operations have been unsuccessful, and ConocoPhillips is therefore requesting a variance from the AOGCC well plugging requirements as specified in 20 AAC 25.112 (c)(1)(C): "by the displacement method, a cement plug placed from the well's plugged -back total depth to 100 feet above the top of the perforated interval, if all hydrocarbon -bearing, abnormally geo-pressured, and freshwater strata below are isolated,- however, the commission will approve plugging from the top offill or the top ofjunk instead offrom the plugged -back total depth, if the commission determines that the objectives of this subsection will be met; " To achieve isolation objectives, tubing will be perforated above the fish, and a cement plug placed in the tubing and tubing x production casing annulus (IA), from approximately 7,380ft KB to surface. The well will then be excavated 4 feet below original ground level, wellhead and cellar removed, and site backfilled with gravel/fill to ground level. Please refer to the attached procedure for more details. If you have any questions or require any further information, please contact me at 263-4131. Sincerely, UJ ll Sime J 11I Integrity Engineer CPAI Drilling and Wells ConocoPhillips 313-19A P&A Permit to Drill #: 201-106 P&A operations will be performed by placing a cast iron bridge plug above the coil tubing fish, then placing a cement plug in the tubing and tubing x production casing annulus (IA), from the bridge plug to surface. The well will then be excavated 4 feet below original ground level, wellhead and cellar removed, and site backfilled with gravel/fill to ground level. Well Status: The well is currently shut in (LTSI). Coiled tubing tool FISH is at 7,402ft KB. Production casing x surface casing annulus (OA) is cemented from—1,600ft KB to surface. Last known fluid: • 3-1/2" Tubing = diesel • 3-1/2" x 7" = diesel/ unknown Last SBHP = 2,299 psi @ 5,585ft TVD (7,402ft MD); obtained 7/25/2014 Latest Drift/tag = Unsuccessful coiled tubing fishing attempt 12/18/2018 to 12/23/2018 Min ID (above fish) = 2.75' Camco D Nipple No -Go @ 7,402.3ft KB Max deviation (above fish) = 47 degrees at 7,394ft KB Procedure: E -line Objective: Set Cast Iron Bridge Plug (CIBP) above FISH. 1. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 2. RU a -line and PT Equipment as required. 3. RIH with CIBP; reference 10/22/2012 schematic and tubing details for depth correlation. 4. Set CIBP above FISH at—7,395ft KB. 5. RDMO. J DHD: Objective: Test plug. 1. Notify the AOGCC Inspector of timing for pressure test witness (submit AOGCC Test Witness Notification Form 24hrs in advance of witness). 2. RU DHD and PT equipment. 3. Perform MIT -T and MIT -IA to 1,500 psi. Record Results. AOGCC witness required. 4. If MIT -T or MIT -IA fails, perform CMIT-TxIA to 1500psi. Record Results. AOGCC witness required. 5. Perform drawdown test on tubing and IA. _ ZV fy 'f-o6rC ��_� -1_e� o� f7rotfco/�h� E -line /Little Red T� Objective: Punch 3'/z" tubing to establish circulation for cement plug. 1. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 2. RU a -line and PT Equipment as required. 3. RIH with 2" x 4' tubing punch, 4 spf; reference 10/22/2012 schematic and tubing details for depth correlation. 4. Punch at 7,380ft KB. 5. Rig up LRS and pump 20 bbis diesel through tubing holes to ensure adequate rate for cementing (+/- 2 bpm <= 2,OOOpsi). 6. If 2 bpm circ. rate is not achievable, RIH with a second tubing punch and punch holes 32' above the previous holes. 7. RDMO. Cementing: Objective: Plug #1 - Place a cement plug in the tubing and IA from CIBP (7,395 ft KB) to surface. We will be circulating cement down the 3'/z" tubing and up the 7" x 3'/2" annulus. Cement Volume Calculations: 3'/ " tubing from CIBP to surface: (0.008696 bbl/ft) * (7,395ft — Oft) = 64.3 bbis 3'/" x 7" annulus from tubing punch to surface: (0.02636 bbl/ft) * (7,380ft— Oft) = 194.5 bbis • Total = 64.3 + 194.5 + 41.2 = 300 bbis 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. (Charles Hacker / Stephen Higgins 907 659-6121). The job is designed for 300 bbis of 15.8# Class "G" cement. 3. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. JS no 4. RU Cement Equipment and PT surface lines as required. Ensure to rig up a cement clean up line using an isolation valve and 'T" connection off the tree. 5. Ensure that hardline is rigged up to pump down the tubing and take returns to a tank from the 3 Y2" x 7" (IA) annulus. Also ensure that there is a way to pump down the IA in case the tubing pressures up. 6. Pump 5 bbls fresh water spacer 7. Pump 300 bbls of Class "G" cement (cement to surface in tubing and IA, including 41 bbls excess). 8. After good IA cement is seen at surface, shut down pumps and close in IA valve. 9. Close in the master valve, open the cement clean up line, and circulate to tanks to wash up tree and surface equipment. 10. RDMO Objective: DDT 1. WOC for 48 hr or until field blend UCA chart shows cement developed 1,500 psi compressive strength. 2. RU DHD and PT equipment. 3. Perform drawdown test on tubing, IA, and OA. Wellhead Excavation / Final P&A: 1. Determine top of cement in tubing and annuli; perform cement top up job. 2. Notify the AOGCC Inspector of timing for surface plug witness and marker plate installation (submit AOGCC Test Witness Notification Form 24hrs in advance of witness). 3. Remove the well house, if still installed. 4. Bleed off TWO to ensure all pressure is bled off the system. 5. Remove the production tree, in preparation for the excavation and casing cut. 6. If shallow thaw conditions are found, have shoring box installed during the excavation activity to prevent lose ground from falling into the excavation. 7. Cut off the wellhead and all casing strings at 4 feet below original ground level. 8. Perform Top Job and verify that cement is at surface in all strings. AOGCC witness and photo document required. 9. Send the casing head w/ stub to materials shop. Photo document. 10. Weld Yd' thick cover plate (16" O.D.) over all casing strings with the following information bead welded into the top. Photo document. AOGCC Witness required. ConocoPhillips 3G -19A PTD M 201-106 API M 50-103-20136-01 JS 11. Remove Cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole tc ground level. 12. Obtain site clearance approval from AOGCC. RDMO. 13. 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. is Schematic: ConocoPhillips is KUP 3G -19A Wetl nwsul.a MaaM rarD TII a wlLsroiwF� xwA4uxFlv[quwi �W �]]ny Me.rlmb0.1 nmw r Wr.r �]s a,lsism •I )aJ ]b101 ti19:%B qn gea�OPx. aA]CS i),ypC�} r+W CMLNC]JP !YM ',SLV+ IWII fmi- 9vOFt. ! Me fi5f 6: Sf WCLGCO CWW $UgI.V`l avrylo. apW_ W IM1'P .. NI- aM aM iW iM 95e1 p9}] ]SO v]6]91i ]lag^ EM J55 YJII [PVK Piulwm� wi'1 pWiO - 6]]6 .. anw W]SO >,yr4 SY6.9 }6W JpS OIPI Ae %] LNrq - !vV - )95e 61a2 vp.. ieue iw iam] gismo po-ss +: eo .e4 Nsc] LblW OeMb WOWm �:'ai IWP9.WaP. omi 'i19sPK+[a ^l,lW] a.x') pAxCF AV PKkP VG: LIL[ 14]p ].a'.a] YLS �uwi(F xCq!_V.CC\W.ryGCF aaoe ],595' ]a pAx(F IOJL SCAT C1 CeGY2J l0]p Tia M":99+ avry o_ vMTq. aM tvV-aM iYAw iW $B.] 116 SY96 9x LbJ [U[eG4MW T91 eaa_ MMp aRl i fl Yn0.vMs a e.SR. NIPR JN�PRC ANO ]. ♦ Y0.+ a WK MlltyYlO v. xlvanvl pll f1Ywl En ]br MleraOY �a19es fu Ha TW aP4 i fl v CIW 1. 0 . Mfabe Wles gvJK4nv Vav CRL5 rCT a %n&. Y IP.]CI([P iYAB\C4MV'V FP .F lm- f f4f .rMa Se]15 Y[ a µ BMC EF lm. 5 ].Y .22 ^ICM .J�fLIV Jgli /-Oa5 I Se] .a Y IOIAL V4 PYM P• i • 1 1 PTIMA ]r11N Kqf TIMN[IS] -Kffnp. 5L [N -WH i i £GPECNP!! 1} 1mRe05 1 vl L}yiZ CaW FPp IULIh Pah 1(}MMf 5. R CMMU}C V}l. iYf ]a 1} -nM N MTM.CK ENwliyM 1.-[905 1 1 mla S EN [N ! V/N }e %A% a 601C. epV SAbNGCCM l.a 0.900 S.YI IJTN VCLTM COQ] •Of tb clta]upw RNTVJKt51 Owe .91 e. T u 1. ym o ux 0900 s9}xs ApJws W. -Mg gime s. v ap Tm u- r aNMaw- o a s.mu mn ttw n [vpeaE nq am a s.yp] mxga®aa gCIE/SC srEW Lm ea Mu iP4�5t W m W rmw eaa YW s aL 9�a 6L}50 Sp9]p 19]}.142 6a iE f ] e M1nu T hm Aai vpn i�T91 _ Mal •m aa�SE eC}5o S.BS]p 194}'. lFK 'A'SAVa lql{ ps iw IM1JI Mal vl ip 1{q MM imL }. 1 a� '✓.4CJ KYW 1 (i4c .ln O_v n m^0 ]rlydLt ]1Y a9] ..]n vl 1 a]_I LW.O 1:BJG1 0R O.Y oic 92 o. m ] � c11 wr P&A Diagram: is 3G -19A P&A PTD #: 201-106 16'&2.51n4 CWdnlotg 115'4® anW TR NWOE No GO a 496' KB GLM: GLV g 36062 KB 9 Sir :G43M stutz ECalrgg 3.B77 KS GLV 5,607 rB g CLV.5,579'rB OV 4e 6, 357 XB DIN e3 7.BST K !M ZXPP3CW47AOf1B FISH g 7,402' 99 :arta S NpplE NOGog 7ACZ KB Gi&225Ea1 AWV" rt WW Lota1x S 7A11' KB 8.}:• 93? L40 TID1y g 7.412 K9 trop Seal We EftTg 7424' KB 5V }55 Plod W Cab g g' 7,524Kb - 3ft E,C 130-8,025.G KB e.W.0-B,CMV K8 4;a' 12.641-80 _IEr g 8,303 K8 AI �t W aE 15.55 CIM 'a' CemET. Pty n Ste KUP PROD WELLNAME 3G -19A WELLBORE 3G -19A COtIOeoPFUllipsAMIP1.11A. ell Attributes Max Angle & MD TD ltNameWe11Mre APYUWIWNIWreStats nci )MO Ir+K31 Aelder'no•B)A arilfa, elCELK RIVER UNIT 501(132013fi0I PROD Ir, 471 JJJ]9J A'Ll 0 w-taA v+prsMstzsaw PM Last Tag ve1[tl er'.Mnlclapun0 Amounted- plead Ins! Ogle '11, WtbW ey Last Tag: ).3640 1/192006 3G -19A ._....__............. _iiwc[u;aa... 1 Convvee rsion Last Rev Reason AnmYtian 1 EM qb wandere 1 Laal"i Rev Reason: DRILL DATES 10222012 3G -19A 1.071 Casing Strings Casing Description oD (in) IDpn) Top MET Stl OepthotIOD Ser Oepm Under WULen p_.Gm4e Tnp To. CONDUCTOR 16 1506 360 115.0 115.0 62.58 H40 WELDED CONDUCTOR: 3661150 CUIrp Description OD (in) IDpn) Top(IMB) Ser Oepm madd Sel Oepn(ND)... WIILen p... Gr a 4e Top TlrrW mppLF:ae6o SURFACE 95/8 892 35.0 3,879.1 3,1492 36.00 J55 BUTT Casing Deaonptlon OD(in) Ing TopplMig SH..,ohna., SH page Pood... WBLerr p...GrMe Tpp TRrMO Production Pasi SIT J 6.28 15 35.0 7,524.0 5.6702 2600 J-55 BUTT AB - GAS UFT; 3,ar[.a di UNERCescrlptM LINER OD OnI Nlinl 412 3.96 Tap OEKEB 7,4007 BN Cartel MOT BN DepM OVDI....n 8,300.0 6,015.5 In -jun.. Top Tllmn 1260 L-80 NSCT Liner Details xorgani Top 1Top(M Tap lne'r, Des Com got 7 40 7,400) 5,583.) 46.68 PACKER J rintd' BAKER ESP PACKER w/C2 PROFILE 4.406 7,414.5 5,593.2 46.54 Hghol BAKER FLEX LOCK HANGER 4406 -URFACE: M0-307al 7424,7 5,600.2 I 4629 SBE BAKER B11i0 SEAL BORE EXTENSION 4000 Tubing Strings Tubing Description I soin8 Ma.. 101inl Top(t+KDI set Depth(it SN Depth UnIISI... 011 IIdN Grade Tap Connecen WBUFT;4�8 TUBING 3112 2.99 26.3 7,411.6 5,591.2 9.30 L-80 EUEBRDMOD j Completion Details mp/TVD) Top 1-1 Nominal Top p✓BI IXxe) (1 Ixm Dee Com ID (in) 253 26.3 006 HANGER WKM TUBING HANGER 3.500 Gas upra,was 498.0 4980 066 NIPPLE 1 CAMCO DS NIPPLE w/N GO PROFILE 2.812 7,402.3 5,584.8 1 46.84 NIPPLE CAMCO D NIPPLE .1 NO GO PROFILE 27750 7,410.6 5,590.5 4664 SEAL ASSY BAKER H S LY .1 NO Local active 3.0270 GAs uFr; me6.1 1 seal a55embry length 18', slabbed into liner lop SBE @ 7424' Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top ill Top Top W'd pithe I -On$ Com Run Ogre IDpn) OAS UFT: 7.656.7 7,4020 5,5846 46Fish Coiled TBG Tool lost during Gravel Pack 1/3012005 7.424.0 5,599.7 46R RETRIEVABLE GRAVE PACK PACKER 1WZKKrS 1.610 7,4280 56025465EAL BORE EXTEN5ION 11272005 1.9507,440.0 OPACKER 5,6108 45HEAR OUT SAFETY JOINT 1272005 1500 ],4700 5,631.8 45A L U E_ # F 1 1 BO 1262005 NIPPLE:➢4@a PROP (143#M IN PERF TUNNELS) 8,009.0 5.8951 64EN TRATACOIL SCREEN PMF IWO 127/2005 1.500SEA ASSY: 7.4108 8,015.0 5,897.7 64Gravel Pumped; 3520x12718 Cato Prop 14M In Peris 1/26/2005 8,020.0 5,899.8 64.8 Centralizer BOW SPRING CENTRALIZER 1/2712505 1481 8,0230 5,901.1 .82 SCREEN STRATACOIL SCREEN PMF I WO 112712005 1.500 8,025.0 5,9019 6485 SAND Gravel Pumped= 3520# 12/18 CARBO PROP 1262005 PACKER. 1424.0 8,034.0 5,905.8 64.97 SCREEN STRATACOIL SCREEN PMF TWO 1272005 ISM SBE: 74M.0- 8,0450 5,910.4 65.12 Centralizer BOW SPRING CENTRALIZER 1272005 1.478 B4O4&O 5,911.7 65.16 SCREEN STRATACOIL SCREEN PMF IWO 727/2005 1500 8,060.0 5,916.7 65.32 SAND TOTAL GRAVELPUMPED= 3520 IT OF1 ARBO 12&2005 PROP T43#IX IN PERF TUNNELS) PabxtialPutBR,EO 75240 SCSI 5,9167 65.32 SCREEN STRATACOIL SCREEN PMF TWO 112712005 1.500 7,4400 7 85#27', 7,4]00 8,0710 5,921.3 65.45 Centralizer BOW SPRING CENTRALIZER 1/272005 1467 8,073.0 5,922.1 65.45 PLUG COMBINATION BULL PLUG 1127/2005 8,074.0 5,922.5 65.46 JARS SPANG JARS 112712005 8,077.0 5,923.8 65.46 Retrieve Tool 15' RETRIEVING TOOL arm Wi SR 12)2005 8,0780 5,924.2 65.47 PLUG RETRIEVABLE BRIDGE PLUG 1272005 B4ONTO 5,928.7 65.50 Release Food PSP vol 8 On' RELEASE STEM 1272005 scREEN', e.oreo 8.300.0 6,015.5 65.83 FISH Fish lost IF Braided Line Brush, No FIN 62912001 aAND,,0,0150 FPAC. sons 0P & Slots /PERF', B,MSDa,W60 CenbYxen 60A a shot D ne -GREEN; 6.�0 Togas Bi"x) IshoM1lfl BCREEN', 6CG40 Tap IXKB) Bim IM61 (XKB) IXKeI LInFM 2wn Oale ) Type Core xwD: 60260 cennasm: , 5,897.7 5,901.9 8,0150 :0 A -2,3G -19A 6I28I2o01 6.0 (PERF 25"HSU, DP&BH Cogs severe acREEN: e.ae0 IPeaF: eFAi 8,060.0 8,070.0 5,9167 5,9 .0 A-, G -19A J1272o01 6.0 (PERF 2.5"HC Gtgs,fiO deg Oh Frac Summary 1.,010.0 FRAC: e.ow.0 s6N0: e.Dw.O 6Del ppsnl CesignM ltq PmProppanil Formtllon pe) scREEN: 6.090.0 613O 02001 CerOYuar', 9.0]+0 as. 1 Siert Detr Tap DepthMB) BNIIIXKB) 613012001 8,015.0 &0250 Ling fo Fluor By.. VOICWnIbbg eid Slurrylbbll PLUG:a,O]3.0 Skirt Dal Prepeani CaurgnMllal Prapporam FormNOn IIN Adder e.m4o 61302001 Reeyw TM;6,R/7.p ft. union. Top Depth MIKE) Brand OAKS) Unk.Ftugmemen eeclenlbap VOlawry mbq PLDG: e.oTao 1 71212001 $0600 8,070.0 Mandrel Inserts R.B..amn;acee.0 st au To P TWO) Vane Ended Porl TW Red H Top We) Inns) rAaRe Mosel Dopar Bele Type type (in) 1w# gain Date Com 1 3.0624 2,6050 CAMCO KBUG 1 GAS LIFT GLV BK ]/12/2001 3,8028CAMCO KBUG 1 GAS LIFT GLV 6K 1,333.0 )/12/2001 978.5 46130 CAMCO KBUG A12960 1 GAS LIFT GLV BK 14320 JI122014 61481 5139) GAMCO KBUG 1 GAS LIFT ON BK 00711220015 13551 5,553) U -MCO MMG 1 GAS LIFT DMV RK Do 41612005 LINER:]" ...and. FI -X: BN]0+ KUP PROD WELLNAME 3G -19A WELLBORE 3G -19A ConocoPhillips Neska.lnc. & F-- I E: a�H, 111.1e 1z ERS, IE Notes: General & Safety WNUIxMmxec acW.p EndOah Annotation 1I2L2001 NOTE. PUMPED GRAVEL PACK (GH) nPNGER. ie.] &20I2001 NOiE'. WELL IDETRACKED TO'P' Ju 11172011 NOTE :VIM bLhRnHHiC wl Alazka fthoniatic9.0 COXWCTOR: Y61150 NPP E',-0 GPS LIFT: ]OSiA WRFPCE: 530.9.R19.1� GASIIFi;<,m'28 OPSLIFi: a.9Ta1 GPSU07,,A.1 GASUFi;T,38T XIVVLE: I.W2a FISH. 7.W20 SEAL A%Y, 74106 P AEN; 7.a0 SEE: TAlB.O Vro]IaEalFla Bn: ]524S OS T,N00 swo:>.arao SCREEX;SWi.O sum. e.msn FasC: So15o IPEXF: bots 60,oE.a SO$T.0 It SCREEN. E,Ozeo FLFFEN F. F.. Ce -1 -,,.,"EI cREFN bws.o 'PERE, B,WJ.p ..I FRAC; 9... SW0:4aco.o SCREEN: R.0 ammm; 8.0]10 JARS, e.ma0 Rn,—Tm; RIM RUG, &010.0 R.Su .0.0SE0 LINER; 7tla 7d,=0 FISH: S]ooa � P&A Diagram: is 3G -19A P&A PTD M 201-106 tE fi2.5C He0 ^SnSlcicr (p ;BMW 0.; NkoPeW Go,g 498 Ke GLM: GLV 0 3762' KEI 9 S36?J-55 SuT"sztngg AB:P KH WW GL'd ig 4,EG3 K.9 6L'd,g 3.5-3 KH GMf,g 7,3e, K5 Hakzru P wcRr•}J 7.40r KE5 FISH C, 7.407 KS :anm'C' Mppe NP Ga -g ?AWPM -t GH&2Z Se31ABOe yA'N]'3u 023,xg�,dti'KH }y -63x LAGT ng gP'413'K9 rti�i28i Ek+t El�'�m g`,dZ1' K& 5#J s5 PRicu wrg a?.52'K9 �•��� arts ,m-$CP.S.0KH _ P �Wn7.0-6,L4M.p KH 4!r e26Y4ED Lner.g MW K5 L NI car t0[e 15.60 Cly 'T cem Pkg to Sulxe G jo-P 3� �l .7S 1249.15 ConocoPhillips 3G -19A P&A Permit to Drill #: 201-106 P&A operations will be performed by placing a cement plug in the tubing and tubing x production casing annulus (IA), from the Top of Fish to surface. The well will then be excavated 4 feet below original ground level, wellheadan cellar removed, and site backfilled with gravel/fill to ground level. Well Status: i The well is currently shut in (LTSI). Coiled tubing tool F!SH is at 7,402ft KB. Production casing x surface casing annulus (OA) is cemented fro�i �1,600ft KB to surface. Last known fluid: • 3-1/2" Tubing = diesel • 3-1/2" x 7" = diesel/ unknown Last SBHP = 2,299 psi @ 5,585ft TVD (7,402ft MD); obtain�d 7/25/2014 Latest Drift/tag = Unsuccessful coiled tubir 5t 12/18/2018 to 12/23/2 Min ID (above fish) = 2.75" Camco D Nipple No -Go ,402.3ft KB Max deviation (above fish) = 47 degrees at 7,394ft� Procedure: E -line / Little Red Objective: Punch 3'/s" tubing to establish circulation for cement plug. 1. Conduct Safety eeting and Identify Hazards. Inspect wellhead and pad condition to identify any re -existing conditions. 2. RU a -line an PT Equipment as required. 3. RIH with 2" 4' tubing punch, 4 spf; reference 10/22/2012 schematic and tubing details for epth correlation. 4. Punch at 380ft KB. 5. Rig up S and pump 20 bbls diesel through tubing holes to ensure adequate rate for ce enting (+/- 2 bpm <= 2,OOOpsi). 6. If 2 bpm circ. rate is not achievable, RIH with a second tubing punch and punch holes 32' above the previous holes. 7. RDMO. JS Cementing: DHD: JS Objective: Plug #1 - Place a cement plug in the tubing and IA from top of fish (7,402 ft KB) to surface. We will be circulating cement dow the 3 %" tubing and up the 7" x 3 %" annulus. Cement Volume Calculations: • 3'/ " tubing from FISH to surface: (0.008696 bbl * (7,402ft — Oft) = 64.4 bbls • 3'/Z' x 7" annulus from tubing punch to surface: 0.02636 bbl/ft) * (7,380ft — Oft) = 194.5 bbls • Total = 64.4 + 194.5 + 41.1 = 300 bbls 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. (Charles Hacker / Stephen Higgins 907 659-6121). The job is designedfor 30 s of 15.8# Class "G" cement. 3. Conduct Safety Meeting and Identify Haz ds. bblInspect wellhead and pad condition to identify any pre-existing conditions. 4. RU Cement Equipment and PT surface ines as required. Ensure to rig up a cement clean up line using an isolatio valve and "T" connection off the tree. 5. Ensure that hardline is rigged up to mp down the tubing and take returns to a tank from the 3 %" x 7" (IA) annulus Also ensure that there is a way to pump down the IA in case the tubing pressures up. 6. Pump 5 bbls fresh water spacer 7. Pump 300 bbls of Class "G" ce nt (cement to surface in tubing and IA, including 41 bbls excess). 8. After good IA cement is seen su ce, shut down pumps and close in IA valve. 9. Close in the master valve, op a cement clean up line, and circulate to tanks to wash up tree and surface eq ip ent. 10. RDMO t Objective: DDT 1. WOC for 48 hr or compressive strei 2. RU DHD and PT 3. Perform drawdow field blend UCA chart shows cement developed 1,500 psi test on tubing, IA, and OA. 1. Determine too of cement in tubing and annuli; perform cement top up job. 2. Notify the A GCC Inspector of timing for surface plug witness and marker plate installation ubmit AOGCC Test Witness Notification Form 24hrs in advance of witness). 3. Remove the well house, if still installed. 4. Bleed off TWO to ensure all pressure is bled off the system 5. Remove the production tree, in preparation for the excavati n and casing cut. 6. If shallow thaw conditions are found, have shoring box installed during the excavation activity to prevent lose ground from falling ino the excavation. 7. Cut off the wellhead and all casing strings at 4 feet below original ground level. 8. Perform Top Job and verify that cement is at surface in all strings. AOGCC witness and photo document required. 9. Send the casing head w/ stub to materials shop. Photo document. 10. Weld %d thick cover plate (16" O.D.) over all casing strings with the following information bead welded into the top. Photo document. AOGCC Witness required. ConocoPhillips 3G -19A PTD #: 201-106 API #: 50-103-20136-01 11. Remove Cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 12. Obtain site clearance approval from AOGCC. RDMO. 13. 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. is Loepp, Victoria T (DOA) From: Simek, Jill <Jill.Simek@conocophillips.com> Sent: Thursday, February 7, 2019 9:23 AM To: Loepp, Victoria T (DOA) Subject: RE: [EXTERNAL]KRU 3G-10A(PTD 201-106, Sundry 319-008) Final P&A Attachments: 3G -19A PandA Application for Sundry Approval REVISED 2-7-2019.pdf Victoria, Revised procedure for 3G -19A is attached. I just noticed the typo in the subject line ("3G -30A"). Thanks, Jill From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Wednesday, February 06, 2019 9:44 AM To: Simek, Jill <JilI.Simek@conocophill ips.com> Subject: [EXTERNAL]KRU 3G-10A(PTD 201-106, Sundry 319-008) Final P&A Jill, Please attempt an MIT -T and MIT -IA separately after the 1st plug is set. If either fails then attempt an OMIT-TxIA. Please modify the procedure to add the first plug. You may email the modified procedure to me. 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. LoeooCalalaska.aov 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: Simek, Jill <Jill.Simek@conocoohillips.com> Sent: Tuesday, February 5, 2019 4:37 PM To: Loepp, Victoria T (DOA) <victoria.loeop@alaska.aov> Subject: RE: [EXTERNAL]RE: KRU 3G-10A(PTD 201-106, Sundry 319-008) Final P&A Hi Victoria, Last MIT -IA (passed to 3500psi) was 6/23/2001. There is a note of suspect TxIA from the coil tubing fishing job on 9/25/2018, so I would suspect a MIT -IA might fail . Would CMIT-TxIA be acceptable after the plug set? Regarding 7" TOC, I only have the cement report from drilling (attached). Using 40% excess and 9" bit size, I calculate 2,517ft KB TOC. I'm still digging around in our records to see if I can find a log.. Jill From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.eov> Sent: Friday, February 01, 2019 11:13 AM To: Simek, Jill <Jill.Simek(alconocoohillips.com> Subject: [EXTERNAL]RE: KRU 3G-10A(PTD 201-106, Sundry 319-008) Final P&A Also, What is the TOC of the 7" production casing? How was this obtained, cement evaluation log or calculated? Please provide a summary of the cement job. Thanx, Victoria From: Loepp, Victoria T (DOA) Sent: Friday, February 1, 2019 11:10 AM To:'jill.simek@conocophillips.com' <iill.simek@conocoohillips.com> Subject: KRU 3G-10A(PTD 201-106, Sundry 319-008) Final P&A Has an MIT -IA been acquired? What is the MIT -IA history? Please modify the procedure to place a reservoir plug above the packer/fish. This plug will require a tubing tag and a passing MIT -T as well as a passing MIT -IA. Would like to verify reservoir isolation before cementing to surface. 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 V Ictoria. Loeoo(ftlaska.cov 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 aov -;SING I TUBING /LINER DE --L DRILLSITE �r ARCO Alaska, Inc. DATE 8—/3' O Subsidiary of AeanitaRlahfieldCampany Page _ t Of / pages Remarks ARCO PM 118 R. Supervisor !7 u COMPLETEDISCRIPTION OF f f / 'I Y�1�it7GJ h 1 VW' y . , BOTTOM Remarks ARCO PM 118 R. Supervisor !7 u Imag~ roject Well History' File Cover I~' je 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. ~O J_- _J O ~ Well History File Identifier RESCAN DI~/AL DATA / Color items: t.D/ Diskettes, No. [] Grayscale items: [3 Other, No/Type [] Poor Quality Originals: [] Other: NOTES: BY: BEVERLY ROBIN VINCENT SHERYGINDY OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds D^TE:?/~~~;the~ ~ Project Proofing BY: BEVERLY ROBIN VINCENT SHERY[~WINDY Scanning Preparation ,-~ x 30 = ~('~ BY: BEVERLY ROBIN VINCENT SHERYL~WINDY Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: _~. YES BY: Stage 2 IF NO IN STAGE 1 , PAGE(S) DISCREPANCIES WERE FOUND: ~ YES (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES ) NO NO RESCANNEDB~'; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Is~ General Notes or Comments about this file: Quality Checked 12/10/02Rev3NOTScanned.wpd • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ~ ~,,f ~ : ~~$~_. March 12, 2009 ~~~~'~~ ~®/ ~ ~ ~ 20p~ { +'" i R' " ~ r " ~ ~~~ S~~t ,"LE~~~~ ~ ~ N ~`: . _ , J 1 _ ~~~®~~ FBA ~~. Mr. Tom Maunder 1~~®® Alaska Oil & Gas Commission 333 West 7~` Avenue, Suite 100 Anchorage, AK 99501 ~ ~ i -- Dear Mr. Maunder: ~~-- i~A Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRLn. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped February 15~` 2009. The corrosion inhibitor/sealant was pumped March 10~' and 11 ~', 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, %' :` %~" ~ ~: iJ M.J. Loveland ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off -~ Report of Sundry Operations (10-404) Kuparuk Field Date 3/12/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 3G-02 190-137 SF NA 16" NA 1.7 3/11/2009 3G-03 196-122 SF NA 16" NA 1.7 3/11/2009 3G-05 190-075 12'6" 1.80 19" 2/15/2009 4.25 3/10/2009 3G-06 190-069 8'4" 1.20 18" 2/15/2009 3.5 3/10/2009 3G-07A 190-085 25'6" 3.40 18" 2/15/2009 3.4 3/10/2009 3G-11 190-076 22" NA 22" NA 4.25 3/10/2009 3G-14A 197-251 SF NA 17" NA 3.4 3/10/2009 3G-17 190-122 5' 0.80 16" 2/15/2009 2.55 3/10/2009 3G-18 190-125 18" NA 18" NA 4.25 3/10/2009 3G-19A 201-106 18" NA 18" NA 2.55 3/10/2009 3G-21A 198-052 21' 2.80 2'10" 2/15/2009 12.75 3/10/2009 3G-25X 196-136 SF NA 7" NA 2.55 3/10/2009 e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc ) ConocóPhillips ) Mike Mooney Wells Group Team Leader . Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 February 15, 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 ,: tt:: rIEl ""'#.- D 1 6 2005 Com' AnChfJrage ml$$ion Subject: Report of Sundry Well Operations for 3G-19A (APD # 201-106) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent gravel pack installation on the Kuparuk well 3G-19A. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, M1M1::/:J Wells Group Team Leader CPAI Drilling and Wells MM/skad SCANNED FES 1 8 2005 OR\G\NAL Abandon D Alter Casing D Change Approved Program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 7. KB Elevation (ft): RKB 26' 1. Operations Performed: ) ) E' D FE8 1 6 2005 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Stimulate 0 QtÞ~r. dQi!8. Comm'ss~on Ah~s\\a Ù¡¡ Üi. -D.. Waiver D Time ExtenAWt!tUJH¡J~je Re-enter Suspended Well D Repair Well D Pull Tubing D Operat. ShutdownD Plug Perforations D Perforate New Pool D Perforate D 4. Current Well Status: Development - 0 Stratigraphic D Exploratory 0 Service D 5. Permit to Drill Number: 201-106 6. API Number: 50-103-20136-01 9. Well Name and Number: 3G-19A 8. Property Designation: ADL 25548, ALK 2662 11. Present Well Condition Summary: 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE PRODUCTION PROD LINER Perforation depth: measured 8301' feet true vertical 6016' feet measured 8203' feet true vertical 5976' feet Length Size MD 115' 16" 115' 3853' 9-5/8" 3879' 7498' 7" 7524' 895' 4-1/2" 8300' Plugs (measured) Junk (measured) TVD Burst Collapse 115' 3149' 5670' 6015' Measured depth: 8015'-8025', 8060'-8070' true vertical depth: 5897'-5902',5917'-5921' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 7446' MD. RBDMS B~B r~rn r&., rr.:o 1 6 2005 Packers & SSSV (type & measured depth) pkr= BAKER ZXP LINER TOP PKR pkr= 7401' Cameo 'OS' nipple @ 498' 12. Stimulation or cement squeeze summary: through tubing gravel pack installation Intervals treated (measured) 13. Treatment descriptions including volumes used and final pressure: 3520#of 12/18 carbolite placed Oil-Bbl SI 289 Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Tubinç¡ Pressure Casinç¡ Pressure Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations _X 1267 1779 15. Well Class after proposed work: Exploratory D Development 0 Service D 16. Well Status after proposed work: oil0 GasD WAGD GINJD WINJ D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Mike Mooney @ 263-4574 Mike Mooney Title Wells Group Team Leader, ,j!/ Ij , Phone 907-263-4574 Date -;//5- 05 ¡1dF 'W~. tJøtØ. . \. ~ ì t\ I A L Prepared by Sharon ~;;'-Drake 263-4612 ---'mOMS 8Ft FEB 1 " Q R G I \I Form 10-404 Revised 04/2004 Contact Printed Name Signature 254 WDSPL D Submit Original Only ) 3G-19A Well Events Summary ) Date Summary 11/22/04 SET LOWER SWS POSI-SET PLUG IN 4.5" LINER - PUMPED 6 BPM WITH SLICK DIESEL TO PASS 77 DEGREE ANGLE WI 30.8 DEGREE DOGLEG. SET UPPER TIS BRIDGE PLUG IN TUBING - READY FOR GRAVEL PACK 01/21/05 MOVED IN WORK PLATFORM FOR UPCOMING GRAVEL PACK. 01/22/05 SET WORK PLATFORM OVER WELLHEAD AND RU CTU TO WORK PLATFORM. JOB IN PROGRESS. 01/23/05 COMPLETED BOP TEST. WARMED WELL BORE UP, CIRC 125 DEGREE SW FROM SURFACE DOWN TO 7415'. LAYED IN 12.3# BRINE TO SURFACE. MADE UP 663' GRAVEL PACK ASSY & RAN SAME TO 7415'. RECOVERED 12.3# BRINE AND DISPLACED TBG TO DIESEL. RELEASED RBP AND CONTINUED DOWN TO 8078' WITOP OF GRAVEL PACK PACKER 7425'. SET PACKER AND ESTABLISHED INJECTION INTO FORMATION. COMPLETED STEP RATE TEST USING 50# HEC GEL. 01/24/05 PUMP GRAVEL PACK SLURRY USING 50# HEC AND #12/18 CARBOLlTE @ 1.2 PPG, ACHEIVED 1700 PSI SAND OUT PLACED 3520# BEHIND PIPE WI 143 LBS PER FT @ THE PERFS, CIRCULATED ABOVE GRAVEL PACK PACKER AND CLEANED TBG WI 50#HEC, 1.5# BIO, & DIESEL. UNABLE TO RELEASE FROM GRAVEL PACK PACKER. DROPPED BALL AND DISCONNECTED FROM GRAVEL PACK TOOLSTRING. POOH WASHING WIDIESEL AT 1.7 BPM, HOLDING 1:1 RTNS. DEMOBED COIL UNIT. Permit to Drill 2011060 DATA SUBMITTAL COMPLIANCE REPORT 7~8~2003 Well Name/No. KUPARUK RIV UNIT 3G-19A Operator CONOCOPHILLIPS ALASKA INC MD 8301J TVD 6016 -~ Completion Dat 6/21/2001 f Completion Statu 1-OIL Current Status 1-OIL APl No. 50-103-20136-01-00 UIC N REQUIRED INFORMATION Mud Log No Sample N._9 Directional Survey N_go DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Ty~e_ ~..~ i a Fmt (data taken from Logs Portion of Master Well Data Maint) Interval Log Log Run OH I Dataset Name Scale Media No Start Stop CH Received Number Comments ,r~LIS Verification 1 7500 8260 Open 1/3/2002 4..1~1~96 ~ LIS Verification 1 7500 8260 Open 4/26/2002 ~r~'' cB,''/'. MWD Survey FINAL OH 7/18/2001 Cn See Notes 1 7309 8198 Case 9/13/2002 MWD Survey, Digital Data Memory Multi-finger Caliper Log Results Summary Well Cores/Samples Information: Interval Dataset Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y Chips Received? Y-/-N---" Analysis RP.c.P. ivRd';) Daily History Received? ~/~ / N Formation Tops ~ / N Comments: Compliance Reviewed By: I l..L LOG ,,. TRANSMITTAL ProActive Diagnostic Services, Inc. To: State of Alaska AOG~ 333 W. 7th Street Suite 700 Anchorage, Alaska 99501 RE' Distribution - Final Print{s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of' Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 L08 DiGiTAL MYLAr / BLUE LINE REPORT' WELL DATE TYPE OR SEPIA PRINT{S) OR CD-ROM F~LM BLUE L~NE , , , , Open Hole' ' I I 1 ,, , Res. Eval. CH I I 1 ,, , , ' Mech. 'CH ' ,, 3C~19A1 9/2/02 Caliper Survey 1 Rpt or 2 Color Signed' ~. ~ Date' Print Name: RECEIVED :SEP 1 Alaska O, & G~ Cons. Commm~mn Anchorage ProActive Diagnostic Services, Inc., 310 K Street Suite 200, Anchorage, AK 99501 Phone:(907) 245-8951 Fax:(907) 245-8952 E-mail: pdsanchorage~memorylog.com Website: w~'.memorvlog.com WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 March 05, 2002 RE: MWD Formation Evaluation Logs 3G-19A, AK-MM-II099 The technical data listed below is being submitted herewith. Please address any problems or concems to the attention of~ Jim Galvin, Sperry-Sun Drilling Services, 6900 .Arctic Blvd., Anchorage, AK 99518 3G-19A: Digital Log Images 50-103-20136-01 1 CD Rom RECEIVED 2002 AlaekaOil &Gas Cons. Commissio WEIJ, LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Lisa Weepie 333 West 7a Avenue, Suite 100 Anchorage, Alaska December 18, 2001 RE: MWD Formation Evaluation Logs 3G-19A, AK-MM- 11099 1 LDWG formatted Disc with verification listing. API#: 50-103-20136-01 PLEASE ACKN'OWLE1)GE RECEIPT BY sIGNING, AND RETURNING, A CoPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: RECEIVED JAH 0 5 2002 Alaska 0ii & Gas Cons. Commissior~ Anc~rage PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 C. Mallary Phone (907) 265-6434 Fax: (907) 265-6224 August 8, 2001 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7tn Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for 3G- 19A (201-106) Dear Ms. Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Kuparuk well 3G- 19A. If you have any questions regarding this matter, please contact Brian Noel at 265-6979. Sincerely, C. Drilling Engineering Supervisor PAI Drilling CM/skad ORIGINAl. RECEIVED AUG 10 2001 Alaska 0ii & Gas CONS. Commission ~chora[te , . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil [~] Gas E] Suspended D Abandoned D service E] ~ 2. Name of Operator ~ "~~ 7. Permit Number Phillips Alaska, Inc. ' i.,,-?~;3.-~-- 201-106 3. Address ~u~ 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360!~,~. ~ 50-103-20136-01 4. Location of well at sudace 9. Unit or Lease Name 2538' FNL, 145' FEL, Sec. 23, T12N, R8E, UM (ASP: 498235, 5988561) I f'"0M~.P~ 10~ Kuparuk River Unit At Top Producing Interval!.~r 10. Well Number 1712' FNL, 1718' FEL, Sec. 26, T12N, R8E, UM (ASP: 496664, 5984108) ~ ~ 3G-19A At Total Depth L~ 11. Field and Pool 1860' FNL, 2097' FEL, Sec. 26, T12N, R8E, UM (ASP: 496285, 5983960) , Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Kuparuk River Pool RKB 26' feetI ADL 25548 ALK 2662 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions ! June 15, 2001 June 17, 2001 June21, 2001 I N/A feetMSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 8301' MD / 6016' TVD 8203' MD / 5976' TVD YES r~ No E]I N/A feet MD 1 6O0' (approx) 22. Type Electric or Other Logs Run MWD/GR/Res/PWD, CCL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD I CASING SIZE WT. PER FT. GRADE TOP BO3-1'OM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 62.5# H-40 Surface 115' 24" 216 sx AS I 9.625" 36# J-55 Surface 3879' 12.25" 845 sx AS III & 545 sx Class G 7" 26# J-55 Surface 8200' 8.5" 485 sx Class G & 200 sx Class G Tail 4.5" 12.6# L-80 7401' 8300' 6.125" 262 sx Class G 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 7401' 7401' 8015'-8025' MD 5898'-5902' TVD 6 spf 8060'-8070' MD 5917'-5921' TVD 6 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8015'-8025' MD 4198# of 16/20# behind pipe w'~ ppa, left 3384# prop in wellbore 8060'-8070' MD placed 170258# proppant in formation, left 9076# of prop in wellbore 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) July 20, 2001 Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I 7/23/2001 18 hrs Test Period > 541 344 1147 100 I 44.6 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (con') 3ress. 227 psi 1323 24-Hour Rate> 659 494 1500 24.7° 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. RECEIV£D N/A AUG 1 0 ?.001 ORIGINAL^laska 0ii & Gas C0ns' C°n~missi°n Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 7859' 5838' Base Kuparuk C 7892' 5849' Top Kuparuk A 7912' 5856' Base Kuparuk A 8208' 5979' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following Is true and correct to the best of my knowledge. Questions? Brian Noel 265-6979 ~"~ . ~'~ Title Drillin,q E n.qineerin,q Supervisor Date Signed C. Mallary ~ Prepared by Sharon Al~sup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. 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 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 PHILLIPS ALASKA INC. page 1 of 3 Operations Summa Report Legal Well Name: 3G-19 Common Well Name: 3G-19A Spud Date: 6/7/2001 Event Name: ROT- SIDETRACK Start: 6/9/2001 End: Contractor Name: Nordic Rig Release: Group: Rig Name: Nordic 3 Rig Number: 3 Sub Phase Description of Operations Date From - To HoUrs COde Code 6/11/2001 07:30 - 13:30 6.00 MOVE MOB MOBMIR Move rig from 3J pad to 3G pad (7.5 miles) & spot over well # 19A-Accept rig @ 1330 Hrs. 06/11/2001. 13:30 - 15:30 2.00 ABANDN OTHR ABANDN Spot cutting tank & trash bins-run hard line to kill tank-rig up kill manifold. 15:30 - 18:00 2.50 ABANDN OTHR ABANDN Pull BPV & VR plug-350# on tbg. & annulus. 18:00 - 21:00 3.00 ABANDN CIRC ABANDN PJSM-Displace well w/8.5# seawater @ 4.3 bpm thru choke-monitor well-well dead 21:00 - 00:00 3.00 ABANDI~ NUND ABANDN Set BPV-Nipple down tree-nipple up bope. 00:00 - ABANDI~ ABANDN 6/12/2001 00:00 - 02:30 2.50 ABANDI~ NUND ABANDN Nipple up bope-change door seals in upper pipe rams. 02:30- 03:30 1.00 ABANDI~ OTHR ABANDN Pull BPV-set 2 way check. 03:30- 06:00 2.50 ABANDI~ OTHR ABANDN Test bope 250-5000# 06:00 - 07:30 1.50 ABANDI~ OTHR ABANDN Pull 2 way check-install landing jt.-bolds. 07:30 - 08:00 0.50 ABANDI~ WLHD ABANDN Pull hanger & lay down same-rig up control line spooler. 08:00 - 18:00 10.00 ABANDI~ RTRV ABANDN POH laying down 3.5" tbg-recovered 31 control line bands-243 jts. tbg.-cut off piece-Tbg, had hard crude & scale build up from 5745' to 5847'. 18:00 - 20:30 2.50 ABANDI~ OTHR ABANDN Load out mandrels & misc. tbg. equipment-load 9 steel dc,s-18 hwdp-Clean floor area-PJSM. 20:30 - 00:00 3.50 ABANDI~ OTHR ABANDN Make up bha #1 & run in hole picking up 3.5" dp. 6/13/2001 00:00- 02:00 2.00 ABANDN TRIP ABANDN RIH w/bit & 7" csg. scraper. 02:00 - 06:00 4.00 ABANDN CIRC ABANDN Break circ.-hook up hot oil truck & pump 60 bbls. hot diesel down annulUS to bit-pump down dp & bring diesel back-pump diesel down again & out thru dp. 06:00- 07:00 1.00 ABANDN SFTY ABANDN Crew change-service rig & PJSM. 07:00- 12:00 5.00 ABANDNTRIP ABANDN POH w/7" scraper. 12:00 - 13:00 1.00 ABANDN OTHR I ABANDN Lay down bha & clear floor. 13:00 - 17:30 4.50 ABANDN PLUG 'ABANDN PJSM-Rig up SWS & rih w/7" bridge plug-set same @ 7530' WLM-poh & rig down sws. 17:30 - 18:00 0.50 ABANDN OTHR ABANDN Test csg. to 3000# 30 mins. OK. 18:00 - 22:00 4.00 ABANDI~ TRIP ABANDN Make up Whipstock & milling assembly-rih-hit tight spot @ 1639'-bottom of whipstock-tight-work loose-appears to be upper mill w/ 6.151 OD stuck in cement stage collar. 22:00- 00:00 2.00 ABANDI~ TRIP ABANDN POH & laydown whipstock. 6/14/2001 00:00-02:00 2.00 ABANDI~TRIP ABANDN I Make up new bha & rih w/ same to to1619. 02:00 - 02:30 0.50 ABANDI~ MILL ABANDN Make up top drive-break circ.-mill thru dv collar. 02:30- 04:00 1.50 ABANDF, TRIP ABANDN Finish rih-tag bp @ 7531 DPM. 04:00 - 06:00 2.00 ABANDI~ CIRC ABANDN Make up.top drive-displace seawater out w/milling fluid. 06:00 - 07:00 1.00 ABANDI~ OTHR ABANDN Crew change-service rig-Pump dry job. 07:00- 09:30 2.50 ABANDI', TRIP ABANDN POH for whipstock. 09:30- 10:00 0.50 ABANDI~ SFTY ABANDN Rig assesment meeting. 10:00- 12:00 2.00 ABAND~ TRIP ABANDN Finish poh for whipstock. 12:00- 21:00 9.00 ABAND~ TRIP ABANDN Pick up whipstock & rih. 21:00 - 22:00 1.00 ABANDI~ CIRC ABANDN Break circ.-orient & set whipstock 75 deg. right of hi side. 22:00- 00:00 2.00 ABANDI~ MILL ABANDN Start milling top of window @ 7511'. 6/15/2001 00:00 - 06:00 6.00 WINDOV 'STWP PROD Milling window from 7511 to 7524 & milling new hole from 7524' to 7539'. (recovered 134# metal cuttings.) 06:00 - 08:00 2.00 WINDOV 'CIRC PROD Pump sweep & circ. hole clean. 08:00 - 08:30 0.50 DRILL FIT PROD Perform FIT @ 13.2# OK. 08:30 - 12:00 3.50 DRILL TRIP PROD POH for drilling assembly. 12:00 - 14:00 2.00 DRILL PULD PROD Lay down milling bha-make up mud motor & stand back in derrick. 14:00 - 15:30 1.50 DRILL OTHR PROD Make up stack washer-clean metal from bope-clear floor. Printed: 7/16/2001 4;00:22 PM PHILLIPS ALASKA INC. Page 2 of 3 Operations Summa Report Legal Well Name: 3G-19 Common Well Name: 3G-19A Spud Date: 6/7/2001 Event Name: ROT- SIDETRACK Start: 6/9/2001 End: Contractor Name: Nordic Rig Release: Group: Rig Name: Nordic 3 Rig Number: 3 Sub Phase Description of Operations Date From-To Hours Code Code 6/15/2001 15:30- 18:00 2.50 DRILL F:'ULD PROD Make up drlg. assembly-up load mwd. 18:00 - 22:00 4.00 DRILL TRIP PROD Pick up 30 jts. 3.5" dp-Tag @ 7539'-orient from window. 22:00 - 00:00 2.00 DRILL DRLG PROD Sliding from 7539 to 7558'. 6/16/2001 00:00 - 00:00 24.00 DRILL DRLG PROD Drlg. & surveys from 7558' to 7955'. No Gains No losses on drlg. fluids-avg. 13.5 ECD,s. 6/17/2001 00:00 - 14:30 14.50 DRILL DRLG PROD Drlg. & surveys from 7955' to 8300 TD. 6015' TVD. 14:30 - 16:00 1.50 DRILL PROD Cim. bottoms up for trip out of hole. (Rotate & Reciprocate.) 16:00 - 20:30 4.50 DRILL TRIP PROD POH for Hole Opener Assembly to to Hi-dog legs. 20:30- 22:30 2.00 DRILL 3ULD PROD Lay down BHA-download MWD. 22:30 - 00:00 1.50 DRILL TRIP PROD Lay down 6 Steel dc,s-Make up & rih w/hole opener assembly. 6/18/2001 00:00 - 02:30 2.50 DRILL TRIP PROD RIH w/hole opener & roller reamer to 7500'. 02:30 - 05:30 3.00 DRILL :{EAM PROD Make up top drive & run thru window-Wash & ream from 7524' to 8300'. Ream out dog legs. 05:30 - 07:00 1.50 DRILL CIRC PROD pump hi-vis sweep & cbu. 07:00 - 11:30 4.50 DRILL TRIP PROD Poh & lay down hole opener assembly. 11:30 - 14:30 3.00 CASE PULR PROD Rig up & run 28 jts. 4.5" 12.6# L-80 NSCT liner-make up liner hanger & packer. 14:30 - 15:30 1.00 CASE ClRC PROD Change handling equipment & circ. capacity of 4.5" liner. 15:30 - 19:30 4.00 CASE RUNL PROD RIH w/4.5" liner on 3.5" dp to 7500'. 19:30 - 20:00 0.50 CASE ClRC PROD Circ. volume of liner & dp.-Make up cement head on single. 20:00 - 21:00 1.00 CASE RUNL PROD Run liner in open hole to 8300'. (hole Knotty.) 21:00 - 00:00 3.00 CASE ClRC PROD Break circ. @ 4 bpm-Reciprocate pipe while circ. Circ. condition mud for cementing liner. 6/19/2001 00:00 - 01:00 1.00 CEMEN'I'DISP CMPLTN Crnt 4.5" liner as follows: Pump 5 bbl CW100, pt to 4000 psi, pump 5 bbl CW100 followed by 40 bbl mud push @ 14.0 ppg. Pumped 42 bbl cmt / 262 sx Cl G [+adds] @ 15.8 ppg / yield 1.2, rates / pressures 5 -6 bpm / 1200 - 750 psi. Reciprocate pipe until CW100 on formation then set 2' off td @ 8298'. Drop plug & disp w/2 bbl fw, hand over to rig. Rig continued disp to bump plug w/64 bbl [total = 66 bbl]. Bump to 1250 psi, then increase pressure to 2900 psi to set flex loc hanger. Continue to 3800 psi to initiate the hydraulic push sleeve setting the ZXP packer. Hold 5 minutes, bleed off pressure [floats held] keeping 25k lbs on hanger, Rotate off liner 20 right hand turns. Pressure up dp to 1000 psi, pu & observe pressure bleed off. Pump 15 bbl down dp to clear liner top. 01:00 - 02:00 1.00 CEMEN'I' OTHR CMPLTN Ru / Reverse out excess cmt until uncontaminated returns to surface, recovered 15 bbl contaminated cmt / mud. 02:00 - 03:00 1.00 CMPLTN RURD CMPLTN !Break down /lay out surface cmt equip. Mix & pump dry slug. 03:00 - 10:00 7.00 CMPLTN TRIP CMPLTN Pooh /Iddp & liner setting equipment. 10:00 - 11:00 1.00 CMPLTN TRIP CMPLTN Rih w/dp from derrick, pooh Id same, hwdp & dc's. 11:00 - 12:00 1.00 CMPLTN OTHR CMPLTN Pull wear bushing, police floor & prep to completion. 12:00- 14:00 2.00 CMPLTN RUNT CMPLTN Run seal assmby & tbg as per program. 14:00 - 16:00 2.00 RIGMNT RGRP CMPLTN Problems w/tongs - unable to repair - sheared gears. 16:00 - 16:30 0.50 WALTON EQIP CMPLTN we replacement tongs / ru standby backup tongs. Printed: 7/16/2001 4:00:22 PM PHILLIPS ALASKA INC. Page 3 of 3 Operations Summa Report Legal Well Name: 3G-19 Common Well Name: 3G-19A Spud Date: 6/7/2001 Event Name: ROT - SIDETRACK Start: 6/9/2001 End: Contractor Name: Nordic Rig Release: Group: Rig Name: Nordic 3 Rig Number: 3 Sub Date From - To Hours Code Code Phase Description of Operations 6/19/2001 16:30- 18:00 1.50 CMPLTI~ RUNT CMPLTN Continue to run tbg w/rig tongs. 18:00 - 19:00 1.00 CMPLTN SFTY CMPLTN RU Foster Tongs / PJSM on replacement power tongs. 19:00- 00:00 5.00 CMPLTN RUNT CMPLTN Continue to run completion. 6/20/2001 00:00-01:30 1.50 CMPLTN RUNT CMPLTN SpaceoutTbg- NoGoTag @ 7414' 01:30 - 02:30 1.00 CMPLTN DEQT CMPLTN Test 3 1/2" X 7" Ann to 3500 psi - Chart & hold 30 min - R/D Test Equip 02:30 - 04:30 2.00 CMPLTN ClRC CMPLTN Circu Well bore fluid over to Sea Water per Bariod Plan - Pump 85 bbls barazen pi11,35 bbls caustic wash,120 bbls fresh water & 580 bbls Sea Water - Sample @ end pump = NTV 110 04:30 - 05:30 1.00 CMPLTN SOHO CMPLTN Space Out - P/U pup(l= 2.36') Hanger & Ld Jt (Land w/1.14' above locater- Land Tbg - RILDS 05:30 - 08:30 3.00 CMPLTN DEQT CMPLTN R/U to test Tbg - Test Tbg to 3500 psi & hold 15 rain (loss 25 psi) - Test 3 1/2" X 7" Ann to 3500 psi & hold 15 min(Ioss 140 psi) - Bleed psi off Tbg to shear DCR valve -"No Shear" - Pressure up on 3 1/2" X 7' Ann to 3480 psi - DCR valve Sheared - Pressure up on 3 1/2" TBG & Ann to 3500 psi and hold for 30 min-Pressure bleed to 3260 psi and held steady (240 psi loss) 08:30- 09:00 0.50 CMPLTN NUND CMPLTN L/D Ld JT- Set BPV 09:00- 12:00 3.00 CMPLTN NUND CMPLTN N/D BOPs 12:00 - 23:00 11.00 CMPLTN NUND CMPLTN Attempt N/U Tree - Tbg Adapter not matched to Tbg Hanger Ran(Top extenion 2" long on hanger) Cameron Rep (Mark Kerschion) After talking with Cameron Engineers(Houston) had Tbg Adapter Milled to accept long extenion Hanger. -@ 8:30PM N/U milled Adapte & Tree -Test packoff 5000psi/held 15 min - Pull BPV - Install test plug - Test Tree 250/5000 psi "OK" - Pull Test Plug 23:00 - 00:00 1.00 CMPLTN OTHR CMPLTN R/U to Freeze Protect Well - Pump 85 bbls Diesel Dn 3 1/2" X 7" Annulus - Put Tbg & Ann in communication - Let U Tube( Diesel Cap Top 2414' MD) 6/21/2001 00:00 - 01:30 1.50 CMPLTN FRZP CMPLTN Allow diesel to u tube for freeze protection. 01:30 - 02:30 1.00 CMPLTN OTHR CMPLTN RD circulation equip. Set bpv & secure tree. 02:30 - 04:00 1.50 CMPLTN SFTY CMPLTN PJSM on rig move. Move off well. Load out aux equip. Clean up cellar area. Moving @ 0400 hrs / rig released. Printed: 7/16/2001 4:00:22 PM Date 06/28/01 Well Na 3G-19A Service Type COILED TUBING Desc of Work PERFORATE Supervisor KENNEDY Complet r~ Accident I~ Injury I- spil~ I- Summary UpC~,, ,~ing f-- Job Num 0531011826.4 Unit UNIT #2 AFC 999659 1 Prop 230DS36( Uploaded to Set Contractor Key Perso DS-WHITTUM Successful r~ Initial Tbg Press 600 Initial Int Csg Press 550 Initial Out Csg Press 200 Final Tbg Press 500 Final Int Csg Press 650 Final Out Csg Press 200 PERFORATED FROM 8015' -8025' RKB W/2.5" HSD CARRIER, 6 SPF, ALT. DP & BH CHARGES. ATTEMPTED TO INJECT INTO WEI TIGHT, HELD AT 2500 PSI WITH VERY LITTLE BLEED-OFF. WELL FREEZE PROTECTED W/DIESEL TO 2500'+. [Perf] Fluid Summary 80 SLICK DIESEL Date printed: 07/16/01 at: 16:16:15 Date 06/29/01 Well Na 3G-19A Service Type PUMPING Desc of Work A SAND FRAC ATTEMPT Supervisor CHANEY Complet I-- Accident ~-- Injury l- sp~ l- Summary Upco,, ,lng Job Num 0531011826.4 Unit AFC 999659 1 Prop 230DS36(- Uploaded to Ser Contractor Key Perso DS-GALLEGOS Successful F- Initial Tbg Press 1400 1200 Initial Int Csg Press 600 500 Initial Out Csg Press 200 Final Out Csg Press 200 Final Tbg Press Final Int Csg Press "A" SAND FRAC Al-tEMPTED. PUMPED APP 112 BBLS OF 20# GEL FOR BREAKDOWN VERY TIGHT 30 BPM & 9200 PSI. TREESAVE FAILED TWICE AND CAME APART IN THE WELL. LEFT 2.89" X 2" X 9.5" BULLNOSE OF TREESAVER IN THE HOLE. WILL RE-ATtEMPT FISH RETRIEVED. [Frac-Refrac] Fluid Summary 120 BBLS OF SEAWATER Date printed: 07/16/01 at: 16:16:34 Date 06/30/01 Well Na 3G-19A Service Type PUMPING Desc of Work "'A" SAND FRAC Supervisor CHANEY Complet I-- Accident F- Injury I-- sp~ i- Summary Upco,, ,~ng r- Job Num 0531011826.4 Unit AFC 999659 1 Prop 230DS36E- Uploaded to Set Contractor Key Perso DS-GALLEGOS Successful I~ Initial Tbg Press 1200 Initial Int Csg Press 700 Initial Out Csg Press 200 Final Tbg Press 1600 Final Int Csg Press 500 Final Out Csg Press 200 "A" SAND FRAC PUMPED. NWBSO AS 2 PPA WENT THRU THE PERF'S. PUT 4198 LBS OF 16/20# BEHIND PIPE W/#2 PPA @ THE I LEFT 3384 LBS OF PROP IN THE WELLBORE. LEFT 50% OF TREESAVER RUBBER IN WELLBORE. [Frac-Refrac] Fluid Summary 10 BBLS DIESEL 1485 BBLS OF SEAWATER Date printed: 07/16/01 at: 16:17:17 Date 07/02/01 Well Na 3G-19A Service Type COILED TUBING Desc of Work CTU MEMORY LOG / PERF Supervisor RENNIE-KENNEDY Complet r~ Accident ['- Injury l- sp~ F- Summary Upc~c" ,'ing F Job Num 053101182604 Unit UNIT #2 Contractor Key Perso DS-ROBINSON Successful r~ Initial Tbg Press 750 Initial Iht Csg Press 300 Initial Out Csg Press 225 AFC 999659 1 Prop 230DS36C Uploaded to Ser Final Tbg Press 1160 Final Int Csg Press 300 Final Out Csg Press 225 CONT'D FROM PREVIOUS WSR. OBTAINED MEMORY CCL/GR LOG FROM 7500' TO 8150'. FLAGGED PIPE AT 8000' CTM. PERFORATED FROM 8060'-8070' MD W/2-1/2" HC W/BH CHGS, 6 SPF, 60 DEGREE PHASING. [Per0 Fluid Summary 25 BBL SLICK SEAWATER 25 SLICK DIESEL Date printed: 07/16/01 at: 16:17:54 Date 07/02/01 Well Na 3G-19A Service Type PUMPING Desc of Work "A" SAND FRAC Supervisor CHANEY Complet r~ Accident F- Injury I~ Spill F- summary Upcoming Job Num 0531011826.4 Unit AFC 999659 0 Prop 230DS36( Uploaded to Se~ Contractor Key Perso DS-GALLEGOS Successful ~ Initial Tbg Press 1250 Initial Int Csg Press 150 Initial Out Csg Press 50 Final Tbg Press 800 Final Int Csg Press 500 Final Out Csg Press 200 "A" SAND FRAC COMPLETED PER DESIGN ACHIEVED TSO W/10 PPA OF 16/20# @ THE PERF'S. PLACED 170258 LBS OF PROP FORMATION. FLUSHED TO 4600' & LEFT 9076 LBS OF PROP IN THE WELLBORE. [Frac-Refrac] Fluid Summary 1750 BBLS SEAWATER 20 BBLS DIESEL Date printed: 07/16/01 at: 16:18:07 12-Jul-01 AOGCC 333 VV. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for WelI3G-19A ~_O t -- ~[~ Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 7.493.55' MD 'MD 8,301.00' MD (if applicable Please call me at 273,3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED 'JUL 18 ~ Oil & Gas Cons. Kuparuk River Unit North Slope, Alaska Kuparuk 3G, Slot 3G-19 3G-19A Job N°. AKMMlf099, Surveyed: ~7 June, 200~ SURVEY REPORT 18 July, 2001 Your Ref: API501032013601 Surface Coordinates: 5988560.54 N, 498234.68 E (70° 22' 47.9249"N, Kelly Bushing: 83.55ft above Mean Sea Level f SO° 00' 51.6708" VI~) DRILLING SERVICES A Halliburton Company Survey Ref: svy957f Kuparuk River Unit Measured Depth Incl. (ft) 3G-19 0.00 0.000 0.000 93.55 0.230 239.170 193.55 0.240 260.780 293.55 0.180 258.760 393.55 0.090 224.300 493.55 0.560 208.770 593.55 2.840 190.460 693.55 7.000 192.210 793.55 9.060 -193.910 893.55 12.980 192.350 993.55 17.720 192.310 1093.55 24.540 194.260 1193.55 24.570 195.130 1293.55 24.950 195.880 1393.55 25.910 200.200 Sub-Sea Depth (ft) -83.55 10.00 110.00 210.00 310.00 410.00 509.95 609.56 708.57 806.71 903.11 996.33 1087.29 1178.10 1268.42 1493.55 27.630 200.200 1357.70 1593.55 29.510 198.290 .1445.52 1693.55 31.520 198.700 1531.66 1793.55 31.840 198.750 1616.76 1893.55 39.210 193.370 1698.11 1993.55 41.590 2093.55 42.560 2193.55 44.100 2293.55 48.070 2393.55 46.850 195.900 199.360 198.960 196.120 196.960 f8 July, 200'/- 4:07 1774.26 1848.50 1921.24 1990.59 2058.20 Vertical Depth (ft) Sperry-Sun Drilling Services Survey Report for 3G-19 Your Ref: AP!$01032013601 Job No. AKMMl1099, Surveyed: 17 June, 2001 Local Coordinates Global Coordinates Northings. Eastings Northings Eastings (ft) (ft) (ft) (ft) 0.00 93.55 193.55 293.55 393.55 493.55 593.50 693.11 792.12 890.26 986.66 1079.88 1170.84 1261.65 1351.97 1441.25 1529.07 1615.21 1700.31 1781.66 1857.81 1932.05 2004.79 2074.14 2141.75 0.00 N 0.00 E 5988560.54 N 498234.68 E 0.10 S 0.16W 5988560.44N 498234.52 E 0.23 S 0.54W 5988560.31 N 498234.14 E 0.30 S 0.90W 5988560.24 N 498233.78 E 0,38 S 1.11W 5988560.16 N 498233.57 E FJN T VE North Slope, Alaska Kuparuk 3G Dogleg Vertical Rate Section Comment (°/lOOft) 0.00 0.246 0.19 0.089 0.58 0.060 0.92 0.117 1.15 0.87 S 1.40W 5988559.67 N 498233.28 E 0.474 1.65 3.73 S 2.09W 5988556.81N 498232.59 E 2.315 3.72 12.13 S 3.82W 5988548.41N 498230.85 E 4.162 9.56 25.73 S 7.01W 5988534.81 N 498227.67 E 2.073 19.33 44.35 S 11.30W 5988516.19 N 498223.37 E '3.931 32.65 70.20 S 16.95W 5988490.34 N 498217.71 E 105.24 S 25.32W 5988455.31 N 498209.33 E 145.44 S 35.86W 5988415.11N 498198.78 E 185.79 S 47.06W 5988374.76 N 498187.57 E 226.59 S 60.38W 5988333.97 N 498174.25 E 268.86 S 75.93W 5988291.70 N 498158.69 E 314.01S 91.67W 5988246.55 N 498142.94 E 362.16 S 107.78W 5988198.41 N 498126.82 E 411.89 S 124.64W 5988148.67 N 498109.94 E 467.71S 140.45W 5988092.86 N 498094.12 E 530.40 S 156.86W 5988030.18 N 498077.70 E 594.24 S 177.16W 5987966.35 N 498057.38 E 659.05 $ 199.68W 5987901.53 N 498034.84 E 727.73 S 221.33W 5987832.86 N 498013.18 E 798.36 S 242.30W 5987762.24 N 497992.20 E Page 2 of 6 4.740 50.88 6.855 76.20 0.363 106.04 0.493 136.53 2.088 169.06 1.720 204.27 2.090 241.13 2.021 279.86 0.321 320.05 7.999 362,51 2.890 409.02 2.513 459.47 1.564 512.32 4.465 566.42 1.368 620.96 Tolerable Gyro DrillQuest 2.00.08.005 Kuparuk River Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth fit) 2493.55 45.750 198.630 2127.29 2593.55 44.940 198.700 2197.58 2693.55 44.760 199.830 2268.47 2793.55 44.650 200.220 2339.55 2893.55 47.810 194.670 2408.74 2993.55 48.340 192.880 2475.56 3093.55 47.690 193.370 2542.45 3193.55 47.070 194.400 2610.17 3293.55 46.380 195.300 2678.72 3393.55 45.980 195.880 2747.96 3493.55 49.730 196.850 3593.55 49.750 198.740 3693.55 49.390 199.260 3793.55 49.330 204.290 3893.55 48.870 205.360 2815.05 2879.68 2944.53 3009.68 3075.16 3993.55 48.180 206.030 3141.39 4093.55 46.640 206.320 3209.06 4193.55 45.130 207.890 3278.67 4293.55 42.870 209.580 3350.60 4393.55 41.050 210.820 3424.96 4493.55 41.560 201.920 4593.55 42.450 198.680 4693.55 46.950 196.930 4793.55 48.150 197.730 4893.55 47.730 197.470 35O0.15 3574.46 3645.53 3713.02 3780.01 Sperry-Sun Drilling Services Survey Report for 3G-19. Your Ref: API501032013601 Job No. AKMMff099, Surveyed: ~7 June, 200~ J Vertical Depth 2210.84 2281.13 2352.02 2423.10 2492.29 Local Coordinates Global Coordinates Dogleg Northings Eastings Northings Eastings Rate (ft) (ft) fit) fit) (°/100ft) 867.20 S 934.59 S 1001.16 S 1067.26 S 1136.11S 264.38W 5987693.41N 497970.10 E 1.633 287.15W 5987626.02 N 497947.31E 0.812 310.41W 5987559.45 N 497924.03 E 0.817 334.50W 5987493.36 N 497899.93 E 0.296 356.04W 5987424.51 N 497878.37 E 5.102 2559.11 2626.00 2693.72 2762.27 2831.51 1208.37 S 1280.76 S 1352.20 S 1422.57 S 1492.07 S 373.75W 5987352.26 N 497860.64E 1.433 390.63W 5987279.87 N 497843.75 E 0.745 408.28VV 5987208.44 N 497826.08 E 0.979 426.94W 5987138.07 N 497807.40 E 0.952 446.33W 5987068.58 N 497788.00 E 0.579 2898.60 1563.19 S '467.23W 5986997.46 N 497767.08 E 3.818 2963.23 1635.84 $ 490.55W 5986924.81 N 497743.74 E 1.442 3028.08 1707.82 S 515.33W 5986852.85 N 497718.94 E 0.535 3093.23 1778.24 S 543.47W 5986782.43 N 497690.79 E 3.817 3158.71 1846.84 S 575.20W 5986713.83 N 497659.05 E 0.930 4993.55 46.380 200.040 3848.15 5093.55 46.310 199.720 3917.18 5193.55' 46.380 199.900 3986.21 5293.55 45.420 199.280 4055.80 5393.55 45.340 198.530 4126.04 f8 July, 200f - 4:07 3224.94 1914.36 S 607.68W 5986646.33 N 497626.55 E 0.853 3292.61 1980.43 S 640.15W 5986580.26 N 497594.06 E 1.555 3362.22 2044.34S 672.85W 5986516.36 N 497561.35 E 1.884 3434.15 2105.25 S 706.22W 5986455.46 N 497527.96 E 2.547 3508.51 2163.04 S 739.84W 5986397.68 N 497494.33 E 2.000 3583.70 2222.06 S 769.07W 5986338.66 N 497465.08 E 5,893 3658.01 2284.81S 792.27W 5986275.92 N 497441.87 E 2.344 3729.08 2351.77 S 813.73W 5986208.96 N 497420.40 E 4.665 3796.57 2422.21S 835.71W 5986138.53 N 497398.40 E 1.337 3863.56 2492.97 S 858.16W 5986067.77 N 497375.93 E 0.462 3931.70 4000.73 4069.76 4139.35 4209.59 2562.28 S 2630.32 S 2698.39 S 2766.04 S 2833.38 S 881.68W 5985998.47 N 497352.40 E 2.315 906.28W 5985930.43 N 497327.78 E 0.242 930.80W 5985862.37 N 497303.24 E 0.148 954.88W 5985794.72 N 497279.15 E '1.058 977.94W 5985727.39 N 497256.07 E 0.540 Page 3 of 6 North Slope, Alaska Kuparuk 3G Vertical Section Comment 675.52 729.92 784.32 839.17 893.28 945.87 997.82 1049.94 1102.36 1154.96 1209.70 1267.29 1325.79 1386.34 1449.03 1511.80 1573.81 1634.90 1695.00 1753.70 1809.29 1861.65 1914.70 1970.01 2025.88 2081.91 2138.21 2194.46 2250.11 2304.73 DrillQuest 2.00.08.005 KuparUk River Unit Measured Depth Incl. Azim. Sub-Sea Depth (ft) 5493.55 45.300 198.300 4196.36 5593.55 45.980 197.960 4266.27 5693.55 47.090 198.110 4335.06 5793.55 46.940 197.930 4403.24 5893.55 46.950 192.330 4471.54 5993.55 47.130 191.610 6093.55 46.740 192.170 6193.55 46.290 192.870 6293.55 46.500 192.620 6393.55 46.300 192.070 4539.69 4607.98 4676.79 4745.76 4814.72 6493.55 46.820 191.580 4883.48 6593.55 47.300 191.980 4951.61 6693.55 47.730 192.100 5019.14 6793.55 48.200 191.780 5086.10 6893.55 47.850 192.240 5152.98 6993.55 46.490 194.660 7093.55 47.010 194.550 7193.55 -46.310 190.070 7293.55 46.720 189.220 7393.55 47.060 189.820 5220.97 5289.49 5358.14 5426.96 5495.30 7493.55 44.590 193.050 5564.99 18 July, 2001- 4:07 VertiCal Depth (ft) Sperry-Sun Drilling Services Survey Report for 3G-19 Your Ref: APIS01032013601 Job No. AKMM11099, Surveyed: 17 June, 2001 4279.91 4349.82 4418.61 4486.79 4555.09 .Local Coordinates Northings Eastings (ft) (ft) 2900.84 S 2968.79 S 3037.80 S 3107.37 S 3177.85 S 1000.40 1022.65 1045.12 1067.75 1086.81 4623.24 3249.44 S 1101.98 4691.53 3320.93 S 1117.04 4760.34 3391.76 S 1132.76 4829.31 3462.39 S 1148.74 4898.27 3533.13 S 1164.22 4967.03 3604.20 S 1179.10 5035.16 3675.86 S 1194.04 5102.69 3747.98 S 1209.43 5169.65 3820.65 S 1224.79 5236.53 3893.37 S 1240.26 5304.52 3964.69 S 1257.30 5373.04 4035.17 S 1275.67 5441.69 4106.19 S 1291.18 5510.51 4177.72 S 1303.33 5578.85 4249.71S 1315.41 5648.54 4320.00 S 1329.58 Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°/100ft) W 5985659.93 N 497233.59 E W 5985591.99 N 497211.33 E W 5985522.98 N 497188.84E W 5985453.42 N 497166.20 E W 5985382.95 N 497147.12 E W 5985311.36 N 497131.93 E W 5985239.87 N 497116.86 E W 5985169.05 N 497101.12 E W 5985098.42 N 497085.13 E W 5985027.69 N 497069.63 E W 5984956.62 N 497054.73 E W 5984884.96 N 497039.77 E W 5984812.84 N 497024.37 E W 5984740.18 N 497008.99 E W 5984667.47 N 496993.50 E W 5984596.15 N 496976.44E W 5984525.67 N 496958.06 E W 5984454.66 N 496942.53 E W 5984383.13 N 496930.36 E W 5984311.14 N 496918.27 E W 5984240.86 N 496904.08 E Page 4 of 6 0.168 0.722 1.115 0.200 4.091 0.557 0.565 0.679 0.277 0.446 0.630 0.562 0.439 0.527 0.489 2.236 0.526 3.332 0.741 0.554 3.386 North Slope, Alaska Kuparuk 3G Vertical Section Comment 2358.90 2413.14 2468.12 2523.53 2576.35 2626.44 2676.36 2726.51 2776.78 2826.68 2876.23 2926.16 2976.69 3027.49 3078.4O 3129.93 3182.17 3232.24 3279.70 3327.34 3375.89 Tie on point DrillQuest 2.00.08.005 Kuparuk RiVer Unit MeaSured Sub-Sea Depth Incl. Azim. Depth (ft) (ft) 3G-19A 7511.00 44.710 192.980 5577.40 7582.55 43.900 216.580 5628.96 7679.98 52.300 248.650 5694.91 7747.93 71.810 257.500 5726.65 7777.91 76.970 260.930 5734.71 7875.22 72.860 259.890 5760.03 7972.22 64.140 247.950 5795.66 8068.81 65.440 245.910 5836.80 8165.69 65.730 245.060 5876.85 8246.42 65.830 246.960 5909.97 8301.00 65.830 246.960 5932.32 Sperry-Sun Drilling Services Survey Report for 3G-19 Your Ref: API501032013601 Job No, AKIVIMl1099, Surveyed: 17 June, 2001 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 5660.95 4331.94 S 1332.34W 5984228.91 N 496901.31 E 5712.51 4376.70 S 1352.92W 5984184.16 N 496880.73 E 5778.46 4418.53 S 1409.87W 5984142.35 N 496823.77 E 5810.20 4435.49 S 1467.06W 5984125.40 N 496766.58 E 5818.26 4440.88 S 1495.41W 5984120.01 N 496738.22 E 5843.58 4456.52 S 1588.03W 5984104.39 N 496645.60 E 5879.21 4481.17 S 1674.55W 5984079.77 N 496559.08 E 5920.35 4515.41S 1754.94W 5984045.54 N 496478.68 E 5960.40 4552.02 $ 1835.20W 5984008.96 N 496398.41 E 5993.52 4581.95 S 1902.46W 5983979.04 N 496331.14 E 6015.87 4601.44S 1948.28W 5983959.56 N 496285.31 E All data is in Feet (US) unless Otherwise stat[ed. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northin~s and Eastings are relative to Well. / Magnetic Declination at Surface is 25.948° (~ 3-Jun-01) The Dogleg Severity is in Degrees per 100 f~et (US). Vertical Section is from Well and calculated .~long an Azimuth of 238.786° (True). Based upon Minimum Curvature type calcul~tions, at a Measured Depth of 8301.00ft., The Bottom Hole Displacement is 4996.90ft. in the Direction of 202.948° (True). Dogleg Rate ("/'~OOft) 0.743 22.982 25.765 30.892 20.434 4.348 14.545 2.337 0.853 2.150 0.000 North Slope, Alaska Kuparuk 3G Vertical Section Comment 3384.44 Window point MWD Magnetic 3425.23 3495.61 3553.31 3580.35 3667.67 3754.44 3840.94 3928.55 4001.59 4050.88 Projected TD 18 July, 2001 - 4:07 i Page 5 of 6 DrillQuest 2,00.08,005 Kuparuk River Unit Comments Measured Depth (ft) 7493.55 5648.54 7511.00 5660.95 8301.00 6015.87 Survey tool program for 3G-19A From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 7511.00 5660.95 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 4320.00 S' 4331.94 S 4601.44 S To Measured Ver lical Depth De )th (ft) (~t) 7511.00 5660.95 8301.00 6015.87 f8 July, 2001 - 4:07 Sperry-Sun Drilling Services Survey Report for 3G-19 Your Ref: API501032013601 Job No. AKMM11099, Surveyed: 17 June, 2001 Comment 1329.58W Tie on point 1332.34W Window point 1948.28W Projected TD Survey Tool Description Tolerable Gyro (3G-19) MWD Magnetic (3G-19A) Page 6 of 6 North Slope, Alaska Kuparuk 3G DrillQues t 2. 00. 08.005 LOCATED IN THE APPENDIX UI WFL UI IPR LOG i~I*CALIPER SURVEY UI VOLAN [~ CURVE DATA [21 STRATIGRAPHIC HIGH RESOLUTION DIPMETER UI OTHER: ALASKA OIL AND GAS CONSERVATION COM~HSSION TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 James Trantham Drilling Engineering Supervisor Phillips Alaska, Inc. PO Box 100360 Anchorage AK 99510 Re: Kupamk River Unit 3G-19A Phillips Alaska, Inc. Permit No: 201-106 Sur Loc: 2538' FNL, 145' FEL, SEC. 23, T12N, R8E, UM Btmhole Loc. 1846' FNL, 2044' FEL, SEC 26, T12N, R8N, UM Dear Mr. Trantham: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application Kupamk River Unit 3G- 19A.. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Cammy Chair BY ORDER OF THE COMMISSION DATED this (~ day of June, 2001 jjc/Enclosures CC: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 la. Type ot work: Drill r'~ Redrill [~ lb. Type of well. Exploratory D StratigraphicTes, [--] Development Oil r'~ Re-entry B Deepen D Service D Development Gas D Single Zone r~ Multiple Zone 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool Phillips Alaska, Inc. RKB 90 feet 3. Address 6. Properly Designation Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0360 AD L 25548 ALK 2662 Kuparuk River Pool 4. Location o! well at sudace 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) 2538' FNL, 145' FEL, Sec. 23, T12N, R8E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 1761' FNL, 1762' FEL, Sec. 26, T12N, R8E, UM 3G-19A #59-52-180 At total depth 9. Approximate spud date Amount 1846' FNL, 2044' FEL, Sec. 26, T12N, R8E, UM June 11,2001 $200,000 12. Distance to nearest property line I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 1761' @ Targ~ feetI 3G-18 1321' @ 7520' feet 2560 8250' MD / 6007' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 7506 MD Maximum hole angle 67° Maximum surface 3167 psig At total depth (TVD) 3930 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Len~h MD TVD MD TVD /include stage data) 6.125" 4.5" 12.6# L-80 NSCT 895' 7355' 5554' 8250' 6007' 30 bbls Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured 8200' feet Plugs (measured) true vertical 6143' feet Effective Depth: measured 8114' feet Junk (measured) None true vertical 6083' feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 80' 16" 216 sx AS I 115' 115' Surface 3842' 9.625" 845 sx AS III & 545 sx Class G 3879' 3146' Production 8165' 7" 485 sx Class G & 200 sx Class G Tail 8200' 6143' Perforation depth: measured Current Perforations to be Abandoned ~'.; ~-.,,;:'I~! Ii 20. Attachments Filing fee [~] Property Plat D BoP Sketch D Diverter Sketch [~ Drilling program [~] Drilling f, uid program B Time vs depth plot DRefraction analysis D Seabed report D 20 AAC 25.050 requirements 21. I hereby c ?rtify that the foregoing is true and correct to the best of my knowledg~ Questions? Brian Noel265-697(. Signed ~.~~~~.~.~ Title:Dri#in~£n~inoorin~Suporvisor Date /J ~..el ~,~ amos Trantham Preoared by Sharon ~llsuo-Dral¢E Commission Use Onl) Permit Numbe~/,,../~)4 I APl number J Appr°v~7~/~ ISee c°ver letter 50- [~Y~es- "~'-~/',,~,'""'0/ / Ifor other requirements Cond. onsofspprova Samp.esrequ ... No Uud ogr qu reV'--.' I--I Yes No r'l .o Yes D Hydrogen sulfide measu res Required working pressure for BOPE U~M; D 3M; D 5M; D 10M:D D"--¥-- ~~"' Other:0riginal Signed Byv 0echsliby order of Approved by Camm_ Commissioner the commission Date ORIGINAL Form 10-401 Rev. 12/1/85 · Submit in triplicate .,,,,. ~.' 'ication for Permit to Drill, Well 3G-19A Revision No.O Saved: l-Jun-01 Permit It- Kuparuk Well 3G-19A App/icat/on for Perm/t to Dr~l~ Document MaxWell Ma×i~iz~ Well Value Table of Contents ! 1 1 g 1 Si 1 Sm Sm 10. 11. 12. 13. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (f) ........................................................................................................ 2 Location Summary ................................................................................................... 2 Requirements of 20 AAC 25. 005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25. 050(b) ........................................................................................................ 2 Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ................................................................................................... 3 Drilling Hazards Information ................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 3 Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25. 005 (c)(5) .................................................................................................. 3 Casing and Cementing Program ............................................................................. 4 Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 4 Diverter System Information ................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 4 Drilling Fluid Program ............................................................................................. 4 Requirements of 20 AAC 25.005(c)(8) ................................................................................................... 4 Abnormally Pressured Formation Information ...................................................... 5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 Seismic Analysis ...................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 5 Seabed Condition Analysis .......................... · .............................................. 5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 5 Evidence of Bonding ................................................................................................ 5 Requirements of 20 AAC 25. 005 (c)(12) ................................................................................................ 5 Proposed Drilling Program ...................................................................................... 5 3G- 19A PERMIT I T. DOC Page I of 6 0 ~it/~ i i,V~..~ L Printed:l-Jun-01 14. 15. ,~' "~.ation for Permit to Drill, Well 3G-19A Revision No.0 Saved: l-Jun-01 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 5 Discussion of Mud and Cuffings Disposal and Annular Disposal ....................... 6 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 6 Attachments ............................................................................................................. 6 Attachment I Directional Plan ................................................................................................................ 6 Attachment 2 Well Schematic .............................................................................................. 6 i i Well Name Requirements of 20 AAC 25. 005 (f) Each we//must be identified by a unique name des/~gnated by the operator and a unique API number assigned by the co/n/n/ss/on under 20 AAC 23-. O,tO(b). For a well with multiple well branctzes, each branct7 must similarly be/dent/f/ed by a unique name and API number by adding a .~zffix to the name des~inated for the welt by' the operator and to the number ass~igned to the well by the comm/sL~on, The well for which this Application is submitted will be designated as 3G-19A. Location Summary Requirements of 20 AAC 25.005(c)(2) An application fbr a Permit to Dr/It must be accompar#ed by each of the fbi/owing/terns, except for an/tern ~/ready on file with the commission and identified in the application; (2) a p/at identifying the property and the propef~Y owners and showing (A)the coordinates of the proposed/oo~ti~xz of ~he well at the surface, at the top of each ot%jecb've formati~x~, and at total depth, m~renced to governmental sect/on Iines~ (B) the coordinates of the proposed location of the we// at the surface, ret~renced to the s'ta~ plane coordinatP syscom for this state as maintained by the National Geodetic ,5~ey in ~he National Oceanic and A~mospheric Administration; (C) the proposed d~th of the we// at lhe top of eacf~ objective fbrmation and at total depth/ Location at Surface 2538' FNL~ 145' FEL~ NGS Coordinates Northings: 5,988,560.5 Eastings: 498,234.7 Sec 23~ T12N~ R8E~ UM I RKB Elevation I Pad E/e va t/on ~ 83.3' AMSL 53.0' AIVISL Location at Top of 1761' FNL, 1762' FEL, Sec 26, T12N, R8E, UM Productive Interval (Kuparuk "A3" Sand) A/ES Coordinates Measured Depth~ RKB: 7884' North/ngs: 5,984,063 East/rigs: 496,662 Total Vert/ca/Depth~ RKB: 5864' Total Vertical Depth~ SS: 5781' Location at Total Depth 11846' FNL~ 2044' FEL Sec 26~ T12N~ R8E~ UM NGS Coordinates Measured Depth~ RKB: 8250' Northings: 5,983,976 Eastings: 496,337 Total Vertical Depth~ RKB: 6007' Total Vertical Depth~ $5: 5924' and (D) other infotm,Ttion required by 20 AAC 25,050(b); Requirements of 20 AAC 25.050(b) Ifa well is to be intentionally deviated, the application fi~r a Permit to Dr///(F-?xm 10~401) must (1) include a p/at) dra~n to a suitable sca/e, showi/tg ~he path of the proposed we#bom, #~d~ing all adjacent wellbores w/thin 200 feet of any potion of the proposed we/~' Please see Attachment 1' Directional Plan 3G- 19A PERMIT I T. DOC ORIG it'VAL Printed:l-Jun-01 f r-, "cation for Permit to Drill, Well 3G-19A Revision No.0 Saved: l-Jun-01 m and (2) for all wells within 200 feet of the proposed wellbore (A) list' the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by ceA'fled/nail; or (B) state that the app#cant /s the only affected owner. The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the fo/lowing item_$ except for an item a/ready on file with the comn?ission and ident/fied in the application: (3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; Please reference BOP schematics on file for Nordic 3. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An applicaEon for a Permit to Dr///must be accompanied by each of the fo/lowing items; except for an item already on tile w/th the con~n'Ession and identified in the application: (4) information on drilling hazards; including (A) the maximum downho/e pressure that may be encountered, criteria used to detem~ine it, and maximum potent/a/surfbce pressure based on a methane gradient; The expected reservoir pressure in the Kuparuk A3 sand for the 3G-19A wellbore replacement sidetrack is 3785 psi at 5865' tvd, 0.65 psi/ft or 12.4 ppg EMW (equivalent mud weight). This pressure was obtained from 3G-19 and matches offset pressure data for the Kuparuk sands. The maximum potential surface pressure (MPSP) while drilling the sidetrack is calculated using above reservoir pressure, a gas gradient of 0.11 psi/ft, and top of the A3 sand target at 5865' tvd: MPSP =(5865 ft)*(0.65 - 0.11 psi/fL) = 3167 psi (£) da&'~ on pot'ential gas zones; The well bore is not expected to penetrate any gas zones. Drilling operations on 3G pad have not encountered H2S but it is present in the produced fluids. The H2S concentrations (ppm) measured during August in the production stream for 3G-19 and the 3G drill site average are: 3G-19 3G drills/re average 1994 58 178 1995 190 174 1996 95 129 1997 125 142 2000 125 132 and (C) data concerning potent/a/causes of hole problems such as abnormally geo-press'ured strata, lost cY~cz//alion zones; and zone.z that have a propensity fbr different/a/sticking/ No significant drilling hazards anticipated. , Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25. 005 (c)(5) An application fo/' a Permit to Dr/Il must be ac~r)n?pan/ed by each of the t"ol/ow/ng /ten?s; except for an it~fl'~ a/ready on file w/th the commissYon and identified in the application: 3G- 19A PERMIT IT. DOC Page 3 of 6 ORIGINAL Printed:l-Jun-01 Sm , am '/cation for Permit to Drill, Well 3G-19A t Revision No.O Saved: 1-Jun-O1 (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(f); Perform F[-i- test to 13.2 ppg (expected ECD at window for 12.5 ppg GEM mud) in accordance with the Kuparuk LOT/FT1' procedure, that Phillips Alaska has on file with the Commission. Casing and Cementing Program Requirements of 20 AAC 25. 005(c)(6) An application for a Permit to Dr///must be accompanied by each of the fo/lowing/terns, except for an item a/ready on file with the commiss/bn a~Td identified/n the app//cat/on: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any s/otted i/nec, pre- perforated i/nec, or screen to be instal/ed; Casing and Cementing Program Hole Top Btm Csg/-I'bg Size Weight Length MD/TVD MD/TVD OD (in) (in) (Ib/ft) Grade Connection (ft) (ft) (ft) Cement Program 4-1/2 6-1/8 12.6 L-80 NSCT 895' 7355'/5554' 8250'/6007' 30 bbls Class G w/ 3-1/2 9.3 L-80 EUE 8rd 7355' 30 / 30 7355'/5554' additives· Mod · Cement volume sufficient to bring TOC 150' above liner top. Diverter System Information Requirements of 20 AAC 25. 005(c)(7) An application for a Permit to DH// must be accompanied by eac/7 of'the ~b//ow/n~ items; except/bt an item a/ready on fi/e commission and identified in the apptic~tion: (7) a di~qram and description of the divezter system as t~quir~d by 20 AAC 25.03~ un/ess ~is requirement is waived by the commL~sion under20 AAC N/A - Sidetrack out of 7" with BOP installed. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An app/ica~Fon £or a Permit to Drill m[z¢t' be accompanied by each of the fo#owing item~; except' for ar)/ten"/a/ready on l?/e w/th the cornmission and ~dentified in the application: (8) a drilling #uid program, including a diagrarn and description of'the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done with a freshwater GEIVl system having the following properties: hC////n~7 Dr////n~t Density (ppg) 12.5 12.5 Funne/Viscosity(sec) 45-60 45-60 Yie/d Point (cP) 20-25 20-25 P/astic Viscosity (ih/lO0 sf) 11- 25 11- 27 10 sec, Ge/(/b/lO0 sO 8-13 7-13 10 min. Ge/(/b/lO0 so 10-20 10-20 API F#trate (cc) < 6 < 6 pH 9-9.5 9-9.5 Sol~ds (%) 13-20 13-20 Diagram of Nordic 3 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 3G- 19A PERMIT I T. DOC Page 4 of 6 ORIGINAL Printed:l-Jun-01 ication for Permit to Drill, Well 3G-19A Revision No.0 Saved: 1-Jun-O1 gm Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Dr/Il must be accompanied by each of the fo#owing item.~, except for an item r/ready on file with the commi~ion and identified in the application: (9) for an exploratory or stratigrapt#c test well, a tabu/at/on setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Dr/Il must be accompanied by ~.,ac?~ of the fo/lowing items, except for an/tern a/ready on file with the cornmi~sion and identified in the application: (~ 0) fo/' an exploratory or ~tratigraphic test well, a ~eismic refraction or reflect/on analysis as required by 20 AAC 25. OdZ (a); N/A - Application is not for an exploratory or sitar/graphic test well. 11.Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) Art application thc a Permit to Dr/Il rnust be accompanied by each of the fo/lowing item~-, ezcept tbr an item a/ready on file with the c'ommL~'5ion and identified in the application: (dZ) fbr a we, Il drilled from an off~hore platfbrm, mobile bottom-tbunded structure, jack,up rig, or ftoatirLq dz#lirLq ves~el, an analys?s of'seabed conditions as required by 20 N/A - Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Dr///mu.~t' be accompanied by each of the fo/lowing item~~, except for' a/7 item ~ready on tile w/th th~~. comn?/:~.~iOn and/dent/fled in the application: (.t2) evidence showing ff'~at' the requirements ol: 2D AAC 25: 025' .(Bonding½have been met;' Evidence of bonding for Phillips Alaska, ]:nc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25. 005 (c)(13) An applic~tion tbr a Permit to Df#1 mu.~t be accompanied by each of'the fo/lowing items', except fbr an item a/ready on file w/Ih commission and iclentified in the application: The proposed drilling program is listed below. Please refer as well to Attachment 2, Well Schematic. 1. MIRU Nordic 3. Lay hard-line to tree. Pull BPV and VR plug. 2. Circulate well to seawater through tubing cut at 7556' MD. Verify well is dead. 3. Set BPV. ND tree. NU and test BOPE. 4. Screw in landing joint. Pull tubing hanger to rig floor. POOH laying down all tubing and jewelry. 5. PU 7" Casing Scraper on DP and run through Bridge Plug seLLing depth. 6. RU E-line Unit. RIH and set Bridge Plug at 7534' MD. Test bridge plug/7" casing to 3000 psi. 7. PU Baker 7" Window Master Bottom Trip Whipstock, MWD, etc and RIH. Circulate well to 12.5 ppg milling fluid, orient and set whipstock w/MWD. Shear off whipstock bolt and mill window in 7" casing and 20' formation. Perform FTT test to 13.2 ppg (expected ECD at window for 12.5 ppg LSND mud). POOH and LD milling assembly. Note: If unable to obtain adequate FTT, squeeze window with cement, redrill and test again. 8. RIH w/6-1/8" bit, MWD / LWD, and steerable drilling assembly. Slide out window, kick-off and directionally drill to total depth as per directional plan. Short trip to window in casing. POOH and lay down drilling assembly. 9. Run 4-1/2" liner to TD w/150' of overlap above top of milled window. 10. Cement liner in place, set liner hanger and liner top packer, circulate out excess cement and POOH laying down 3-1/2" DP. 11. Pressure test casing and liner lap to 3000 psi for 30 min (Chart Test for State). 3G- 19A PERMIT I T. DOC ORIGINAL PrintePda"gle'ju5n°'fo~ 14. 15. ..,~' /)'" '~cation for Permit to Drill, Well 3G-19A ~, ~ Revision No.0 Saved: l-Jun-01 12. RIH w/3-1/2" completion assembly and sting into Seal Bore Extension below liner top packer. Space out. Displace well to seawater and land tubing. Test tubing and annulus to 3000 psi. 13. ND BOPE. NU and test tree. Freeze protect well with diesel. RDMO Nordic 3. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the fo/lowing items, except for an item a/ready on file with the commission and identified in the application: (Z 4) a genera/descn'ption of how the operator plans to dispose of dffl/ing mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation fi] the we//,/ Waste fluids generated while drilling the sidetrack will be hauled to a KRU Class T! disposal well. All cuttings generated will be hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. Phillips Alaska does not intend to request authorization for annular disposal operations in this well. Attachments Attachment I Directional Plan Attachment 2 Well Schematic. 3G- 19A PERMIT IT. DOC Page 6 of 6 ORIGINAL N Refe~'ence is True Nm-ih 4700 PhiBips Alaska, Inc. Nort~ $~ope, A~aska Kupamk River U~it 3G Pad 3®~ 9 (wp0~) 8250 00' MD 600715' TVD [ [ 7 T [ Easfings 1750 Scale: linch = 100ft J Current We~ [ We~ 3GI 9A (wpO!) Hoi~xontal Coordir~ate~: Phillips Alaska, lnc, North Slope, Alaska Kuparuk River Unit 3G Pad 3®-t9 (wp01 } 5750 A Halliburton Company Scale; 1inch = 100fi 3750 T I F T 3850 3950 4050 Sectio¢ Azm( h: 238800" (-l~ue No/th} 4150 North Slope, Kuparuk 3G, Slot 3G~19A?:-WP 3G- 19A WP~i-..~,.3G-19 WPO 1 .Revised: 3~':May, 2001 POSAL REPORT .... :';;:::::. .................... 30 May, 2001 : . ... · .. ::~r:~: =========================== ' .... ~ i:"::' "'i ::~'":' "'" Surface Coordinates: 5988560.54 N, 498234.68 E (70° 22' 47.9249" N, 150° 00' 51.6708" W) ,:.,:::: :. ,: ::,:,:::::~. Surface Coordinates relative to Project H Reference: 988560.54 N, 1765.32 W (Grid) Surface Coordinates relative to Structure: 0.29 N, 490.34 W (True) Kelly Bushing: 83.30ft above Mean Sea Level Proposal Ref: pro9531 Sperry-Sun Drilling Services Proposal Report for 3G-19A WP - 3G-19 WP01 Revised: 30 May, 2001 Kuparuk River Unit Measured Depth Incl. (ft) 7505.70 44.676 Sub-Sea Vertical Local Coordinates Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) 193.006 5573.81 5657.11 4328.48 S 1331.55W 7533,70 45.904 198.659 5593.52 5676,82 7600.00 48.396 215.535 5638.78 5722.08 7700.00 56.197 237.530 5700.36 5783.66 7798.62 67.000 255.000 5747.48 5830.78 7800.00 67.000 7884.41 67.000 7900.00 67.000 7953.51 67.000 8000.00 67.000 8048.21 8089.16 8100.00 8158.26 8200.00 4347.61 S 1336.98 ~ 4390.51 S . !359.09W 4443.73 S :: .:" '14i'6.~'~ :: 4477.78S. '~'.. '.. 1495.52 W::': 255.000 5831.32 i':i': :: 4478:.~i~i..~ :::'~ 1'496.75 W 255.000 5864.30 ~;i;:! ! ::::. 4498.22 S 1571.80 W 5748.02 5781.00 .... . ========================= .. 255.000 5787.09;;;;;;;; 58~8.39 4501.93 S 1585.66 W 255.000 58.08~00 4514.68 S 1633.24 W 255.000 ::;;;,~ 5826¢il;~"~ ~;;;5909.46 4525.75 S 1674.58 W 67 58~$~:00 5928.30 4537.24 S 1717.44 W 67.000'i :. ,255.0~ ' ;' ..;~5861.00 5944.30 4547.00 S 1753.85 W 67.000 ;-.;;255.08~' 5865.24 5948.54 4549.58 S 1763.49 W .: . 67.000 :';25,8~eoo 5888.oo 5971.30 4563.46 s 1815.29 w 67.000 255.000 5904.31 5987.61 4573.40 S 1852.40 W 8250.00 67.000 255.000 5923.85 6007.15 4585.32 S 1896.86W All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 25.967° (22-May-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Whipstock Top and calculated along an Azimuth of 238.800° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8250.00ft., The Bottom Hole Displacement is 4962.18ft., in the Direction of 202.474° (True). Global Coordinates..::;: :': Dogleg Northings Eastings ' : Rate (ft) :: (°/100ft) 5984232.37 496902it 1 E 5984~13.25:N 496896.67 E 15.000 5984170~35 N 496874.55 E 19.000 5984117.15 N 496817.23 E 19.000 5984083.12 N 496738.10 E 19.000 5984082.79 N 496736.88 E 0.000 5984062.69 N 496661.82 E 0.000 5984058.98 N 496647.96 E 0.000 5984046.25 N 496600.37 E 0.000 5984035.18 N 496559.04 E 0.000 5984023.71N 496516.17 E 0.000 5984013.96 N 496479.76 E 0.000 5984011.38 N 496470.12 E 0.000 5983997.51 N 496418.31 E 0.000 5983987.57 N 496381.20 E 0.000 5983975.67 N 496336.74 E 0.000 Vertical Section 3381.23 3395.78 3436.92 3513.51 3598.82 3600.04 3674.66 3688.44 3735.74 3776.84 3819.45 3855.65 3865.23 3916.73 3953.63 3997.82 North Slope, Alaska Kuparuk 3G Comment Top of Whipstock, Begin Dir @ 15.0°/100ft (TF @ 75° R): 7505.70ft MD, 5657.1 lft TVD 7" Casing Window Increase in Dir Rate @ 19.0°/10' 7533.70ft MD, 5676.82ft TVD End Dir, Start Sail @ 67.0° · 7798.62ft MD, 5830,78ft TVD Target: 50' Radius @ 5781' SSTVD, Centered @ X=496619'& Y=5984061 Top A3 Top A2 Base A2 Top A1 Miluveach Total Depth · 8250.00ft MD, 60(' TVD 4-1/2" Liner ,,~,~,,~. 30 May, 2001 - 22:40 Page 2 of 4 DrillQuest 2.00.09.001 Sperry-Sun Drilling Services Proposal Report for 3G-19A WP - 3G-19 WP01 Revised: 30 May, 2001 Kuparuk River Unit Comments Measured Depth TVD (ft) (ft) 7505.70 5657.11 7533.70 5676.82 7798.62 5830.78 7884.41 5864.30 8250,00 6007.15 Formation Tops Formati on Plane (Below Well Origin) Sub-Sea (ft) 5781.00 5808.00 5845.00 5861.00 5888.00 Station Coordinates Northings Eastings (ft) 4328.48 S 1331.55W 4347.61 S 1336.98W 4477.78 S 1495.52W 4498.22 S 1571.80W 4585.32 S 1896.86W Top of Whipstock, Begin Di~o@;"[5.0°)~Oof~i(TF@ 75;:R): 7505.70ft MD, 5657.1 lft TVD Increase in Dir Rate @. !'9.0/100fi: 753§:~0ft MD, 5676.82ft TVD End Dir Start Sail-@ 6710°: 779~!~2fi- MD, 5830.78ft TVD Target: ~0' RadiU:~'::~:'::'5~!' SsTvDi: C~tered @ X=496619' & Y=5984061' Total DeptA !~50,00ftlMD, 6007.15ft TVD Eastings Formation Name (ft) 1571.80W TopA3 1633.24W TopA2 1717.44 W Base A2 1753.85 W Top A1 1815.29 W Miluveach P r o::f il e ;:.';!;;~.e n e:i~.t r:*~'~'a:'{ i o n P o i n t Measured ::..~i.. :.v~.rtical :: ~i~s~.:,a~:: Dip Dip Dir. Depth :.:..ii:~.i~;iD~h D~th Northings Deg. Deg. (fi) (~):!~?" · :,.:...(fi) (fi) 0.000 359.986 ,..~.i~ .~'~;~ ::". :i :: :i5864.30 5781.00 4498.22 S 0.000 '359:.986 7953i5.17'~!I'I * 5891.30 5808.00 4514.68 S 0 000;:~.!':: 359.9'86'.:.," i.:'! :;¢04~i!~¥ 5928.30 5845.00 4537.24 S 0.000 .359.986;...i;: ::.; 8089.16 5944.30 5861.00 4547.00 S 0.000 ':"359.986.::.'/ 8158.26 5971.30 5888.00 4563.46 S · :. :..". .. North Slope, Alaska Kuparuk 3G ~-" 30 May, 2001 - 22:40 Page 3 of 4 DrillQuest 2.00.09.001 Sperry-Sun Drilling Services Proposal Report for 3G-19A WP - 3G-19 WP01 Revised: 30 May, 2001 Kuparuk River Unit Casing details From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) <Surface> <Surface> 7505.70 5657.11 7505.70 5657.11 8250.00 6007.15 Targets associated with this wellpath Target Name T1 (3G-19A) Casing Detail 7" Casing Window 4-1/2" Liner Mean Sea Level/Global Coordinates: Geographical Coordinates: Target Radius: Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) 5864.30 4499.92 S 1614.62 W 5781.00 5984061.00 N 496619.00 E 70° 22' 03.6626" N 150° 01' 38.9022" W 50.00ft North Slope, Alaska Kuparuk 3G Target Shape Circle Target Type Current Target 30 May, 2001 - 22:40 Page 4 of 4 DrillQuest 2.00.09.001 WEI_L DETAILS Na~r~ +NLS +Fd-WNorthing Ea.~.~g La~udu Lqng/mde Slot 3(i-19 0.51 -4~J.M 5988560.54 498 Z~.6,8 ?0:2T47.925N I ?d:OCt51_671W ANTI-COLLISION SETtiNGS Interpolation Method'3,lD Interval: 20.00 Deplh Range Frown: 7500.00 To: 8250,00 Maximum Range: 5000.00 Reference: Plan: 3G-198 WP01 Panini WellFatlc 3G- 19 T'e on MD: 7505.70 I1%: Ref. ~tu~ ~-I~ ~ 83..~ 13G-191 z3.3~1 V.S~n (1~ Ofi~q 202.~ O.~ O.m O.~ SURVI~' I'ROGR,\M Ik'l,lh FI,! I)..'1~0, 'r,, Su,-.'~)fl'L,n 7505.7O 82~1J~} I'tml~:d; ~(;. 1~, WIq)l VI MWI)-Ii-R From Col{mrTo MD 0 7500 7500 75511 75511 7600 76(X) 7650 7650 7700 7700 7750 7750 780O 0 7800 7850 --35 785¢) 7900 From Colour To MD 7900 7950 795¢) 8000 0 7500 30 '' . ' _.~ ......... 30 .......... ~ 8(g10 8050 751.10 7550 · ............ ,. ~ 8050 8100 7550 ............... 7600 ~"'"" '"'-.~8100 8150 7600 7650 //" ' '" 'x, , 8 - - - 8250 7650 .......7700 /~/ "',, '~50 - - ' 82011 0 3 ~ '~[;'] ] -:' ' ~'2 '"'- ~ 7700 7750 63 -- 3~- ' .... ~~ 7750 7800 ~-~o ..... / - .... ..-. ~ 7800 7850 20 . ~/ . · ~- -20 ....... ~ .... - ' . ' ,, -'.. '.. '. ~'"~qnx7850 7900 ....... ""% O0 // "' "..~~--'~["300---~' ' . .'.. '~ 7950 8000 ~/ ' ~-~ . { . ..~-~'-' '% 8000 8o5o '-'/.' . / .' ~/ -' .. [ . -'"'-.. '. 'X8050 8100 / ,, ',, / · // '. ' .. -' { ' - . .. '--~ -- · ~oo 8~5o -4o.. ',,\ / -~ -' . [ ~ .. ~ -- '% ' 81Xo 8200 10 .- .. / . . .. / . ..- . . '-. \ \ . -.. .' __ --0 - ~"~~o.~:' [ i 190 ,j :... -.? .? o // -.-.. /--... /~q~-.~~\ . \ ,,'" ~,6 10 ;~ . ' ": Iff'~- , ~ - { : ' ' ! ' i '--'" ; : i" : : [ ' : ' i - ' ' "k,i ' %, / " 3G-19 ~.701/ L~ : i - i _ ' ' [~~~ ! } : 190 y ," t.-. i-.'.'-.: i" .- ',, '__ ' ' "/ '" :'/ """"-,. ' i · ~. " ' '~ .,.w~.' : - i - ' - i - ' .... -~' ,,' I,°° , - 2405 x . '"~ ' I ' ' ~.~ ' · -" .)~ '/i20 I ~0O X'-. % -"'~-~. :' ' -/-'~/ -~ ~ .-.- - ..I .... -- -~..( . / 63 18If°'~ Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [20fl/in] Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [200ft/in] Pkm: 3G-198 WPOI [3G-19DG-I¢a) Created By: [)ave Egedahl Da~e: L5f30/2001 Check~: _ Date: Re'.Sev. x~ci: Date: Approved: Dale: SE('T1ON I )l rI-AII.Y. S,x MI) lac ;,/i TVI> +N/-S .IT.W IH~ '[l:~.c V,cc I 7~5.70 ~.70193.WJ ~57.11 4.t28.39 2 7533.7( 45.93 1~.25~7fi 81 -43.17.47 · 1337.0~ If{l) 75.1~ 4528.25 3 ~.3g 67.~LqS.(~} 5829.24 ~76.1~-1495 4 7~.1067.~1 255.{~ 5~ -~t)7.~ -1574.g7 [1(~} (till 47~7.81 5 ~50.ffi 67.UA 255.1X1 ~g~.4945~1.15 .1 ~)S-I.I OJll 0.111 41~170 (3G-191 Sperry-Sun Anticollision Report Company: Phillips Alaska Inc. Date: 5/30/2001 Time: 23:05:58 Page: ! Field: Kuparuk River Unit Reference Site: Kuparuk 3G Pad Co-ordinate(NE) Reference: Well: 3G-19. True North Reference Well: 3G-19 Vertical (TVD) Reference: 3G-19a @ 83.30 (3G-19) 83.3 ReferenceWellpath: 3G-19a Db: Sybase NO GLOBAL SCAN: Using tL~er defined selection & scan criteria Reference: Principal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 20.00 ft Error Model: ISCWSA Ellipse Depth Range: 7500.00 to 8250.00 ft Scan Method: Trav Cylinder North Maximum Raditts: 5000.00 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 5/30/2001 Validated: No Version: 8 Planned From To Survey Toolcode Tool Name ft ft 93.30 7505.70 3G-19 (0) GYD-CT-CMS Gyrodata cont.casing m/s 7505.70 8250.00 Planned: 3G-19a WP01 V1 MWD+IFR MWD + IFR correction Casing I'oinLs MD TVD Diameter Hole Size Name ft ft in in 8395.00 0.00 4.500 6.125 41/2" Liner Summary < ......................Offset Wellpath ...................... > Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft Kuparuk 3G Pad 3G-02 3G-02 Vl Out of range Kuparuk 3G Pad 3G-03 3G-03 Vl Out of range Kuparuk3G Pad 3G-04 3G-04 V1 7500.00 7700.00 2399.01 201.53 2197,99 Pass: Major Risk Kuparuk 3G Pad 3G-05 3G-05 V1 Out of range Kuparuk 3G Pad 3G-06 3G-06 V1 Out of range Kuparuk 3G Pad 3G-07 3G-07 V2 Out of range Kuparuk 3G Pad 3G-07A 3G-07A V1 Out of range Kuparuk 3G Pad 3G-08 3G-08 V1 Out of range Kuparuk 3G Pad 3G-09 3G-09 V1 Out of range Kuparuk 3G Pad 3G-10 3G-10 V1 Out of range Kuparuk 3G Pad 3G-11 3G-11 V1 Out of range Kuparuk 3G Pad 3G-12 3G-12 V1 Out of range Kuparuk 3G Pad 3G-13 3G-13 V1 Out of range Kuparuk 3G Pad 3G-14 3G-14 V1 Out of range Kuparuk 3G Pad 3G-14 3G-14A V1 Out of range Kuparuk 3G Pad 3G-15 3G-15 V1 Out of range Kuparuk3G Pad 3G~16 3G-16 V1 7502.63 8100.00 3380.65 213.87 3178.88 Pass: Major Risk Kuparuk 3G. Pad 3Gr!7 3G-17 Vl QUt of.range Kuparuk3GPad: !3G-18: 3G'i8Vi 7505170 7520.00 1320.83 214.45 1174.43: Pass: Major Risk Kuparuk 3G Pad 3GL19 3G-19 V1 7500.00 7500,00 0.01 0144 -0.43 FAIL: No Errors Kuparuk3G Pad 3G-20 3G-20 V1 8240.57 7160.00 1615.96 167.80 1487.50 Pass: Major Risk Kuparuk 3G Pad 3G-21 3G-21 V1 Out of range Kuparuk 3G Pad 3G-21 3G-2 lA V2 Out of range Kuparuk 3G Pad 3G-22 3G-22 V1 Out of range Kuparuk 3G Pad 3G-23 3G-23 V1 Out of range Kuparuk 3G Pad 3G-24 3G-24 V1 Out of range Kuparuk 3G Pad 3G-25 3G-25 V2 Out of range ORIGINAL Kuparuk River Unit 3G-19A (wp01) TVD TVD MD Inc Azim. N/S E/W Y X DLS V.S. Comment (SS) (RKB) (ft) (Deg) (Deg) (ft) (ft) , (ft) (ft) (ft) (ft) (°/100ft! (ft) ~ 7505,70 7533.70 7798,62 7884.41 7953.5't 8©.48:2~ 44.68 193;01 5573.81 5657.11 4328,48 S1331.55W 5984232.37 N 496902.11E 451.90 198.:66 5593.52 5676~82 4347.61S 1336.98W 5984213.25 N 496896,67 E 67.00 255;00 5747.48 5830.78 4477.78S 1495.52W 5984083.12 N 496738.10 E 67:00 255,00 5781,00 5864,30 4498,22S 1571,80W 5984062.69 N 496661,82 E 67,0~ 255,00 580&00 589'1:3©~ 4,5~4~68S '~633~,24W 598404&25N496600~37~ 67,00 25,5,00 5845,00 592&30 453'?~24. S 'I717,44W 5984023.7~ N 4965~6,'17 ~ :~6 o~.~., ~ ~'.~ 67,00 ~..;~,.,,:,~, 58'8't ,00,,~4aa,,., ,~,:t, ~.30.., ,~. x: x"r.,,.,,:..~, ,., r~n~,~ ,,<a ...~. o3,6a \ F 5984,r}'~ ,,., ~ ,~, N 496479,76 B '"'"=':' '~ ='"=' '='' ~ """" '"=''"'/ '":'~'~'~ ~ ' ..... ' ..... ";'"? 'J !': ;'. ?.}i' .'? ' ~'.,.',' ~ ,..' ...... · ,,.;... ;... ., . .... ,.~ ...... . .................... ':..;,..; .......... :}':.:,..'.., '.: '."... ........ : ..,.,: ...... ...,.......'...: ............................ ::,:...-.. .... · ....................... :...~.., ...... · .................... 8250.00 67.00 255.00 5923.85 6007.15 4585.32 S 1896.86 W 5983975.67 N 496336.74 E 0.00 3381.23 Top of WhiPstock 15.00 3395.78 Increase DLS 19.00 3598.82 End Dir, Start Sail 0,00 3674,66 Target /T'op A3 0~00 38t9,,45 ::3a~e A2 ,' ..... :,. :;.' ,' :' .' .,. . ~'..~ ~' ',,; :'.C a,.. .......................... 0.00 3997.~2 Total Depth KRU 3G-19A Pr uucer Proposed Completion PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY H. 3-1/2" 5M WKM Gen IV tubing hanger with 3-1/2" L-80 EUE 8rd Mod pin down. G. 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing to surface. F. 3-1/2" Camco 'DS' landing nipple with 2.812" ID No-Go profile set at +/-500' MD. 9-5/8" 36# J-55 @ 3879' E. 3-1/2" 9.3# L-80 EUE 8rd Mod tubing to 'DS' landing nipple w/ 3-1/2" x 1" Camco 'KBUG' mandrels w/DV's, spaced out as follows: GLM# ME) TVD Liner top and Whipstock Depth's are based on Original RKB to the hanger from the 7" Csg Detail. These depths need to be converted to Nordic RKB. 1 TBD TBD 2 TBD TBD 3 TBD TBD 4 TBD TBD Note: Each GLM should have 6' L-80 handling pups installed on top and bottom. D. 3-1/2" x 1-1/2" Camco 'MMG' Mandrel at +/-7320' MD w/DCR Dump Kill Valve (3000 psi casing to tubing shear), 6" L-80 handling pups installed on top and bottom of mandrel. C. 1 joint 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing B. 3-1/2" Camco 'DS' landing nipple with 2.75" ID and No-Go profile 4-1/2" liner top @ +/-7365' MD Top of Whipstock & KOP at +/-7515' MD Window in 7" A. Baker 3-1/2" 'GBH-22' Tubing Seal Assembly w/10' of seals and special Iocator to locate in liner tie back sleeve. Locator 5.125" OD, seals 4.0" OD. 6' L-80 Handling Pup Joint installed. Liner Top Baker 4-1/2" x 7" 'C-2 ZXP' Liner Top Isolation Packer and 6' setting sleeve w/5" BTC Box Down. Baker 4-1/2" × 7" 'HMC' Hydraulic Liner Hanger w/5" BTC Pin x Pin. Baker '80-40' SBE (12' Length w/4" ID seal bore). 4-1/2" NSCT pin down. Solid Liner 4-1/2" 12.6# L-80 NSCT from Liner Hanger to Landing Collar. Bridge Plug at +/-7534' MD Abandoned Peds C/B-Sand Perfs A-Sand Peds 7"26# J-55 @ 8200' Cement Fill Future Perfs 4-1/2" NSCT Baker Landing Collar. 1 joint 4-1/2" L-80 NSCT tubing. 4-1/2" NSCT Baker Float Collar. 2 joints 4-1/2" L-80 NSCT tubing. 4-1/2" NSCT Baker Float Shoe. TD @ +/-8250' BDN 5/31/01 ORIGINAL PHILLIS,. S Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 June 1,2001 Alaska Oil and Gas Conservation Commission 333 West 7'h Avenue, Suite 100 Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill: KRU 3G-19A Surface Location: Target Location: Bottom Hole Location: Dear Sirs: 2538' FNL, 145' FEL, Sec. 23, T12N, R8E 1761' FNL, 1762' FEL, Sec. 26, T12N, R8E 1846' FNL, 2044' FEL, Sec. 22, T12N, R8E6 Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore development well KRU 3G-19A. ,, The well will be drilled and completed using Nordic 3. Please utilize documents on file for this rig. Subject to AOGCC approval, fluids generated from drilling the sidetrack will be pumped down an approved KRU Class II disposal well and all drill solids will be hauled to an approved Prudhoe Bay facility for grind and inject disposal. The following people are the designated contacts for reporting responsibilities to the Commission: A) Completion Report Sharon AIIsup-Drake, Drilling Technologist (20 AAC 25.070) 263-4612 B) Geologic Data and Logs (20 AAC 25.071) Mark Scheihing, Geologist 265-6072 If you have any questions or require further information, please contact Brian Noel at (907) 265-6979 or James Trantham at (907) 265-6434. Sincerely, James Trantham Drilling Engineering Supervisor American Express® Cash Ad~nce Draft 138 Issued by Integrated Payment System, Inc. Englewood, Colorado NOT VALID FOR AMOUNT OVER, $ 1000 Colorndo · ~ '//'k._ "'__" PERIOD ENDING ~( / ! ': &D ;~ ~.DD t,D[3,: 5 5 ,,,D ~. ? c;DDD c; %P,,'D ~, ~ WELL PERMIT CHECKLIST FIELD & POOL ~/~)/'~ ADMINISTRATION 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. AR ATE 12. WELL NAM~'-/'~,'~ PROGRAM: exp dev v/ redrll ~ serv wellbore seg ann. disposal para req Permit fee attached ....................... Lease number appropriate ................... Unique well name and number .................. Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... Conductor string provided ................... 15. Surface casing protects all known USDWs... ........ 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... GEOL AREA __~?~ UNIT# ~ / //'~,,/~ ('~ ON/OFF SHORE N N N ~ ~ ~ 24. Drilling fluid program schematic & equip list adequate 25. BOPEs, d° they meet regulation ................ 26. BOPE press rating appropriate; test to .z~~ 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. . Is presence of H2S gas probable ................. 30. Permit can be issued w/o hydrogen sulfide measures .... 31. ~Da!a p. resen!ed, on.po, te,n, tial overpressure zones ....... 32. ~e~smlc analys~s or snallow gas zones ............. AP R .DATE , 33. Seabed condition survey (if off-shore) .... ....... ~ .~/~,,~/"~/ 34. Contact name/phone for weekly progress reports [explj~,~ory only] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; .... : . . Y N APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well'used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAc 25.252 or 20 AAC 25.412. Y N GEOLO, J;~Y: ENGINEERING: UIC/Annular COMMISSION: ,.. TEM /,,I~ ~/] ('~ JMH ~ ~.~. Commentsllnstructions: 0 Z 0 c:\msoffice\wordian\diana\checklist (rev. 11/01fl00) Well Histo.ry 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 APPENDIXi No'special'effort has been made to chronologically organize this category of information. · ,, · ,o Memory Multi-Finger Caliper Log Results Summary Company: PHILLIPS Alaska Inc. Well: 3G-19A Log Date: September 2, 2002 Field: Kuparuk Log No.: 4792 State: Alaska Run No.: 1 APl No.: 50-103-20136-01 Pipe1 Desc.: 3.5" 9.3 lb. L-80 Top Log Intvll.: 7,309 Ft. (MD) Pipe1 Use: Tubing Bot. Log Intvll.: 7,446 Ft. (MD) Pipe2 Desc.: 4.5" 12.6 lb. L-80 Top Log Intvll.: 7,447 Ft. (MD) Pipe2 Use: Liner Bot. Log Intvll.: 8,198 Ft. (MD) Inspection Type: Corrosive & Mechanical Damage Inspection COMMENTS: This log was run to assess the condition of the tubing and liner with respect to corrosive and mechanical damages. The caliper recordings indicate that the interval g,f 3.5" tubing logged is in good to fair condition. Penetrations from 20% to 25% are recorded throughout the'interval. The damage appears in the form of General Corrosion with Isolated Pitting. No significa,nt areas of cross-sectional wall loss are recorded throughout the interval. Deposits restrict the minimum measured I.D. to 2.74" @ 7,426.' No other significant I.D. restrictions are recorded throughout the interval logged. A 3-D Log Plot of the interval of tubing logged is included in this report. The caliper recordings indicate that the interval of 4.5" liner logged is in good to fair condition with respect to corrosive penetrations. Penetrations from 20% to 28% are recorded throughout the interval. The damage appears in the form of General Corrosion with Isolated Pitting. Perforated intervals are recorded in joints 20 and 22. No areas of significant cross-sectional wall loss are recorded throughout the interval logged. Heavy deposits restrict the minimum measured I.D. to 3.22" @ 8,025.' Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. Joint numbering is an approximation based on average joint length and top depth recorded in the interval logged. 3.5" TUBING - MAXIMUM RECORDED WALL PENETRATIONS: Shallow Corrosion (25%) Jt. 241 @ 7,372 Ft. (MD) Shallow Corrosion (24%) Jt. 240 @ 7,324 Ft. (MD) Shallow Corrosion (24%) Jt. 242 @ 7,421 Ft. (MD) Shallow Corrosion (20%) Jt. 240.1 @ 7,352 Ft. (MD) No other significant wall penetrations are recorded throughout the logged interval. 3.5" TUBING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No areas of significant cross-sectional metal loss (> 9%) are recorded throughout the logged interval. 3.5" TUBING -MAXIMUM RECORDED ID RESTRICTIONS: Lt. Deposits Minimum I.D. = 2.74" Jt. 242 @ 7,426 Ft. (MD) ProActive Diagnostic Services, :[nc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memor¥1og.com Prudhoe Bay Field Office Phone: (907) 659.-2307 Fax: (907) 659-2314 No other significant I.D. r~.~'ictions are recorded throughout the Iogge(~ ,,,terval. 4.5" LINER - MAXIMUM RECORDED WALL PENETRATIONS: Perforations (100%) Jt. 20 @ 8,016 Ft. (MD) Perforations (100%) Jt. 22 @ 8,067 Ft. (MD) Corrosion (28%) Jt. 19 @ 7,979 Ft. (MD) Line Corrosion (27%) Jt. 12 @ 7,830 Ft. (MD) Corrosion (26%) Jt. 25 @ 8,179 Ft. (MD) 4.5" LINER - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No areas of significant cross-sectional metal loss (> 12%) are recorded throughout the logged interval. 4.5" LINER -MAXIMUM RECORDED ID RESTRICTIONS: Heavy Deposits Minimum I.D. = 3.22" Jt. 20 @ 8,025 Ft. (MD) Deposits Minimum I.D. = 3.51" Jt. 21 @ 8,047 Ft. (MD) Deposits Minimum I.D. = 3.60" Jt. 16 @ 7,881 Ft. (MD) Deposits Minimum I.D. = 3.61" Jt. 26 @ 8,192 Ft. (MD) Deposits Minimum I.D. = 3.64" Jt. 7 @ 7,610 Ft. (MD) Field Engineer: D. Cain Analyst: M. Lawrence Witness: M. Chaney ProActive Diagnostic Services, Inc. / P,O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (28:1.) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 Weli; 3GdgA Date; September 2~ 20¢2 GLM 5 Pup Jt. 248,3 Joint 242 WLEG 7360 7370 7388 7390 7400 7410 7420 7430 7440 PDS REP~ JOINT TABULATION SHEET e ?ipe: 3.5 ins 9.3 ppf U80 Wall thickness: i}ody = 0254 ins Upsel = 0.254 ins Nominal ID: 2.992 ins Metal Body Ioss Projeciion Cpbg god~ No. Upset Bd@Up ; inch~s i inches inches Well: 311-19A FMd: Kuparuk Conlpany: PHIkLIPS Alaska, Inc, Country: USA Survey Date: Septembe~ 2, 2002 penetration body metal loss body 2402 0 0 0 0 0 0 0 N/'A GLM 5 (late:h@ 10:00) ~i 0~ ~2 Ob 5~ ~ 0~ .lO 2.85 Shall ...... onosi 241.1 0 0 0 0 0 0 0 2.75 [ i)-NIP .i I...~ I 0 0 0 0 0 0 0 N/A WLEG Damage classification scheme Penetration / projection class, in order of damage severib/ t/ole - penetration exceeds 85% of nominal wall ~hickness Damage reporting thleshold -: 30 thou inches deviation in body, 50 thou in coupling. Modal line length = 0.203 feet. l)an~age Profile (% wall} ~) 5 0 I 0(} P pe Tabula i )ns p ige 1 Well: 3G-19A Field: Kuparuk Company: PHILLIPS Alaska Inc. Country: USA PDS Caliper Statistical Evaluation Report Survey Date: September 2, 2002 Tool: MFC 24 No. 00387 Tool Size: 1.69 inches Tubing I.D.: 2.992 inches 0.24 0.19 0.14 O.Og 0.04 0.1 Percent Probability of Hole 10 20 50 100 I 10 100 Average Rank Maximum Probable Penetration* 0.066 inches (25.9 % Wall Thickness) Percent Probability of Recording a Hole* Less than 10% Derived I'rom data with average rank value less than or equal to 20. PDS Report Cross Sections Well: 3(]-19A Survey Date: September 2, 2002 Field: Kupa~uk Tool Type: MFC 24 No. ()03~7 Company: PHILLIPS AJasl<a. Inc. Tool Size: 1.69 Country USA No. of Fin/~ers: 24 Cross Section for Joint 241 at depth 7371,98ft Tool speed = 53 Nominal ID = 2.q92 Lpset OD = 3.500 I~emaini%, wall ama = 98 % Shallow Corrosion 0.06 ins = 25% Wall Penelration lllGH 51Dl = UP Cross Sections pa~ 1 PDS Report Cross Sections Well: 3G-19A Survey Date: September 2~ 2002 Field: Kup,~uk Tool Type: MFC 24 No. 00387 Company: PI iILLIPS Alaska, lnc, Tool Size: 1.69 Country: USA No, of Fingers: Cross Secdon for Joint 242 at: depth 7426,28 ft qool speed = 54 Nominal ID = 2.992 Nominal OD - 3.$00 Remaining v~a]l a~ ea = 9~i % Finge~ 17 Proiection -0.248 ins lt. Deposils Minimum I.D: 274 ins HIGH SIDE ,, UP (~oss Sections page 2 PDS REPORT JOINT TALLY SHEET Pipe: 3.5 ins 9.3 ppf L-80 Wall thickness: Body = 0~254 ins Upset = 0.254 ins Nominal ID: 2.992 ins Joint Depth Length [Modal [ Mean Nominal [Nominal Type No. ID ID ID OD feet feet inches ! inches inches inches 239 7308.98 10.54 2.992[ 2.992 2.992 3.500 1240 7319.52 31.83 2.955 2.948 2.992 3.500 240.1 7351.35 5.71 i 2.957 2.949 2.992 I 3.500 pup 240.2 7357.06 8.23 I N/A N/A 2.992 3.500 ~lm 240.3 7365.29 6.39 2.993 2.980 2.992 3.500 )up !241.1 740t.00 3.42 2.750 2.750 2.750 3.500 [d-nip 241.2 [ 7404.42 5.80 2.936 2.941 2.992 3.500 up 242 7410.22 35.22[ 2.951 2.954 2.992 3.500 i242.1l 7445.44 N/A [ N/A N/A [ 2.992 [ 3.500 leg Well: 3G-19A Field: Kuparuk Company: PHILLIPS Alaska, Inc. Country: USA Survey Date: September 2, 2002 Joint Depth Length [Modal Mean Nominal Nominal Type · No.] ID ID ID OD feet feet inches inches inches inchesI I I - Joint Tally page 1 PDS Report Overview Body Region Analysis Well: 3(; 19A Survey Date: SeptemM< 2, 2002 Field: Kup~mk Tool qype: MFC 24 No. 0038~ Company: PHILLIPS Alaska, Inc, Fool Size: 1.69 Cotmt~v: USA NO. of Fingers: 24 Analyst M: Lawrepce Itl~)il~g Nc~;~SD Weight ~acle & [~read Non~D Non~ Upse~ UpF<*r k~n7 ~ ower]c';~ Perpetration and Me~a[ Loss (% wa[i) k~a~ penetratkm body ~ rne~a[ loss body 20 0 to 10 to 20 to 40 to ox, er 1% 10% 20% 40% 85% 8 Number of joints analysed (tota{: pem~, 0 0 15 9 0 2 1 I I 3 2 0 0 0 Damage Configuration ( body ) 20 Damage Profile 11 Number ol joints damaged (total = 25) 5 10 7 1 2 Bottom of Survey '~ 26 Analysis OvelMew page 2 Welh FieJd: Company: Country: PDS Caliper Minimum Diameter Profile Survey [)ale!: August 2, 2002 ~oo]: MF( 24 No 00387 fool Size: 169 inches lubing LD: 3.958 inches Mi~limum Measured Diameters PDS REP~ JOINT TABULATION SHEET I'ipe: 4.5 ins 126 ppf 1-80 Wa{I thickness: Body = ) .... ins .... ins Nomin d ID: '~,958 ins Well: '~G-19A Field: Kupamk Company: PI I1LLIPS Alaska, h/c. Country: l)fiA Surw~y Date: September 2, 2002 C )6 ,V ( .14 3 3.74 Corrosion. L 24 ) .05 20 ~ 3.~a Shallow corrosion. Lt. Deposa:~. 25 0 .07 , .05 24 . 70 Corrosion. Deposits. 26 0 .07 55 36 ~.61 Corrosiot Del: Damage ( [as,;ificaiion Penelrafion / projection (las% in order ot damage severi~/ ~ {ole ponetn~tion ex(cods 85% o{ nominal wall Line - damage depth range exceeds 5 * pipe ID, bul extends less than 20% of circumference. isolated - damage depth range (Joes not exceed 5 * pipe ID or extend more thais 20S4 of ckcumference. Damage reporting threshold = 30 thou inches deviation in body, 50 thou in coupling, Modal line length = 0.220 feet. metal ii)ss hod Damage ProfiF= 50 Pipe Tabulations page I PDS Report Cross Sections Well: }6-19A Su!seV Date: September 2, 2002 Field: Kuparuk Tool 'lype: MFC 24 No 00387 Company: PI II,LIPS Alaska, Inc. Tool Size: Country: USA No. of Firq~e~s: 24 Cross Section for joint fool speed = ~5 Nominal ID ~- L958 Nominal OD ,, 4,500 ~.e ~ ~ g wall ama 97 % 19 at depth 7978.54 ft Fin/~er 15 F~enetlaIion = 0076 ins 0.0(') ins = 28% Wall Peneiration PDS Report Cross Sections Well: 3G-19A Survey [)ate: September 2, 2002 Reid: Kupaluk 1oo] Type: MFC 24 Nc). 00387 Con/party: I'Hil tl~b Alaska, Inc. Tool Size: I 69 Country: USA No. of Fingers; ~4 Cross Section for joint 20 at depth 8024,74 ft Taol speed = 56 NomirlaJ ID = 3.958 Nominal OD = 4.500 Tool deviation - 60 ' Finge~ 4 Proit'clion = -0704 ins Hea~v Deposils Minimunl I.D. = ~,22 ins IlK]Il SIf)l - UP PDS REPORT JOINT TALLY SHEET Pipe: 4.5 ins 12.6 ppf L-80 Wall thickness: Body -- 0.271 ins Upset = 0.271 ins Nominal ID: 3.958 ins Joint[ Depth Length !Modal [ Mean Nominal ~Nominal Type No. ID ID ID [ OD feet feet inches inches inches I inches I 1l 7447.64 3.67l 3.958 3.9081 3.958[ 4.500 2[ 7451.31 33.99 3.927 3.925 [ 3.958 4.500 3 [ 7485.30 30.34 3.892 3.899 I 3.958 4.500 4 7515.64 30.86 3.920 3.913 ] 3.958 [ 4.500 5 . 7546.50 30.87 3.850 3.856 3.958 4.500 6 i 7577.37 29.23 3.883 3.870 . 3.958 4.500 7[ 7606.60 30.92 3.958 3.798 I 3.958 4.500 8 7637.52 29.66 , 3.958 3.890 3.958 4.500 9 [ 7667.18 30.17 3.905 3.908i 3.958 4.500 ! 10 7697.35 29.29 3.877 3.877 3.958 4.500 11 7726.64 31.52 3.958 3.895 3.958 4.500 [ 12 7758.16 30.81 3.934 3.908[ 3.958 [ 4.500 I 13 . 7788.97 31.80[ 3.958 3.821 [ 3.958 I 4.500 I I 14 7820.77 29.82 ! 3.869 3.852 [ 3.958 i 4.500 15 7850.59 29.54 3.958 3.765 3.958 [ 4.500 16 . 7880.13 28.45 3.958 3.774 3.958 I 4.500 17 [ 7908.58 29.94 3.958 3.827 3.958 [ 4.500 ~ 18 [ 7938.52 28.21 3.958 3.875 [ 3.958I 4.500 I 19[ 7966.73 32.14I 3.913 3.913 3.958 [ 4.500 [ 20 [7998.87 31.38 3.958 3.885 3.958 4.500 ' 21 [ 8030.25 26.85 [ 3.9t8 3.911 [ 3.958 4.500 23 8092.10 25.20 3.953 3.951 3.958 4.500 25 8148.08 32.35 3.929 3.9191 3.958 4.500 [ 26 I 8180.43 N/A 3.958I 3.910[ 3.958 4.500 Well: Field: Company: Country: Survey Date: Joint No. 3G-19A Kuparuk PHILLIPS Alaska, Inc. USA September 2, 2002 Depth feet Length ModalID inches feet Mean Nominal INominal Type I ID OD ID inches inches inches I Joint Tally page 1 RECEIVED Sperry-Sun Drilling Services LIS Scan Utility SRcvision: 3 $ LisLib SRevision: 4 $ Tue Dec 11 09:38:58 2001 3g-i ga. tapx JZ .I 0 5 2o02 Alaska Oil & Gas Cons. Commmsior, Anc~.orage Keel Header Service name ............. LISTPE Date ..................... 01/12/11 Origin ................... STS Reel Name ................ UN?~O~ Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 01/12/11 Origin ................... STS Tape Name ................ UNknOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS WELL, NAME: AP1 NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEI.,: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 2 AK-MM-ii099 A. WEAVER D. HIEM 3G-19A 501032013601 Phillips Alaska, Inc. Sperry-Sun Drilling Services ii-DEC-01 23 12N 8E 2538 ]..45 83.55 53.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 6.125 7.000 7511.0 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). Page 1 39-19a. tap:< 3. ~D RUN 1 WAS DIRECTIONAL ONLY AND IS NOT PRESENTED. 4. P~D RUN 2 WAS DiRECTiONAL, WiTH DUAL G~P[A RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PI~ASE-4 {EWR4). DEPTH SHIFTING/CORRECTION STATUS OF MWD DATA IS PENDING PER E-MAIL FROM R.~L!SH {SSDS) TO D.SCHWAR'PZ (PHiLLiPS ALASKA) DATED 09/12/01. MWD RUN 2 REPRESENTS WELL 3G-19A WITH API#: 50-103-20136-01. THIS WELL REACHED A TOTAl, DEPTH (TD) OF 8301'MD/6016'TVD. SROP = SMOOTHED RATE OF PENETRATi~ WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP ~ SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING)- SEDP = SMOOTHED PHASE S[~IFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 7500.0 8260.5 RPX 7510.5 8267.5 RPS 7510.5 8267.5 RPM 751.0.5 8267.5 RPD 7510.5 8267.5 FET 7510.5 8267.5 ROP 7534.5 8301.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 2 7500.0 8301.0 MERGED MAIN PASS. $ Page 2 3g-iga. tap:< Data Format Specification Record Data Record Type .................. 0 Data Specification Dlock T~e ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-t~e...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR P~D API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD b~qD OIIMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 Name Service Unit Min Max DEPT FT 7500 8301 ROP MWD FT/H 5.64 204.01 GR F~D API 36,98 281.67 RPX MWD OHMM 1.47 1515.9 RPS MWD OHMM 1.49 1314.16 RPM MWD OHMM 1.5 2000 RPD MWD OHMM !.67 2000 FET MWD HOUR 0.525 25.8933 First Reading For Entire File .......... 7500 Last Reading For Entire File ........... 8301 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Mean, 7900.5 27.9278 110.658 7.18949 8.01328 24.,4534 20.1.14 2.59606 Ns@m 1603 1,534 1522 151,5 1515 15].5 1515 1515 First Reading 7500 7534.5 7500 7510.5 7510.5 7510.5 7510.5 7510.5 LasI2 Reading 8301 8301 8260.5 8267.5 8267.5 8267.5 8267 · 5 8267.5 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/11 Maximum Physical Record..65535 File T~e ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH Page 3 GR 7500.0 RPX 7510.5 RPS 7510.5 RPH ~5', ~. ~ 5 RPD 7510.5 FET 7510.5 ROP 7534.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 8260.~ 8267.5 8267. t °~67u= .5 8267.5 8267.5 8301 . 0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record 7'5~e .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...O 3g-i 9a. h ap~',~ 17-JUN-O1 Insite 4.30 Memory 8301.0 7511.0 8301.0 77.0 TOOL NUHBER PB01967GR4 PB01967GR4 6.125 7511.0 LSND/GEM 12.50 4'7.0 9.5 1100 2.6 2.400 70.0 1.268 138.6 1. 950 70.0 3.500 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP HWD020 FT/H 4 i 68 4 2 GR MWD020 API 4 1 68 8 3 Page 4 Sg-iga. t~p>t RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RrM MWD020 OHMM 4 1 68 20 6 RPD i',~qD020 OIIMH 4 i 68 24 7 FET MWD020 HOUR 4 1 68 28 8 Name Service Unit Min Max DEPT FT 7500 8301 ROP MWD020 FT/H 5.64 204.01 GR MWD020 API 36.98 281.67 RPX MWD020 OHMM 1.47 1515.9 RPS MWD020 OHMM 1.49 1314.16 RPM MWD020 OHMM 1.5 2000 RPD MWD020 OHMM !.67 2000 FET MWD020 HOUR 0.525 25.8933 First Reading For Entire File .......... 7500 Last Reading For Entire File ........... 8301 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Elrst Mean Nsam Reading 7900.5 1603 7500 27.9278 1534 7534.5 'i0 65° 15°° 7500 7.18949 1515 7510.5 8.01328 1515 7510.5 24.4534 1515 7510.5 20.114 1515 7510.5 2.59606 1515 7510.5 Last Reading 8301 8301 8267 5 8267 5 8267 5 8267 5 8267 5 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/12/11 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next 'rape Name ............. UNKNOWN Cemments ................. STS LIS Writing Library.. Reel Trailer Service name ............. LISTPE Date ..................... 01/1,2/1,1 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End OfL_=,'t'e Fil_.e Page 5
