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187-077
Ra 0137 s EEr.) STATE OF ALASKA AI ARKA nll ANn rAc cnnicr=ovoTinni nnnn.nioca^. ___...._ _.._ __.-_ 1. - I-......, 1 14 WEL❑L CO❑MPLETIO❑ COMPLETION PL❑ETIONREPORTAND LOG RECOAbanMn 1a. Well Status:WElOther ❑ Suspended ❑ 1 b. Well Class zoAac 25.105 zoAAc zs.i 10AOGGG GINJ ❑ WINJ ❑ WAGE] WDSPL ❑ No. of Completions: 2. Operator Name: 6. Date Comp., Susp., or ConocoPhillips Alaska, Inc. Aband.: 5/14/2019 3. Address: 7. Date Spudded: Dev LvJ ' Exploratory ❑ Service ❑ Stratigraphic Test ❑ 14. Permit to Drill Number / Sundry: ' 187-077 .O 7 ( 1f1 15. API Number: P.O. Box 100360 Anchorage, AK 99510-0360 919/1987 50-103-20077-00 - 00 4a. Location of Well (Governmental Section): 8. Date TO Reached: 16. Well Name and Number: Surface: 1446' FNL, 281' FWL, Sec 12, T12N, R8E, UM Top of Productive Interval:ry'/ l4L'� 9113/1987 KRU 314-05 9. Ref Elevations: KB:76 - 17. Field / Pool(s): 1268' FSL, 1375' FEL, Sec 11, T12, R8E, UM Total Depth: 1061' FSL, 1478' FEL, Sec 11, T12N, R8E, UM GL: BF: Kuparuk River Field/Kuparuk River Oil Pool - 10. Plug Back Depth MD/TVD: 18. at Surface Property Designation: ADL 25531 - 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 498655 y- 6000211 • Zone- 4 11. Total Depth MD/TVD: 19. . 715516190 - DNR Approval Number: ALK 2657 TPI: x- 497001 y- 5997646 Zone- 4 Total Depth: x- 4,96966 "(16?f y- 5pr90 5'111435 Zone- 4 12, SSSV Depth MD/TVD: 20. N/A Thickness of Permafrost MD/TVD: 160011562 5. Directional or Inclination Survey: Yes ❑ (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary N/A 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 1 6 62.5 H-40 52 115 52 115 24 255 sx AS 1 9 518 36 J-55 52 3454 52 3127 121/4 1250sx AS III & 425sx Class G, 7 26 J-55Top Job performed w/1 noqx AS 1 52 7150 52 6188 8 1/2 300 sx Class G & 400sx AS I 24. Open to production or injection? Yes ❑ No ❑2 25. TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): PERFORATIONS PLUGGED SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 31/2 6557 3108/2834, 6510/5666 ^ I n� tb���L gA 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No ❑� ow D T S fK Ulf VERIF ED Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED Plug 1:7014-3034' 34bbls SqueezeCrete, 126bbls 15.8 Class G (Prod Csg Plug 2:3000-1032' 70bbls 15.7ppg Permafrost Cmt (Tbg & IA) 27. PRODUCTION Plug 3:925 -Surface 88bbls 15.7ppg Permafrost Cmt (Tbg, IA, OA) TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): N/A PLUGGED BACK Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Test Period Flow Tubing Press. Casing Press: Calculated 24 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (torr): ..... .0-vur Ruvisea 5J20 r V'Y'Z 1 61.731l i CONTINU D ON PAGE 2 SubmiLORIGINIAL only //U //� riBDMS�' MAY 3 12flt9 fir,. �,..�, f� 28. CORE DATA Conventional Core(s): Yes ❑ No E Sidewall Cores: Yes [-1 No 2] If Yes, list formations and intervals cored (MDfrVD, From[To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� Surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Permafrost - Base 1600 1562 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 3 Formation at total depth: N/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, Paleontological report production or well test result,9.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: Alaska Drilling Manager Contact Email: Jill.Simek co Authorized ^ Contact Phone: 263-4131 Signature: 523 [� _ Date: Et lPt INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item ib: 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 form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, Fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only _ KUP WELLNAME 3H-05 WELLBORE C0000Pap$ Well Attributes Alaska, )RG IKUPNRmUK RIVER I NIT WIIo�gPlIUWI W¢IIW�e Slaus 11-jr) JMCl VeV.5R21X 101352. 1. Cement Squeezes ea�m vmrca zticl•=ene TOP ITv01 Rem lrvDl TOP UIKBI RM(I RUG) HIDER Dee filen Dad Com M. PI Ale PMa u3MBlrol: sz.onKa 3,0340 3,14).2 Plug #1 91)2018 PM➢ 431u1:32om(0 Mn PUR0 OAI: 53Ufl1(e 3,1472 1,014.0 Plug pl 9I27I2016 GGA.—1 s2.AMID ♦- 1,032.0 3,000.0 PIU -#2 401019 FATC6a100 1,0320 3,000.0 Plug #2 401019 r' 520 9250 Plug#3 412312019 CONDUCTOR; no -n5.0 52.0 9250 71Ug#3 41312019 NIPPLE, 534.0 52.0 9800 Plug #3 41312019 TNI PW 030.0 FSAPot 563.0 PIc0. Rmw S)'�t REG.= EG. K8 P4y SIC (A); 1p32.M1K8 TN Purely 25550 PLUG, AXYO EW#1)NGCPI; ARM C MR G40 LIFT; AGR. PACKER: AI..1 CumM Redux. 3, I.G NIPPLE: 3,135.] WIEG: 31W.] PII (PC): 314]2 ME SU RFACF, 52634X.2 PUMP 1; 69510 PUMP 2', 33]].5 MAKE: 8304.0 REAL 1; 0,ffi6 IHAA 2', 6,., MOTOR; 6435,2 DEPLOY: 4480.4 PACKER: o.510.A SBE; 6,5133 TPAC', 35328 FAV:AMSB VAEQ AGR3 FISH: 37180 IRISH, 6,]20.0 (PERF; 6, 7MI.048310 EDER 8AGE PE0.,0� (PERE, 6FOR ", 0 .PERF, 6,W4.68,BI40 PRODUCTION; 520.],1.0 J L P&A WELL SERVICE REPORT SUMMARY Date Well Event 5/14/2019 Back fill and vibirate 10'X 16" pipe out of the ground 5/13/2019 State witness cement in all strings and marker plate forfinal P&A that was 5' below tundra. 5/12/2019 Using trimmer & excavator remove cellar and excavate to 14' (6' into tundra) for final P&A. 5/11/2019 P&A CUT OFF WELL (47") 5/10/2019 (P&A) Reomove tree and fill tubing w/cement (12 gals). 4/26/2019 (P&A) BLEED T/I/O TO 0 PSI (COMPLETE), T/I/O DDT (PASS) 4/23/2019 Performed fullbore cement P&A from existing plug to surface. Pumped 30 bbls diesel down tubing, up IA and 15 bbls down tubing up OA to verify circualtion. Circulated 47 bbl's AS -1 down tubing, up OA to surface (cmt returns scaled @ 15.6#). Closed OA and circulated remainine cement. 41 bbls. un IA to surface I cmt returns scaled 0 15.7#1. In croeress. 4/21/2019 MIRU E -line, PT Lubricator to 500/3000 PSI. Perforate 980' - 985' w/ 5'x 2.00" PowerFlow HSD 1 SPF, 0 Deg Phase. CCL to Top Shot = 5.6', CCL Stop Depth = 974.4'. LRS unable to establish injectivity pumping down tubing and up IA, and limited injectivity up the OA. Suspect cement higher than expected in the M. Perforate 920'- 925' w/ second gun. CCL to Top Shot = 5.6', CCL Stop Depth = 914.4'. RS pctahkh ini ,flvih un hMh the IA and r1A at 7 RPM Pmmn Flinp 4/10/2019 MIT-TTO 1550 PSI AND DRAW DOWN TEST JOB COMPLETE 4/9/2019 DRIFT W/ TX 2.5" BAILER DOWN TO TOC @ 1032' RKB. JOB COMPLETE & READY FOR PRESSURE TESTING FOLLOWED BY E -LINE. 4/7/2019 PUMP 70 BELS ASI CEMENT FOR PLUG FROM 3000' TO 1000' IN TUBING AND I/A, FREEZE PROTECTED, READY FOR SLICKLINE TAG. 2/18/2019 Circulation test Job comDlete 2/17/2019 PERFORATE 2995' TO 3000' WITH 2.00" X 5' POWERFLOW, 1 SPF, ZERO DEG PHASED, 6 SHOTS, HIGH SIDE. GOOD INDICATION OF TUBING X IA COMMUNICATION. NO INDICATION OF TUBING X OA COMMUNICATION. READY FOR LRS. 2/6/2019 DDT -T (IN -PROGRESS), DDT -IA (IN -PROGRESS), DDT -OA (IN -PROGRESS). 2/3/2019 DDT -T (IN -PROGRESS), DDT -IA (IN -PROGRESS), DDT -OA (IN -PROGRESS). 2/1/2019 DDT -T (IN -PROGRESS), DDT -IA (IN -PROGRESS), DDT -OA (IN -PROGRESS). 1/30/2019 DDT -T, DDT -IA & DDT -OA (IN PROGRESS) 1/29/2019 DDT -T PASS DDT -IA & DDT -OA IN PROGRESS 1/20/2019 DDT -T (PASSED), DDT -IA (IN PROGRESS), DDT -OA (IN PROGRESS). 1/19/2019 T, IA & OA DDT (IN PROGRESS). 1/17/2019 BLEED OA (IN PROGRESS), LEAVE TBG & IA ON OPEN BLEED FOR DDT PREP (COMPLETE). 1/13/2019 DDT -TIN -PROGRESS, DDT -IA IN -PROGRESS. 1/11/2019 T& IA DDT TOO PSI (IN PROGRESS). 1/8/2019 STATE WITNESSED (GUY COOK) MIT T PASSED TO 1780 PSI, STATE WITNESSED MITIA PASSED TO 1710 PSI. 1/8/2019 SET OWEN 10K CIBP AT 3020' 10/13/2018 T-DDT(IN PROGRESS). IA -DDT (IN PROGRESS). 9/30/2018 **STATE WITNESSED** TAGGED CEMENT @ 3034' RKB (OBTAIN GOOD SAMPLE OF CEMENT); MITTTO 1500 PSI (PASS); UNABLE TO GET PASSING DDT; RE -TAGGED @ 3034' RKB. OBTAIN SAMPLE AND OKAY TO MOVE FORWARD (GUY COOK). READY FOR E -LINE. 9/29/2018 TAG DS NIPPLE @ 534' RKB FOR C/F; TAG TOP OF CEMENT @ 3027' RKB; MITT TO 1500 PSI (PASS) DDT TO ZERO (PASS); WORKED BAILER INTO CEMENT DOWN TO 3030' RKB. READY FOR STATE WITNESS. IN PROGRESS. 9/27/2018 RIH, STING INTO RETAINER AT3125' RKB, PUMPED 34BBLS SQUEEZECRETE FOLLOWED BY 125BBLS 15.8 PPG CLASS G, UN STUNG LAID 1.1 BBL ON TOP OF RETAINER, CLEANED OUT DOWN TO 2996' RKB, WAIT MINIMUM 24 HRS FOR SLICKLINE STATE WITNESSED TAG. 9/26/2018 RIH WITH 2.90" GAUGE RING, TAG NIPPLE AT 534' PAINT YELLOW FLAG, OOH, MAKEUP HES RETAINER, RIH STOP AT FLAG CORRECT DEPTH TO MID ELEMENT 541' RKB. RIH SET RETAINER AT 3125' RKB..5" BALL RECOVERED. JOB IN PROGRESS 3/21/2018 DRIFT TBG W/ 3.5" BAITSUB & 2.76" x 12' DUMMY DRIFT TO 3180' RKB. JOB COMPLETE SUNDRY NOTICE 10-407 ConocoPhillips Well 3H-05 Plug and Abandonment May 20, 2019 ConocoPhillips Alaska, Inc. performed Plug and Abandonment operations on 3H-05, commencing operations on March 21, 2018 and completing the Plug and Abandonment on May 16, 2019. 34 bbls of SqueezeCrete and 126 bbls of 15.8 Class "G" cement was pumped to place a plug from 7,014ft KB to 3,034ft KB. A Cast Iron Bridge Plug was set above Top of Cement (TOC), at 3,020ft KB, then tubing punched, and 70 bbls of 15.7 ppg permafrost cement placed in the tubing and tubing x production casing annulus (IA) to 1,032ft KB. Tubing and casing were perforated above TOC, and 88 bbls of 15.7 ppg permafrost cement was circulated to surface in the tubing, IA, and production casing x surface casing annulus (OA). 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 Summary is attached. 31-4-05 P" Marker plate -13-.19• _ Ii Vvf��yy4 "Copyright 2019. All rights reserved. This photograph is provided to the AOGCC with ermission to copy f* its own use. Copying/ r purpose or by other arty is gwifbit consent of Conocol'hiilip,, Alas F }r 31-1-05 P&A Final r`,cP }B.iN•� 6 a/. �-� q. — "Copyright . At! rights reserved. Th togs - provided to the. AOGCC with permission to copy .own use.�.opyin for any Qtfier purpose or by oth+ party is prohib t jthd,5s Consent of ConocoPhillips ,,ncf ■ PTD /8jZ -0 Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Wednesday, May 1, 2019 2:12 PM To: Simek, Jill Subject: KRU 3H-05(PTD 187-077, Sundry 318-021) P&A Extension Request/Approval The extension to complete the P&A of this well is approved to 7/1/2019. Please have the work completed by then. Tha nx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepp a(�alaska.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.Loeao@alaskaagov From: Simek, Jill <Jill.Simek@conocophillips.com> Sent: Wednesday, May 1, 2019 10:35 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]KRU 3H-05(PTD 187-077, Sundry 318-021) P&A Extension Request/Approval Victoria, We have now finished downhole cementing work on 3H-05 and plan excavation and wellhead removal later this month (scheduled May 8). However, the Sundry expires today, May 1, 2019. ConocoPhillips thereby requests an extension to Sundry#318-021 to July 1, 2019 so that we may complete the P&A activities. Latest work summary is below: 4/21/2019: Perforate tubing and production casing 4/23/2019: Pump 89bbls ArcticSEt1 cement down tubing and up IA and OA, to surface. 4/26/2019: DDT -T, DDT -IA, DDT -OA pass Please let me know if the AOGCC can accommodate this request. Thanks, Jill From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.aov> Sent: Friday, February 08, 2019 1:05 PM To: Simek, Jill <Jill.Simek@conocophillips.com> Subject: [EXTERNAL]KRU 3H-05(PTD 187-077, Sundry 318-021) P&A Extension Request/Approval The extension to complete the P&A of this well is approved to 5/1/2019. 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. LoeDDld)alaska.goy CONFIDENTIALRY 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.Loeop@alaska gov From: Simek, Jill <Jill.Simek@conocophillips.com> Sent: Friday, February 8, 2019 12:50 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]RE: 3H-05 P&A (Sundry# 318-021) Victoria, On 1/8/2019, we set the cast iron bridge plug at 3020ft KB, per approved procedure below. State witnessed MIT -T (1780psi) and MIT -IA (1710psi) were obtained 1/8/2019. We are scheduled to continue the procedure with perforating and surface cement job this month. However, the sundry expires 2/14/2019. ConocoPhillips thereby requests an extension on this sundry to 5/1/2019 so we can continue and finish the P&A activities. Please let me know if the AOGCC can accommodate this request. Thank you, Jill Simek ConocoPhillips Alaska Staff Wells Engineer 700 G Street, ATO 1302, Anchorage, AK 99501 Phone: 907-263-41311 Cell: 907-980-7503 From: Loepp, Victoria T (DOA) <victoria.loepp@alaska eov> Sent: Wednesday, December 12, 2018 1:49 PM To: Simek, Jill <Jill Simek(@conocophillips com> Subject: [EXTERNALjRE: 3H-05 P&A (Sundry# 318-021) Please include State Witnessed MIT -IA and MIT -T in the actual procedure after placing CIBP. Thanx, Victoria From: Simek, Jill <Jill SimekCaDconocophillips com> Sent: Wednesday, December 12, 2018 10:16 AM To: Loepp, Victoria T (DOA) <victoria.loeppC@alaska eov> Subject: 3H-05 P&A (Sundry# 318-021) Victoria, For the 3H-05 P&A, we have pumped the first cement plug per approved procedure (Sundry Number 318-021). On 9/30/18, with State Witness, the plug was tagged at 3,034ft KB and a passing MIT -T to 1500psi was obtained. However, we have been unable to get a passing drawdown test to confirm isolation of the wellbore from formation. The following remedial procedure has been developed, and ConocoPhillips requests permission from the AOGCC to proceed with these P&A procedure changes. Work performed to date and list of proposed procedures are below. Please let me know if you agree with this path forward. Thanks, Jill Summary of Procedure (full procedure attached): I. Rig up eline. Set CIBP at 3,020ft KB. 2. Test plug (state witnessed). 3. Rig up eline and LRS. Perforate 3-1/2" tubing and 7" casing at 3,OOOft KB, establish circulation. 4. Rig up cementers. Pump 214.3 bbls AS1 cement for tubing/IA/OA surface plug. 5. Test plug 6. Wellhead excavation/ final P&A Work completed to date: 10/14/2018 T/I/O = SI 860/22/400 Tubing+860 psi, IA+1 psi since 10/13/18. P7`D 197-0-77 Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Friday, February 8, 2019 1:05 PM To: 'Simek, Jill' Subject: KRU 3H-05(PTD 187-077, Sundry 318-021) P&A Extension Request/Approval The extension to complete the P&A of this well is approved to 5/1/2019. 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.LoeppOO alaska.00V 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.Loeop@alaska.aov From: Simek, Jill <Jill.Simek@conocophillips.com> Sent: Friday, February 8, 2019 12:50 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]RE: 3H-05 P&A (Sundry# 318-021) Victoria, On 1/8/2019, we set the cast iron bridge plug at 3020ft KB, per approved procedure below. State witnessed MIT -T (1780psi) and MIT -IA (1710psi) were obtained 1/8/2019. We are scheduled to continue the procedure with perforating and surface cement job this month. However, the sundry expires 2/14/2019. ConocoPhillips thereby requests an extension on this sundry to 5/1/2019 so we can continue and finish the P&A activities. Please let me know if the AOGCC can accommodate this request. Thank you, Jill Simek ConocoPhillips Alaska Staff Wells Engineer 700 G Street, ATO 1302, Anchorage, AK 99501 Phone: 907-263-41311 Cell: 907-980-7503 From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Wednesday, December 12, 2018 1:49 PM To: Simek, Jill <Jill.Simek@conocophillips.com> Subject: [EXTERNAL]RE: 3H-05 P&A (Sundry# 318-021) Please include State Witnessed MIT -IA and MIT -T in the actual procedure after placing CIBP. Thanx, Victoria From: Simek, Jill <1ill.5imek@conocophillips.com> Sent: Wednesday, December 12, 2018 10:16 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.eov> Subject: 3H-05 P&A (Sundry# 318-021) Victoria, For the 3H-05 P&A, we have pumped the first cement plug per approved procedure (Sundry Number 318-021). On 9/30/18, with State Witness, the plug was tagged at 3,034ft KB and a passing MIT -T to 1500psi was obtained. However, we have been unable to get a passing drawdown test to confirm isolation of the wellbore from formation. The following remedial procedure has been developed, and ConocoPhillips requests permission from the AOGCC to proceed with these P&A procedure changes. Work performed to date and list of proposed procedures are below. Please let me know if you agree with this path forward. Thanks, Jill Summary of Procedure (full procedure attached): 1. Rig up eline. Set CIBP at 3,020ft KB. 2. Test plug (state witnessed). 3. Rig up eline and LRS. Perforate 3-1/2" tubing and 7" casing at 3,OOOft KB, establish circulation. 4. Rig up cementers. Pump 214.3 bbls ASI cement for tubing/IA/OA surface plug. 5. Test plug 6. Wellhead excavation/ final P&A Work completed to date: 10/14/2018I T/I/O = 51 860/22/400 Tubing+860 psi, IA+1 psi since 10/13/18. 10/13/2018 T -DDT (IN PROGRESS). IA -DDT (IN PROGRESS). Initial T/I/O = SI 1000/225/400. T FL @ SF. IA FL NS. Slip blind installed on WV. Bled T to 0+ psi in 11 in, held bleed open for 1 hr 20 min, constant stream 2.2 fl oz/min, repeated test 4 times v similar results. Bled IA to 14 psi in 1 hr, SI multiple times to allow gas to break out. Starting T/I/O = 0+/14/400. 15 min T/I/O = 12/21/400 (+12/+7). 30 min T/I/O = 35/21/400 (+23/0). 45 min T/I/O = 58/21/400 (+23/0). 60 min T/I/O = 84/21/400 (+26/0). Bled T to 0+ psi in 2 min (fluid). Final T/I/O = SI 0+/21/400. 10/5/2018 I T/I/O = SI 1000/210/420. FL @ SF 9/30/2018 **STATE WITNESSED** TAGGED CEMENT @ 3034' RKB (OBTAIN GOOD SAMPLE OF CEMENT); MITTTO 1500 P! (PASS); UNABLE TO GET PASSING DDT; RE -TAGGED @ 3034' RKB. OBTAIN SAMPLE AND OKAY TO MOVE FORWJ (GUY COOK). READY FOR E -LINE. Per pump report: MITT to 1500 psi Results Pre T/I/O = 275/190/415 Pressure up with 0.2 bbls diesel to reach test pressure. Initial T/I/O = 1500/200/415 15 min T/I/O = 1370/200/415 30 min T/I/O = 1330/190/415 (Fail, lost over 10% of test pressure) Flowline stayed at 125 psi throughout. Bled tubing back to 225 psi for Drawdown Test, bled back 0.2 bbls. Initial T/I/O = 225/190/415 15 min T/I/O = 330/190/415 30 min T/I/O = 370/190/415 Flowline stayed at 125 psi throughout. Bled tubing back to 225 psi. Retry MITT to 1500 psi Pre T/I/O = 225/190/415 Pressure up with 0.2 bbis diesel to reach test pressure. Initial T/I/O = 1535/200/415 15 min T/I/O = 1430/190/415 30 min T/I/0=1400/190/415 **PASS** Flowline stayed at 125 psi throughout. Bled tubing back to 225 psi, bled back 0.18 bbls. 9/29/2018 TAG DS NIPPLE @ 534' RKB FOR C/F; TAG TOP OF CEMENT @ 3027' RKB; MITT TO 1500 PSI (PASS) DDT TO ZER( (PASS); WORKED BAILER INTO CEMENT DOWN TO 3030' RKB. READY FOR STATE WITNESS. IN PROGRESS. Drawdown Test results Pre T/I/O = 300/190/415 Initial T/I/O = 15/185/415 15 min T/I/O = 50/185/415 30 min T/I/O = 90/185/415 Flowline stayed at 125 psi throughout. MITT to 1500 psi results Pre T/I/O = 0/225/440 1 bbl diesel to pressure up tubing. Initial T/I/O = 1525/250/440 15 min T/I/O = 1500/250/440 30 min T/I/0 = 1500/250/440 Flowline stayed at 125 psi throughout. 9/27/2018 RIH, STING INTO RETAINER AT 3125' RKB, PUMPED 34BBLS SQUEEZECRETE FOLLOWED BY 125BBLS 15.8 PPG CI UN STUNG LAID 1.1 BBL ON TOP OF RETAINER, CLEANED OUT DOWN TO 2996' RKB, WAIT MINIMUM 24 HRS F1 SLICKLI N E STATE WITNESSED TAG. 9/26/2018 Work to progress P&A: RIH WITH 2.90" GAUGE RING, TAG NIPPLE AT 534' PAINT YELLOW FLAG, OOH, MAKE UI RETAINER, RIH STOP AT FLAG CORRECT DEPTH TO MID ELEMENT 541' RKB, RIH SET RETAINER AT 3125' RKB..5' RECOVERED. JOB IN PROGRESS 3/21/2018 DRIFT TBG W/ 3.5" BAITSUB & 2.76" x 12' DUMMY DRIFT TO 3180' RKB. JOB COMPLETE Jill Simek ConocoPhillips Alaska Staff Well Integrity Engineer 700 G Street, ATO 1854, Anchorage, AK 99501 Phone: 907-263-41311 Cell: 907-980-7503 P7-0 /8-7-037- Loepp, Victoria T (DOA) From: Simek, Jill <Jill.Simek@conocophillips.com> Sent: Wednesday, February 20, 2019 11:07 AM To: Loepp, Victoria T (DOA) Subject: RE: KRU 3H-05(PTD 187-077, Sundry 318-021) P&A Sorry, I missed your return call! State witnessed MIT -T (1780psi) and MIT -IA (1710psi) were obtained 1/8/2019. -Jill From:imek, Jill Sent: Wknesday, February 20, 2019 11:01 AM To: Toepp, 'ctoria T (DOA)' <victoria.loepp@alaska.gov> Subject: KRU 3-OS(PTD 187-077, Sundry 318-021) P&A Victoria, On 2/17/2019 we atte ted the perforation of tubing and 7" casing with 2" 5ft Powerflow gun system, per approved P&A procedure. Circulatio ests show that we are now communicating with the IA through holes in tubing; however, circulation cannot be confirm to the OA due to suspected cement behind the 7" casing. ConocoPhillips, therefore, requests permission to amend the P&A procedure per below. Full procedure and schematic attached. Please let me know if you agree with this path Thanks, Jill Summary of Procedure (full procedure attached): N\ 1. Rig up cementers. Pump 70.1 bbls AS1 cement for tubing/11t1 2. Test/tag plug (expected tubing and IA TOC at 1,000ft KB) 3. Rig up eline and LRS. Perforate 3-1/2" tubing and 7" casing at 4. Rig up cementers. Pump 85 bbls AS1 cement for tubing/IA/OA S. Test plug 6. Wellhead excavation/ final P&A Jill Simek ConocoPhillips Alaska Staff Wells Engineer 700 G Street, ATO 1302, Anchorage, AK 99501 Phone: 907-263-41311 Cell. 907-980-7503 KB, establish circulation. .plug. Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Wednesday, February 20, 2019 11:12 AM To: Simek, Jill Subject: RE: KRU 3H-05(PTD 187-077, Sundry 318-021) P&A Procedure Change Approval is granted for the changes to the procedure as outlined below and in the attached procedure. Include this approval with the approved Sundry. 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(a)a I aska. oov CONFIDENTIALRY 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 sale 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 Victo(ia.Loepr)@alaska.gov From: Simek, Jill <Jill.Simek@conocophillips.com> Sent: Wednesday, February 20, 2019 11:01 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Subject: KRU 3H-05(PTD 187-077, Sundry 318-021) P&A Victoria, On 2/17/2019 we attempted the perforation of tubing and 7" casing with 2" 5ft Powerflow gun system, per approved P&A procedure. Circulation tests show that we are now communicating with the IA through holes in tubing; however, circulation cannot be confirmed to the OA due to suspected cement behind the 7" casing. ConocoPhillips, therefore, requests permission to amend the P&A procedure per below. Full procedure and schematic attached. Please let me know if you agree with this path forward. Thanks, Jill Summary of Procedure (full procedure attached): 1. Rig up cementers. Pump 70.1 bbls AS1 cement for tubing/IA plug. 2. Test/tag plug (expected tubing and IA TOC at 1,000ft KB) 3. Rig up eline and LRS. Perforate 3-1/2" tubing and 7" casing at 1,000ft KB, establish circulation. 4. Rig up cementers. Pump 85 bbls AS1 cement for tubing/IA/OA surface plug. 5. Test plug 6. Wellhead excavation/ final P&A Jill Simek ConocoPhillips Alaska Staff Wells Engineer 700 G Street, ATO 1302, Anchorage, AK 99501 Phone: 907-263-4131 Cell: 907-980-7503 From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.izov> Sent: Friday, February 08, 2019 1:05 PM To: Simek, Jill <Jill.Simek@conocophillips.com> Subject: [EXTERNAL]KRU 3H-05(PTD 187-077, Sundry 318-021) P&A Extension Request/Approval The extension to complete the P&A of this well is approved to 5/1/2019. 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 icto ria. Loepp(cDalaska. oov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)7931247 or Vict(Deia.Loepip@olaska.gov From: Simek, Jill <Jill.Simek@conocophillips.com> Sent: Friday, February 8, 2019 12:50 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]RE: 3H-05 P&A (Sundry# 318-021) Victoria, On 1/8/2019, we set the cast iron bridge plug at 3020ft KB, per approved procedure below. State witnessed MIT -T (1780psi) and MIT -IA (1710psi) were obtained 1/8/2019. We are scheduled to continue the procedure with perforating and surface cement job this month. However, the sundry expires 2/14/2019. ConocoPhillips thereby requests an extension on this sundry to 5/1/2019 so we can continue and finish the P&A activities. Please let me know if the AOGCC can accommodate this request. Thank you, Jill Simek ConocoPhillips Alaska Staff Wells Engineer 700 G Street, ATO 1302, Anchorage, AK 99501 Phone: 907-263-41311 Cell. 907-980-7503 From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.eov> Sent: Wednesday, December 12, 2018 1:49 PM To: Simek, Jill <JiII.Simek@conocophillips.com> Subject: [EXTERNAL]RE: 3H-05 P&A (Sundry# 318-021) Please include State Witnessed MIT -IA and MIT -T in the actual procedure after placing CIBP. Thanx, Victoria From: Simek, Jill <Jill,Simek@conocophillips.com> Sent: Wednesday, December 12, 2018 10:16 AM To: Loepp, Victoria T (DOA) <victoria.loeppCa@alaska.gov> Subject: 3H-05 P&A (Sundry# 318-021) Victoria, For the 3H-05 P&A, we have pumped the first cement plug per approved procedure (Sundry Number 318-021). On 9/30/18, with State Witness, the plug was tagged at 3,034ft KB and a passing MIT -T to 1500psi was obtained. However, we have been unable to get a passing drawdown test to confirm isolation of the wellbore from formation. The following remedial procedure has been developed, and ConocoPhillips requests permission from the AOGCC to proceed with these P&A procedure changes. Work performed to date and list of proposed procedures are below. Please let me know if you agree with this path forward. Thanks, Jill Summary of Procedure (full procedure attached): 1. Rig up eline. Set CIBP at 3,020ft KB. 2. Test plug (state witnessed). 3. Rig up eline and LRS. Perforate 3-1/2" tubing and 7" casing at 3,OOOft KB, establish circulation. 4. Rig up cementers. Pump 214.3 bbls ASI cement for tubing/IA/OA surface plug. 5. Test plug 6. Wellhead excavation/ final P&A Work completed to date: 10/14/2018I T/1/O = SI 860/22/400 Tubing+860 psi, IA+1 psi since 10/13/18. 10/13/2018 T -DDT (IN PROGRESS). IA -DDT (IN PROGRESS). Initial T/I/O = SI 1000/225/400. T FL @ SF. IA FL NS. Slip blind installed on WV. Bled T to 0+ psi in 11 in, held bleed open for 1 hr 20 min, constant stream 2.2 fl oz/min, repeated test 4 times w similar results. Bled IA to 14 psi in 1 hr, SI multiple times to allow gas to break out. Starting T/I/O = 0+/14/400. 15 min T/I/O = 12/21/400 (+12/+7). 30 min T/I/O = 35/21/400 (+23/0). 45 min T/I/O = 58/21/400 (+23/0). 60 min T/I/O = 84/21/400 (+26/0). Bled T to 0+ psi in 2 min (fluid). Final T/I/O = SI 0+/21/400. 10/5/2018 I T/I/O = SI 1000/210/420. FL @ SF 9/30/2018 **STATE WITNESSED** TAGGED CEMENT @ 3034' RKB (OBTAIN GOOD SAMPLE OF CEMENT); MITTTO 1500 PS (PASS); UNABLE TO GET PASSING DDT; RE -TAGGED @ 3034' RKB. OBTAIN SAMPLE AND OKAY TO MOVE FORWA (GUY COOK). READY FOR E -LINE. Per pump report: MITT to 1500 psi Results Pre T/I/O = 275/190/415 Pressure up with 0.2 bbls diesel to reach test pressure. Initial T/I/O = 1500/200/415 15 min T/I/O = 1370/200/415 30 min T/1/0 = 1330/190/415 (Fail, lost over 10% of test pressure) Flowline stayed at 125 psi throughout. Bled tubing back to 225 psi for Drawdown Test, bled back 0.2 bbls. Initial T/I/O = 225/190/415 15 min T/I/O = 330/190/415 30 min T/l/O = 370/190/415 Flowline stayed at 125 psi throughout. Bled tubing back to 225 psi. Retry MITT to 1500 psi Pre T/I/O = 225/190/415 Pressure up with 0.2 bbls diesel to reach test pressure. Initial T/I/O = 1535/200/415 15 min T/I/O = 1430/190/415 30 min T/1/0 = 1400/190/415 **PASS** Flowline stayed at 125 psi throughout. Bled tubing back to 225 psi, bled back 0.18 bbls. 9/29/2018 TAG DS NIPPLE @ 534' RKB FOR C/F; TAG TOP OF CEMENT @ 3027' RKB; MITT TO 1500 PSI (PASS) DDT TO ZERO (PASS); WORKED BAILER INTO CEMENT DOWN TO 3030' RKB. READY FOR STATE WITNESS. IN PROGRESS. Drawdown Test results Pre T/I/O = 300/190/415 Initial T/l/O = 15/185/415 15 min T/I/O = 50/185/415 30 min T/I/O = 90/185/415 Flowline stayed at 125 psi throughout. MITT to 1500 psi results Pre T/I/O = 0/225/440 1 bbl diesel to pressure up tubing. Initial T/I/O = 1525/250/440 15 min T/I/O = 1500/250/440 30 min T/l/O = 1500/250/440 Flowline stayed at 125 psi throughout. 9/27/2018 RIH, STING INTO RETAINER AT 3125' RKB, PUMPED 34BBLS SQUEEZECRETE FOLLOWED BY 125BBLS 15.8 PPG CL. UN STUNG LAID 1.1 BBL ON TOP OF RETAINER, CLEANED OUT DOWN TO 2996' RKB, WAIT MINIMUM 24 HRS FC SLICKLINE STATE WITNESSED TAG. 9/26/2018 Work to progress P&A: RIH WITH 2.90" GAUGE RING, TAG NIPPLE AT 534' PAINTYELLOW FLAG, OOH, MAKE UP RETAINER, RIH STOP AT FLAG CORRECT DEPTH TO MID ELEMENT 541' RKB, RIH SET RETAINER AT 3125' RKB..5" RECOVERED. JOB IN PROGRESS 3/21/2018 DRIFT TBG W/ 3.5" BAITSUB & 2.76" x 12' DUMMY DRIFT TO 3180' RKB. JOB COMPLETE Jill Simek ConocoPhillips Alaska Staff Well Integrity Engineer 700 G Street, ATO 1854, Anchorage, AK 99501 Phone: 907-263-41311 Cell: 907-980-7503 ConocoPhillips 31-1-05 P&A PROCEDURE REVISION 3 — February 20, 2019 Job Objective: Plug and abandon with cement to surface. Cut casing and tubing strings below grade and remove wellhead. Well Status: The well is secured with cast iron bridge plug at 3,020ft KB, above cement plug. MIT -T passes to 1780psi and MIT -IA passes to 1710psi. Last known fluid: • 3-1/2" Tubing = diesel • 3-1/2" x 7" = diesel • 7" x 9-5/8" = unknown Last SBHP = 2,420 psi @ 2,858' TVD (3,136' MD); obtained 10/9/2017 Min ID (above fish) = 2.875" Camco DS Nipple No -Go @ 534ft KB Max Deviation = 36 degrees at 6,300' KB Procedure: Cementing: Objective: Fill the wellbore with cement from tubing punch (3,000ft KB) to approximately 1,000ft KB in the tubing and IA. We will be circulating cement down the 3 %" tubing and up the 3 %" x 7" annulus. Cement Volume Calculations: • Volume in 3'/" x 7" annulus: (3,000ft—1,000ft) x 0.02636 bbl/ft = 52.7 bbl • Volume inside 3'/z' tubing: (3,000ft — 1,000ft) x 0.008696 bbl/ft = 17.4 bbl • Total volume: 52.7 + 17.4 = 70.1 bbl • Displacement volume: (1,000ft) ' (0.008696 bbl/ft) — 3 bbl spacer = 5.7 bbl 1. 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 70.1 bbls of ArcticSet 1 (AS1) cement. 2. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. JS 3. Ensure a 5" foam ball is loaded into the tree prior to the cement job. 4. RU Cementers. Pressure test surface equipment as required. 5. Establish circulation with diesel, pumping down tubing and taking returns from the IA. 6. Follow pump schedule below: i. Pump 5 bbls fresh water spacer ii. Pump 70.1 bbls of AS1 cement iii. Drop 5" foam ball iv. Pump 3 bbls fresh water spacer v. Displace with 5.7 bbls diesel to leave Top of Cement in tubing at 1,000' KB. Do not overdisplace. 7. Shut down pumps and close in tubing and IA. 8. Wash up cement pumps and clean up surface lines. 9. RDMO Slickline / Little Red Objective: Tag TOC, MIT -T, DDT -T 1. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 2. RU Slickline and PT Equipment as required. 3. RIH and tag TOC @ approximately 1,000' KB. Record Results. 4. RU LRS and PT Surface Equipment as required. 5. Perform MIT -T to 1,500 psi. Record Results. 6. Perform DDT -T. Record Results. 7. Report issues and results to Well Integrity Engineer. 8. RDMO E -line / Little Red Objective: Perforate 3'/2" tubing and 7" production casing to establish circulation for surface cement plug. 1. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 2. RU a -line and PT equipment as required. 3. RIH with dual -string perforating gun (5ft x 2" Powerflow downloaded to 1spf, zero degree phased), referencing 2/17/2019 schematic and tubing details for depth correlation. 4. Perforate above TOC —1,000' KB, as close to mid joint as possible. Orient perforating gun to shoot high side of tubing. 5. Rig up LRS and pump 20 bbls diesel through tubing holes to ensure adequate rate for cementing (+/- 2 bpm <= 2,000psi). JS 6. If 2 bpm circ. rate is not achievable, RIH with a second perforating gun and perforate holes 32' above the previous holes. 7. RDMO Cementing: Objective: Fill the wellbore with cement from perforation depth (-1,000' KB) to surface. We will be circulating cement down the 3 %" tubing and up the 9 5/8" x 7" annulus as well as up the 7" x 3 %" annulus. Cement Volume Calculations: • Volume in 3'/z" x 7" annulus: (1,000'-0') x 0.02636 bbl/ft = 26.4 bbl • Volume in 7" x 9 5/8" annulus: (1,000'-0') x 0.02971 bbl/ft = 29.7 bbl • Volume inside 3'/i tubing: (1,000'-0') x 0.008696 bbl/ft = 8.7 bbl • Excess: 20 bbl • Total volume: 26.4 + 29.7 + 8.7 + 20.2 = 85 bbl 1. 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 85 bbls of ArcticSet 1 (AS1) cement. 2. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 3. RU SLB Cement Equipment and PT surface lines as required. Ensure that hardline is rigged up to pump down the tubing and take returns to a tank from both the 7" x 9 5/8" (OA) and 3 %" x 7" (IA) annuli independently. Also ensure that there is a way to pump down the IA or OA in case the tubing pressures up. Rig up line to flush all surface lines of cement post -job. 4. Close the OA, open the IA, and pump 20 bbls of diesel down the tubing, taking returns to tank from the IA to confirm circulation. 5. Close the IA, open the OA, and pump 20 bbls of diesel down the tubing, taking returns to tank from the OA to confirm circulation. 6. After circulation to IA and OA is confirmed, batch up AS1 cement. 7. Line up to pump cement down the tubing, taking returns from the OA. 8. Follow Pump Schedule below: i. 5 bbls fresh water spacer ahead ii. 85 bbl of Permafrost Cement (cement to surface in T/1/0, including 20 bbls excess) 9. After approximately 38.4 bbis of cement is pumped away, expect to see OA cement returns. Utilize mud balance to confirm good AS1 cement to surface coming from the OA. Pump contingency cement if needed to obtain good cement to surface. 10. With good OA cement to surface, open the IA, close the OA, and line up to take IA returns to tanks. This step must be performed efficiently as Permafics Cement is thixotropic and will develop gel strength quickly when static. 11. After approximately 26.4 bbls of cement is pumped away, expect to see IA cement returns. Utilize mud balance to confirm good Permafrost Cement to surface JS DHD: coming from the IA. Pump contingency cement if needed to obtain good cement to surface. 12. After good OA and IA cement is seen at surface, shut down pumps and close in the IA and OA valves. 13. Close in the master valve, open up the cement clean up line, and circulate to tanks to wash up tree and surface equipment. 14. RDMO 15. Objective: DDT WOC for 48 hr or until field blend UCA chart shows cement developed 1,500 psi compressive strength. RU DHD and PT equipment. 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 T/I/O 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. A .)' 9. Send the casing head w/ stub to materials shop. Photo document. 10. Weld ''/a' thick cover plate (16" 0. D.) over all casing strings with the following information bead welded into the top. 'Ahoto document. AOGCC Witness required. ConocoPhillips 3H-05 PTD #: 187-077 API #: 50-103-20077-00 11. Remove Cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 12. ; . 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. JS Schematic: JS 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 RECEIVED b Kuparuk FEB 192019 167077 AOGCC 3 0 3 6 2 BP North Slope 0 0 0 EOA, PBOC, PRB-20 (Office 109) D&C Wells Project Aids 900 E. Benson Blbd. - Anchorage, AK 99508 USPS Tracking # Conoco Phillips Alaska Inc. 1 0 0 Attn: NSK-69 700 G Street Anchorage, Alaska 99501 USPS Tracking# n/a AOGCC 0 0 1 ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501-3539 USPS Tracking # 9405 5036 9930 0417 5293 91 DNR 0 0 1 Attn: Garrett Brown -Geologist DNR, Division of Oil & Gas 550 West 7th Ave, Suite #1100 - Anchorage, AK 99501 USPS Tracking # 9405 5036 9930 0417 5293 84 Please return via e-mail a copy to both Alaska E -Line Services and Conoco Phillips Alaska: MEMORANDUM TO: Jim Regg '"I ((l'5Itj P.I. Supervisor I 1 FROM: Guy Cook Petroleum Inspector Section: 12 Township: Drilling Rig: n/a Rig Elevation: Operator Rep: Shelby Sumrall Casing/Tubing Data (depths are MD): Conductor: 16" 0. D. Shoe@ Surface: 9 5/8" 0. D. Shoe@ Intermediate: Feet 0. D. Shoe@ Production: 7" 0. D. Shoe@ Liner: 0. D. Shoe@ Tubing: 3.5 0. D. Tail@ Plugging Data: Test Data: State of Alaska Alaska Oil and Gas Conservation Commission DATE: January 9, 2019 SUBJECT: Well Bore Plug & Abandonment KRU 3H-05 Conoco/Phillips Alaska PTD 187-077;"Sundry 318-021 12N Range: 8E Meridian: Umiat n/a Total Depth: 7155 ft MD Lease No.: ADL 0025531 Suspend: P&A: X 115 ' Feet 3454 Feet Csg Cut@ Feet 7150 Feet Csg Cut@ Feet 3147 , Feet Casina Removal: Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Tbg Cut@ Feet Type Plug Founded on Depth Btm De th To MW Above Verified Tubing Retainer 3020 ft MD N/A 60 P /" OA 360 360 360 Initial 15 min 30 min 45 min Result Tubing 1780 1745 - 1730 " IA 60 60 60 P /" OA 360 360 360 Initial 1.5 min 30 min 45 min Result Tubing 200 270 280 IA 1710 1580 1560 P OA 360 360 360 Remarks: MIT -IA and MIT -T after setting CIBP at 3020 ft MD for P&A. The tubing was fluid packed, but the IA was not and needed approximately 1.3 bbls to fill it. The bbls-in and bbls-out for the MIT -IA was 2.4 bbls in and .8 bbls out. The bbls in and out for the MIT -T were both at .3 bbls. Attachments: ;1o,,te_ rev 11-28-18 2019-0108_Plug_Verification_KRU_3H-05_gc A.,OF Tk • • 6w\�\I�j��s THE STATE Alaska Oil and Gas OfA sKA Conservation Commission L333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Jill Simek Staff Well Interrit Engineer Intergrity SCANNED i-Lb 5 , ,S ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3H-05 Permit to Drill Number: 187-077 Sundry Number: 318-021 Dear Ms. Simek: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, a167 Pg3-e-t-344- Cathy P. Foerster Commissioner DATED this (4 day of February, 2018. • • c RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS JAN 16 2018 20 AAC 25.280 OTS 2/ ( 4-I 1.Type of Request: Abandon Eli. Plug Perforations 0 Fracture Stimulate ❑ Repair Well ❑ G tions 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: ConocoPhillips Alaska, Inc. Exploratory ❑ Development 11 • 187-077 • 3.Address: Stratigraphic ❑ Service El 6.API Number: P. 0. Box 100360,Anchorage,Alaska 99510 50-103-20077-00 ' 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 3H-05 ' Will planned perforations require a spacing exception? Yes ❑ No E 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25531 ' Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth yip(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): .7-,.a66't,cidt 6,199' 6400 5576 2310psi 3120 6719,6720 Casing Length Size MD TVD Burst Collapse Conductor 79' 16" 115' 115' Surface 3,419' 9 5/8 3,454' 3,127' Production 7,115' 7" 7,150' 6,186' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6760-6831,6839-6859,6869- 5869-5927,5933-5950,5958- 4.500" L-80 6,557' 6889,6894-6914 5974,5978-5994 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-BAKER FHL PACKER MD=3108 TVD=2834 PACKER-BAKER FB-1 MD=6510 TVD=5666 12.Attachments: Proposal Summary 0 Wellbore schematic ] 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development I] Service ❑ 14.Estimated Date for 2/15/2018 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ] 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Jill Simek Contact Name: Jill Simek Authorized Title: Staff Wel Integrity Engineer Contact Email: Jill.Simek@cop.com Contact Phone: (907)263-4131 Authorized Signature: i Date: t 1 /gCOMMISSION USE ONLY Conditions of approval: Commission so that a representative may witness Sundry Number: —021 Plug Integrity BOP Test ElMechanical Integrity Test ElLocation Clearance Lr''' Other: N 0 Peery If �� bl� Fork, 740 p cL�wLr�tt ��s1 f`/5l_ Post Initial Injection MIT Req'd? Yes ❑ No � r C Z `J / 2- 1 ) ";) Spacing Exception Required? Yes ❑ No 2/ Subsequent Form Required: RED [' �L Fr,..'v i 1 L18is 10 APPROVED BY Approved by:a..6147 f i (Lip__ COMMISSIONER THE COMMISSION Date: 2.-/ c/__i 8 571.0 ORIGINAL 7,0 Submit Form and Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate S ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 15 January 2018 Commissioner,State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to Plug and Abandon Kuparuk Injector 3H-05(PTD#: 187-077). 3H-05 was drilled and completed in September 1987 as an A and C sand producer. In 2000, the well was recompleted with an electrocoil ESP. After two years of production, the ESP pump failed. A sundry approval was granted, allowing annular production through the failed ESP for one year. Shortly after the sundry was renewed, the electrocoil tubing was found to be leaking. Well Integrity suspected extensive ✓ corrosion and the well was shut in, killed, and loaded with inhibited fluids to minimize the cost of the planned rig workover(RWO)to pull and replace the ESP with a gas lift completion. During the 2004 RWO,the electrocoil tubing parted at 3,088ft KB and the rig was unable to recover the tubing fish or the ESP.A shallow packer with single mandrel gas lift completion was run and the well was returned to production. In 2007,3H-05 began producing emulsion and the well was shut in. Subsequent attempts to produce this well have been unsuccessful because of the emulsion.RWO and rotary sidetrack projects proved unattractive when compared to coiled tubing drilling(CTD).The resources targeted by 3H- 05 are now part of the pattern for the recently completed CTDproie_�ct 3H2b. ✓ The well has 9-5/8" surface casing to 3,454ft KB and 7"production casing to 7,150ft KB. There is 3-1/2" tubing with a packer at 3,108ft KB. Three sets of Kuparuk perforations are at 6,760.0-6,831.0ft KB; 6,839.0-6,859.0ft KB; 6,869.0-6,889.0ft KB; and 7,504.0-7,515.0ft KB. The electrocoil and ESP fish is located from approximately 3,147ft KB to 6,557ft KB. Per this procedure, P&A operations will be performed with coiled tubing to set a cement retainer at approximately 3,125ft KB and cement pumped into the 7" production casing, past the fish, across the Kuparuk perforations,and up into the 3-1/2"tubing tail. Circulation past the fish has been established with diesel. However, if unable to pump cement past the fish, ConocoPhillips asks the commission to approve plugging from the top of fish,per 20 AAC 25.112(1)(C). Cement will then be placed above the retainer in the tubing to an approximate depth of 3,000ft KB. Tubing and production casing will be perforated above top of cement and a second cement plug will be pumped fullbore,to bring cement to surface in the tubing,tubing x production casing annulus(IA), and production casing x surface casing annulus(OA). The well will then be excavated 4 feet below original ground level, wellhead and cellar removed,and site backfilled with gravel/fill to ground level. If you have any questions or require any further information,please contact me at 263-4131. Sincerely, Jill Simek .. Well Integrity Engineer CPAI Drilling and Wells • ConocoPhil l i ps 3H-05 P&A Permit to Drill #: 187-077 P&A operations will be performed with coiled tubing to set a cement retainer at approximately 3,125ft KB and cement pumped into the 7" production casing, past the fish (if possible) and up into the 3-1/2" tubing tail. Cement will also be placed above the retainer in the tubing to an approximate depth of 3,000ft KB. Tubing and production casing will be punched above top of cement and a second cement plug will be pumped fullbore, to bring cement to surface in the tubing, tubing x production casing annulus (IA), and production casing x surface casing annulus (OA). The well will then be excavated 4 feet below original ground level, wellhead and cellar removed, and site backfilled with gravel/fill to ground level. Procedure: Slickline: Objective: Drift for cement retainer 1. Inspect pad and work area for hazards. Complete pre-job safety meeting. RU slickline unit and support equipment. PT lubricator and surface lines as required. 2. RIH with 2.75" x 15' dummy mechanical cement retainer tool string, down to 3125' KB (middle of tubing joint in tubing tail). 3. RDMO. Coiled Tubing /Cementing: Objective: Plug #1 - Place a cement plug in production casing and tubing. NOTE: Maximum pressure, volume and rate for squeeze to be discussed and agreed with client representative at site prior to starting cement job, based on injectivity test results. Cement Volume Calculations (TOC in tubing to be at approximately 3,000' KB): SqueezeCRETE: • 7" production casing from 100ft below perforations to bottom of ESP tubing = (7,014' —6,557') x 0.03826 = 17.5 bbl • Squeeze volume = 10 bbl • 7" x 5.13" annulus (assume ESP and tubing constant OD = 5.13") = (6510' — 6,351') * 0.01270 bbl/ft = 2.0 bbl • 5.13" tubing and ESP (assume ESP and tubing constant ID = 3.958") = (6557' — 6,351') * 0.01522 bbl/ft = 3.1 bbl • Total volume SqueezeCRETE: 17.5 + 10 + 2.0 + 3.1 = 32.6 bbl Class "G": • 7" production casing from top of ESP to bottom of 3-1/2" tubing (assume e-coil tubing in pieces) = (6,351' — 3,147') x 0.03826 = 122.6 bbl JS • s • 3-1/2 tubing volume from tubing tail to cement retainer = (3,147' - 3,125') x 0.008696 bbl/ft = 0.2 bbl • 3-1/2" tubing volume from cement retainer to TOC = (3,125' - 3,000') x 0.008696 bbl/ft = 1.1 bbl • Total volume: 122.6 + 0.2 + 1.1 = 123.9 bbl 1. Ensure an approved sundry has been received from AOGCC. 2. Contact Schlumberger a week before the scheduled P&A date, to allow adequate time for pilot testing of the P&A cement design. (Charles Hacker/Stephen Higgins 907 659-6121). The job is designed for 32.6 bbls of SqueezeCRETE and 123.9 bbls of 15.8# Class "G" cement. 3. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 4. RU Coil Tubing Unit and PT Surface Equipment as required. 5. Reference 10/10/2016 schematic and tubing details for depth correlation. Perform tie-in/pipe flag run to ensure cement retainer is set at desired depth. 6. RIH with Weatherford 2.75" cement retainer, taking returns up the CT x Tubing annulus. Do not pump while RIH. 7. Set cement retainer at approximately 3,125' KB (middle of tubing joint in tubing tail), or as deep as the retainer will safely drift. 8. Close in the CT x tubing annulus, and line up to pump down the coil tubing. 9. Pump 30 bbls of diesel through the retainer to verify proper set and injectivity required for cementing operations (+/- 2 bpm at 2,000psi). 10. RU SLB Cement Equipment and PT surface lines as required. 11. Pump 10 bbls fresh water spacer 12. Pump 32.6 bbls of SqueezeCRETE cement, followed by 122.8 bbls of 15.8# Class "G" cement. If squeeze pressure is seen before pumping total cement volume, unsting from retainer and begin next step. 13. Shut down, un-sting from retainer 14. Lay in remaining 1.1 bbl cement above retainer (equates to - 125' of cement above the retainer, leaving TOC -3,000' KB) 15. POOH above TOC 16. Circulate CTU clean. 17. RDMO Slickline / Little Red Objective: State witnessed tag of TOC, MIT-T, DDT-T 1. WOC per UCA data (minimum 24 hours). Notify the AOGCC Inspector of the timing of the cement plug tag (submit AOGCC Test Witness Notification Form 24hrs in advance of witness). 2. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 3. RU Slickline and PT Equipment as required. 4. RIH and tag TOC @ approximately 3,000' KB. Record Results. TAG MUST BE AOGCC WITNESSED Is • • 5. RU LRS and PT Surface Equipment as required. 6. Perform MIT-T to 1,500 psi. Record Results. 7. Perform DDT-T. Record Results. 8. Report issues and results to Well Integrity Engineer. 9. RDMO E-line / Little Red Objective: Perforate 31/2" tubing and 7" production casing to establish circulation for surface cement plug. 1. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 2. RU e-line and PT equipment as required. 3. RIH with dual-string perforating gun (5ft x 2" Powerflow downloaded to lspf, zero degree phased), referencing 10/10/2016 schematic and tubing details for depth correlation. 4. Perforate above TOC —2,000' KB, as close to mid joint as possible. Orient perforating gun to shoot high side of tubing. 5. Pump diesel down tubing to confirm circulation to both IA and OA (+/- 2 bpm <= 2,000psi). Ensure fresh diesel is circulated into OA to fully displace unknown annulus fluid. 6. If 2 bpm circ. rate is not achievable, RIH with a second perforating gun and perforate holes 32' above the previous holes. 7. RDMO Cementing: Objective: Plug #2 - Fill the wellbore with cement from perforation depth (-3,000' KB) to surface. We will be circulating cement down the 31/2" tubing and up the 9 5/8" x 7" annulus as well as up the 7" x 3 1/2" annulus. Cement Volume Calculations: • Volume in 31/2" x 7" annulus: (2,000'-0') x 0.02636 bbl/ft = 52.7 bbl • Volume in 7" x 9 5/8" annulus: (2,000'-0') x 0.02971 bbl/ft = 59.4 bbl • Volume inside 3 '/2' tubing: (2,000'-0') x 0.008696 bbl/ft = 17.4 bbl • Excess: 20 bbl • Total volume: 52.7 + 59.4 + 17.4 + 20 = 149.5 bbl 1. Contact 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 149.5 bbls of ArcticSet 1 (AS1) cement. 2. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. Is • S 3. RU SLB Cement Equipment and PT surface lines as required. Ensure that hardline is rigged up to pump down the tubing and take returns to a tank from both the 7" x 9 5/8" (OA) and 3 'h" x 7" (IA) annuli independently. Also ensure that there is a way to pump down the IA or OA in case the tubing pressures up. Rig up line to flush all surface lines of cement post-job. 4. Close the OA, open the IA, and pump 20 bbls of diesel down the tubing, taking returns to tank from the IA to confirm circulation. 5. Close the IA, open the OA, and pump 20 bbls of diesel down the tubing, taking returns to tank from the OA to confirm circulation. 6. After circulation to IA and OA is confirmed, batch up AS1 cement. 7. Line up to pump cement down the tubing, taking returns from the OA. 8. Follow Pump Schedule below: i. 5 bbls fresh water spacer ahead ii. 149.5 bbl of Permafrost Cement (cement to surface in T/1/O, including 20 bbls excess) 9. After approximately 76.8 bbls of cement is pumped away, expect to see OA cement returns. Utilize mud balance to confirm good AS1 cement to surface coming from the OA. Pump contingency cement if needed to obtain good cement to surface. 10. With good OA cement to surface, open the IA, close the OA, and line up to take IA returns to tanks. i his step must be pertormed etticientiy as Permafrost Cement is thixotropic and will develop gel strength quickly when static. 11. After approximately 52.7 bbls of cement is pumped away, expect to see IA cement returns. Utilize mud balance to confirm good Permafrost Cement to surface coming from the OA. Pump contingency cement if needed to obtain good cement to surface. 12. After good OA and IA cement is seen at surface, shut down pumps and close in the IA and OA valves. 13. Close in the master valve, open up the cement clean up line, and circulate to tanks to wash up tree and surface equipment. 14. RDMO DHD: Objective: DDT 1. WOC for 48 hr or until field blend UCA chart shows cement developed 1,500 psi compressive strength. 2. RU DHD and PT equipment. 3. Perform drawdown test on tubing, IA, and OA. Wellhead Excavation / Final P&A: 1. 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). Js • • 3. Remove the well house, if still installed. 4. Bleed off T/I/O 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. .uvCC witness and photo document required. 9. Send the casing head w/stub to materials shop. Photo document. 10. Weld I/4" thick cover plate (16" O.D.) over all casing strings with the following information bead welded into the top. Moto document. AOGCC Witness required. ConocoPhillips 3H-05 PTD #: 187-077 API #: 50-103-20077-00 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. 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Iiiiiall441466:T'C,h,M.ks56AWI9I.€T 6,11 5rr 5MIT t1 34411161 *4/1 666104 44E$.+ ®moi 4644141917.COMi1,41;GI?2,.14164613;19<'4 IS 61.1611NJI*1.614 111 r'Gl-11 11311:r: "!1).'1RI13Ilw 1146111136414,NMI 3 4. 9G St's StL/T11E:)131443N14410#'RI. €1'::.11•617 Eil6.14k.A'J4?Wr1:d311.1*611 vr.t.5$1..4 44R4-4-444 1e'.,5101413113----.. 1111111111111 1,04 1.a.43.160+* 1 3'K1L.1.31&1.17)3 Js KUP OD • 3H-05 ConocoPhillhp5, Ng Well Attrib� Max Angle&MD TD Alaska Inc. Wellbore APW WI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) G.wlocae d,,,,, 501032007700 KUPARUK RIVER UNIT PROD 36.02 6,300.00 7,166.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3H-05,1/15/2018 926'22 AM SSSV:NIPPLE Last WO: 6/28/2004 42.31 9/16/1987 Vertical schematic(sons* _ Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ._.___.. Last Tag: 7,026.0 3/24/2000 Rev Reason:SET PLUG,GLV C/O pproven 10/10/2016 HANGER;31.0 8.1.... ...1111 1 asing rings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len It...Grade Top Thread CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED Casing Description OD(in) 'ID(in) Top(ftKB) Set Depth(RKB) Set Depth(TVD)... WtLen(I...Grade Top Thread SURFACE 95/8 8.921 35.2 3,454.2 3,127.2 36.00 J-55 BTC H 1 11 CasingPRODUDescriptCTIONion OD(in) ID(in) Top(ftKB) Set Depth(RKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread F l 7 6.276 34.6 7,150.0 6,186.0 26.00 J-55 BTC rr,. nln"„i Tubing Strings illiH Tubing Description String Ma...ID(in) Top(RKB) Set Depth(ft...Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection PATCH;110.0 TUBING WO 2004 3 1/2 2.992 31.0 3,147.2 2,867.3 9.30 L-80 ABM-EUE Completion Details CONDUCTOR;38.0-115.0 Nominal ID Top(ftKB) Top(ND)(RKB) Top Incl(°) Item Des Com (in) NIPPLE;534.0 - 31.0 31.0 0.04 HANGER FMC TUBING HANGER 3.500 1111 534.0 534.0 0.09 NIPPLE CAMCO DS NIPPLE,SET 6/28/04 2.875 ill 3,108.1 2,834.3 32.51 PACKER BAKER FHL PACKER 2.940 3,135.7 2,857.5 32.53 NIPPLE CAMCO DS NIPPLE NO GO 2.812 GAS LIFT;3,0523 11 I3,146.7 2,866.8 32.54 WLEG BAKER WIRELINE RE-ENTRY GUIDE 3.000 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection E-COIL TUBING 2 3/8 1.100 3,147.0 6,363.0 5,546.4 3.70 E-COIL Tubing Description String Ma...ID(in) Top(MB) Set Depth(ft.. Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING ESP 2000 5.13 6,351.0 6,557.8 5,704.7 PACKER;3,106.1 °_® Completion Details I Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl r) Item Des Corn (in) PLUG;3,120.0 ��d. 6,351.0 5,536.7 35.97 PUMP 1 CENTRILIFT ESP PUMP#83GC10000 6,377.5 5,558.1 35.94 PUMP 2 CENTRILIFT ESP PUMP#54GC8200 RBP;3,130.0 !,a.:: 6,394.9 5,572.2 35.93 INTAKE CENTRILIFT 513 SERIES INTAKE 6,396.6 5,573.6 35.92 SEAL 1 CENTRILIFT SEAL THRUST CHAMBER GTBL NIPPLE;3,135.7 6,402.1 5,578.1 35.91 SEAL 2 CENTRILIFT EXPANSION CHAMBER 6,435.2 5,604.9 35.76 MOTOR CENTRILIFT KMHU 418 MOTOR 6,469.4 5,632.6 35.61 DEPLOY CENTRILIFT ELECTROCOIL DEPLOYMENT SUB WLEG;3,146.7 I l, 6,510.0 5,665.7 35.49 PACKER BAKER FB-1 PACKER w/4"Seal Bore;Baker snap latch 4.000 &seal assembly w/guide sub landed in packer OAL=13.16' I \' [ 6,513.3 5,668.4 35.49 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000 6,532.6 5,684.1 35.50 TPAC PEROLINE TPACS VALVE 2.900 6,540.6 5,690.6 35.51 FSV PETROLINE FSV VALVE 2.500 SURFACE;35.23,454.2 ` 6,557.2 5,704.1 35.52 WLEG BAKER WIRELINE RE-ENTRY GUIDE 3.968 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) PUMP 1;6,351.0 �r.g17% Top(ND) Top Incl Miii Top(ftKB) (ftKB) (°) Des Corn Run Date ID(in) PUMP2;6,377.5 11181 ii 110.0 110.0 0.14 PATCH PATCH SURFACE CASING LEAK @ 110"BELOW 6/28/2004 3.500 OA VALVE,WITH 24"WELDED SLEEVE. INTAKE;8,384.9 '-, SEAL 1;6,396.6 IMP 2,844.3 32.52 PLUG 2.81"CA-2 PLUG(26") 9/10/2016 0.000 3,130.0 2,852.7 32.52 RBP 2 1/2 RBP SET MID ELEMENT @ 3131'RKB 10/9/2016 SEAL 2;8,402.1 'IMNS -- 6,719.0 5,835.8 35.52 FISH 1"GLV&Wobble Ring Lost Downhole 10/3/1997 10/3/1997 0.000 MOTOR;6,435.2 Could still be in hole after workover DEPLOY;6,489.4 6,720.0 5,836.6 35.52 FISH 1/2"SS Bands See WSR's 3/31/00 and 4/4/00 3/31/2000 0.000 Perforations&Slots PACKER;6,510.0 Shot Dens Top(ND) Btm(TVD) (shots/ Top(ftKB) Btm(ftKB) (RKB) (RKB) Zone Date ft) Type Com BBE;5513.3 I ' 6,760.0 6,831.0 5,869.2 5,926.9 UNIT D,C-4, 8/30/1988 8.0 IPERF 2 1/8 EnerJet;60 ph 111 C-3,3H-05 6,839.0 6,859.0 5,933.4 5,949.7 A-5,A-3,3H- 8/30/1988 8.0 IPERF 2 1/8 EnerJet;60 ph _ 05 TPAC;8,532.8 1 Mit6,869.0 6,889.0 5,957.8 5,974.1 A-2,3H-05 8/30/1988 4.0 IPERF 2 1l8 EnerJet;60 ph 6,894.0 6,914.0 5,978.1 5,994.4 A-2,A-1,3H- 12/8/1987 1.0 APERF 4"Csg Gun;120 ph FSV;6,540.8 ) 05 Mandrel Inserts WLEG;8,557.2 f�'.A St ati on Top(TVD) Valve Latch Port Size TRO Run NTop(ftKB) (ftKB) Make Model OD(in) Sery Type Type lin) (psi) Run Date Com 1 3.057.3 2,787.2 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/6/2016 FISH;6,719.0 Notes:General&Safety FISH;6,720.0 End Date Annotation 3/27/2000 NOTE:ESP WORKOVER 6/17/2000 NOTE:7"CASING DAMAGE AT 6544'SEE USIT LOG 3/26/00 IPERF;6,780.03,831.0-) 6/28/2004 NOTE:REMAINING CONTINUOUS COIL BELOW 3147'IS CORRODED,IN PIECES. 6/28/2004 NOTE:ESP WORKING,PRODUCING THRU 3.5"TBG SET DURING 2004 WORKOVER. IPERF;8,838.06,859.0 1/10/2011 NOTE:View Schematic w/Alaska Schematic9.0 IPERF;6,869.06,889.0--) APERF,6,894.0-6,914.0 PRODUCTION;34.6-7,150.0 • • Roby, David S (DOA) From: Roby, David S(DOA) Sent Thursday,January 18, 2018 9:53 AM To: 'Aleshire, Lynn';Simek,Jill Subject: RE:[EXTERNAL]Sundry application for KRU 3H-05 (PTD 187-077) Lynn, Thanks for the update. This answers all my questions. I was just doing my due diligence since the write up made it sound like sidetracking the 3H-05 was considered at one point in time and just wanted to check if that was still on the table. While the AOGCC has spent a lot of effort lately encouraging operators to abandon wells that have no future utility the flipside of that coin is we don't want to see wells that do have viable future utility P&A'd prematurely. Since nothing that could be reached from the 3H-05 location hasn't already been tapped by the recent 3H-26 laterals there's no reason to keep the 3H-05 and P&Aing the well is the proper course of action. Regards, Dave Roby (907) 793-1232 CONFIDEN1IALIIY 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 Dave Roby at(907)793-1232 or dave.roby@alaska.qov. From:Aleshire, Lynn [mailto:Lynn.Aleshire@conocophillips.com] Sent:Thursday,January 18,2018 7:48 AM To:Roby, David S(DOA)<dave.roby@alaska.gov>;Simek,Jill<Jill.Simek@conocophillips.com> Subject:RE:[EXTERNAL]Sundry application for KRU 3H-05(PTD 187-077) Dave, Jill is out of the office for the next several days. There are no targets that can be reached using 3H-05 that are not accessed by 3H-26's CTD laterals.The CTD project was much lower risk than the work required to make 3H-05 usable. I'll be happy to address any other questions you may have while Jill is out. Regards, Lynn Lynn Aleshire I Petroleum Engr 3HGS&Subsidence I ConocoPhillips Alaska 1700 G St.ATO 1348,Anchorage,AK 99501 Office:(907)265-6525 I Mobile:(907)240-2583 1 • • From:Roby,David S(DOA) [mailto:dave.roby@alaska.gov] Sent:Wednesday,January 17,2018 5:43 PM To:Simek,Jill<Jill.Simek@conocophillips.com> Cc:Aleshire, Lynn<Lynn.Aleshire@conocophillips.com> Subject:RE: [EXTERNAL]Sundry application for KRU 3H-05(PTD 187-077) Jill, Thanks for the info,that's what I thought the case was but just wanted to make sure. Are there no viable sidetrack targets using the 3H-05 motherbore and kicking off above the stuck tubing? Thanks, Dave Roby (907) 793-1232 CONFIDENflAUIY 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 Dave Roby at(907)793-1232 or dave.roby@alaska.gov. From:Simek,Jill [mailto:Jill.Simek@conocophillips.com] Sent:Wednesday,January 17,2018 5:31 PM To:Roby, David S(DOA)<dave.roby@alaska.gov> Cc:Aleshire,Lynn<Lynn.Aleshire@conocophillips.com> Subject:RE: [EXTERNAL]Sundry application for KRU 3H-05(PTD 187-077) Dave, The reserves that were being tapped by the existing 314-05 are now being drained by the recently drilled 3H-26 laterals. Sorry for ambiguous wording! Jill From:Roby,David S(DOA) [mailto:dave.roby@alaska.gov] Sent:Wednesday,January 17,2018 2:32 PM To:Simek,Jill<Jill.Simek@conocophillips.com> Subject: [EXTERNAL]Sundry application for KRU 3H-05(PTD 187-077) Jill, A quick question on the referenced sundry application. In the write up it states"RWO and rotary sidetrack projects proved unattractive when compared to coiled tubing drilling(CTD). The resources targeted by 3H-05 are now part of the pattern for the recently completed CTD 3H-26." Does this mean that the reserves that were being tapped by the existing 3H-05 are now being drained by the recently drilled 3H-26 laterals,or that the target(s)that was(were) identified for a possible 3H-05 CTD sidetrack program are being tapped by the 3H-26 laterals? Thanks in advance. Regards, 2 Dave Roby Sr.Reservoir Engineer Alaska Oil and Gas Conservation Commission (907) 793-1232 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 Dave Roby at(907)793-1232 or dave.robyCalaska.goy. 3 WELL HISTORY FILE COVER PAGE XHVZS This page identifies oversize material and digital information available for this individual Well History file and weather or not it is available in the LaserFiche file. Please insure that it remains as the first page in this file. 1Ý7 tJ 77 Well History File # Digital Data 0 CD's - # - 0 DVD's - # - 0 Diskettes - # - Added to LaserFiche File 0 Yes 0 No 0 Yes 0 No 0 Yes 0 No Oversized Material Added to LaserFiche File 0 Maps # - 0 Mud Logs # - 0 Other # - 0 Yes 0 No 0 Yes 0 No 0 Yes 0 No General Notes or Comments about this file. If any of the information listed above is not available in the LaserFiche file you may contact the Alaska Oil & Gas Conservation Commission to request copies. Please call Robin Deason at (907) 793-1225 if you have any questions or information requests regarding this file. • • ConocoPhillips Alaska P.O. BOX 100360' . t' ' ANCHORAGE, ALASKA 99510- 0360 IAN 0 4 2011 December 30 2010 wlo 0m+ Coos. Cr- ;Sion a=�rje ''iRG Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 l S 7 7 7 Anchorage, AK 99501 5LANNED JAN H Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The corrosion inhibitor /sealant was pumped December 21 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907 - 659 -7043, if you have any questions. Sincerely, 4 011, Perry Kle 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 12/30/2010 3G -10 & 3H -05 PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement _ pumped cement date inhibitor sealant date ft bbls ft gal 3G -10 50103201340000 1900840 SF n/a 25" n/a 2.8 12/21/2010 3H-05 50103200770000 1870770 16" n/a 16" Na 4.7 12/21/2010 (...)10 :t~,Qt=\ r:;-, '-,r,:J/;"ð-''1\ l'::-:.:1J,:.. :' !,',::;J l[(!l-J!; ,'I ".. \~.: i I ,. i~ \, !; I L" '\ '> ! ¡ ,.: (' : \ :: ! !'uW rù~ i' ; '~',\ ¡: ::1 ..~~~J LJ ùaJ' \:~ :'"1~ ;~~::J '-I r') {¡':."i\ ;-L {n" ~ (" '~'J)' r~~:7':' I ! , i in ! i " ;', .n , i n i :1 i ',i .' 'II ,¡'H'", 'I \1 '\ \,." ,'" I J .'. ~ ',I I' ::1'.\' ", : I ! r i ,:U "j ! li.~ \, ,'::>""'\ ! :'\\ ¡¡~ ¡¡/'''''H!L /1 \'\:id):¡il\,\ ..s:Jf¿) ~..¡I..:"...:,¡ '-i~ 'I\~ U '~~ ....J ~\....j. ) A"~ASIiA. ORAND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 July 13, 2005 Ms. M. J. Loveland Problem Well Supervisor ConocoPhillips Alaska P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 3H-05 PTD 187-077 Sundry 304-244 SCJ.\NNED JUL 1 i:l2005 Dear Ms. Loveland: The Commission received your letter requesting relief from the requirement to perform quarterly flowline inspections on the subject well. The requirement for quarterly flowline inspections was established while the well was producing via the annulus. The well employed a coil tubing deployed electric pump and the well fluid was pumped up the coil x casing annulus. A partially successful workover was performed about a year ago according to Sundry 304-244. It was not possible to retrieve all of the coil tubing and the well was completed with a standard gas-lift completion, although the packer is only set at about 3100' md. Flowline inspections have been performed since the workover and have not indicated any change in the condition of the flowline. Since the well is now producing with a normal completion in place, it is appropriate to grant the relief requested. Accordingly, the requirement to perform quarterly flowline inspections on Kuparuk River Unit 3H-05 is removed. Sincerely, , i , ('\ 1Y2 Æt-~ (~ Thomas E. Maunder, PE " Sr. Petroleum Engineer ) ) ConocJP'hillips Alaska RECEIVED JUL 1 2 2005 Alaska Oil & Gas Cons C '. Anch . omm'ss,on orage P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 9, 2005 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Subject: Kuparuk We113H-05 (PTD 187-077, Sundry 304-244) Request for Relief of Quarterly Flowline Inspection Requirement Dear Mr. Maunder: ConocoPhillips requests relief from the Quarterly Flowline Inspection requirement stated in the Conditions of Approval in Sundry 304-244 on well 3H -05 (PTD 187-077). The original flowline inspection requirement was adopted when the well was produced annularly due to a failed Electrocoil (ETC) ESP pump. Approximately one year ago, most of the ETC completion (except for a remaining fish) was removed with a workover and replaced with a standard tubing and packer completion. (See attached schematic). Since the workover, 3H-05 has been produced with gas lift in the standard direction of flow - gas down the inner annulus (IA) and production up the tubing. The quarterly flowline inspection log reports a worst case of 16% wall loss over the last five years and no additional wall loss within this last year while on standard gaslift production. (See attached Inspection Log). With relief from the quarterly flowline inspection requirement, flowline erosion would still be monitored on 3H-05 with Kuparuk's standard coupon erosion/corrosion survey program. Please call Marie McConnell or me at 659-7224 if you have any questions. Sincerely, U ~t= Problem Well Supervisor Attachments la,',: ConocQPhUUps Alaska, Inc~ ~ API: 501032007700 SSSV Type: NIPPLE Annular Fluid: Reference Log: 31' RKB Last Tag: 7026 Last Tag Date: 3/24/2000 Casir1gStr'ing'.ALLSTRINGS . Description CONDUCTOR SURF CASING PROD CASING Tùbingstring>~ TUSING· Size Top 3.500 0 2.375 3248 4.500 6510 Þèrtå.rätlë)ns..'$ul'r'lmàry Interval TVD 6760 - 6831 5869 - 5927 TUBING (0-3147. 00:3,500. 10:2,992) COIL (3248-6363, 00:2.375, 10:1,939) ESP (6351-6510. 00:5,130) TUBI NG (6510-6557, 00:4,500, 10:3,958) 1" GLV Wobble Ring (6719-6720, 00:1,000) Perf (6760-6831 ) Perf (6839-6859) Perf (6869-6889) Perf (6894-6914 ) r~,,··.·.:::,'::.11 ~i ""':::"1:"..1 ~ I :I~_ ~ í ~ ~ ~ ~I~ ¡ r~~11 ,(,:..::''' . ¡ ~ I ¡ ~ ¡ ¡ ~ ~ ) ',',' j' " ¡ r "':""','"""""",""'..",',,,",,·,'.,·"',',,,:.,.::::,:::'1 ~ ~:~:::':':~:::::C::':::::::':':~::: ~ ::':'.~'."::'::':':':'::::' ¡ ,:;:':::-:-:-:-:-:-:-:-:-::-::-/ ~ :;::::; ~ ,·.","','·,1·".··»:1 ~ ",.,';",',:, i ,,', ,'.;,;. ~ ~ ~ ~ ~ ~ k +- +- t +- ~ += t= -¡ ---+- -+ ---+ -+ -+- -+ -t- ---+- -+- -+ -t- -+ -+ -+- -t- 1.,',,' " t 6839 - 6859 5933 - 5950 6869 - 6889 5958 - 5974 6894 - 6914 5978 - 5994 $asLiftMål'ÌetrelšNalves : .. St MD TVD Man Man Type V Mfr V Type Mfr 1 3052 2787 CAMCO MMG OV Other..(þlijtJ~;·.é4uip.,..etc.).·.;.ORIGINAL.ÇOM PLETION Depth TVD Type 6351 5537 ESP 6513 5668 SBE 6532 5684 TPAC 6541 5691 FSV 6557 5704 WLEG Othè,,··(þl@s,..eqµip.,.étc.).;.WORKOVE.R.JEWELRY Depth TVD Type 31 31 HANGER 533 533 NIP 3108 2834 PACKER 3136 2858 NIP 3146 2866 WLEG ) 6510 PACKER 5666 ) KRU 3H-05 Well Type: PROD Orig Completion: 9/16/1987 Last W/O: 6/28/2004 Ref Log Date: TD: 7166 ftKB Max Hole Angle: 36 deg (éì! 6300 Angle (ã2 TS: 36 deg (éì! 6764 Angle (éì! TD: 36 deg (éì! 7166 Rev Reason: Set OV Last Update: 8/21/2004 Size 16.000 9.625 7.000 Top o o o Grade H-40 J-55 J-55 Thread TVD 115 3127 6186 Wt 62.50 36.00 26.00 Bottom 115 3454 7150 Bottom 3147 6363 6557 TVD 2867 5546 5704 L-80 Wt 9.30 3.70 12.60 Grade L-80 Thread EUE8rdMod Continuous CT Buttress Zone UNIT D,C-4,C-3 A-5,A-3 A-2 A-2,A-1 Ft SPF 71 8 Date Type Comment 8/30/1988 IPERF 21/8 EnerJet; 60 ph Status 20 20 20 8 8/30/1988 IPERF 2 1/8 EnerJet; 60 ph 4 8/30/1988 IPERF 2 1/8 EnerJet; 60 ph 1 12/8/1987 APERF 4" Csg Gun; 120 ph VOD Latc h Port TRO Date Vlv Run Cmnt 1.5 RKP 0.188 0 7/2/2004 Description Electrocoil ESP Pump & Motor Assembly w/2,375" Deployment Sub PUMP INSTALLED BELOW MOTOR ASSEMBLY Baker FB-1 Packer, w/4" Seal Bore; Baker snap latch & seal assembly w/guide sub landed in packer OAL=13.16' Baker 80-40 Petroline TPACs valve Petroline FSV Valve ID 0.000 4.000 4.000 2.900 2.500 3,968 Description ID 2,992 2.875 2.940 2.812 3,000 FMC TUBING HANGER CAMCO 'DS' NIPPLE, set 6/28/04 BAKER GHL (#781-20-3595) RETRIEVABLE PACKER set 6/28/04 CAMCO 'DS' NIPPLE set 6/28/04 BAKER VVlRELlNE GUIDE Comment Lost Downhole Could still be in hole after workover See WSR's 3/31/00 and 4/4/00 Depth Description 6719 1" GLV & Wobble Ring 6720 1/2" SS Bands Général Nøte$ Date Note 6/17/2000 7" CASING DAMAGE AT 6544' SEE USIT LOG 3/26/00 6/28/2004 REMAINING CONTINUOUS COIL BELOW 3147' IS CORRODED, IN PIECES. ESP STILL \/\ORKING, PRODUCING THROUGH 3.5" TUBING SET DURING 2004 \/\ORKOVER. 7/20/2004 PATCH SURFACE CASING LEAK (éì! 110" BELOWOA VALVE, WITH 24" WELDED SLEEVE. ) ) 3H-05 Special Inspection Request Log DS3H 3H-05 Quarterly Inspection erosion survey due to AOGCC sundry agreement B, I, N - (B - baseline inspection, I - Increase in % wall loss, N - No change from previous inspection) Date of #of Worst Damage Inspection B,I,N Case Wall Comments Inspection Locations Loss % Grade 05/12/05 9 N 16% B No changes noted from previous inspection 02/12/05 9 N 16% B No changes noted from previous inspection 11/24/04 9 N 16% B No changes noted from previous inspection Quarterly Inspection/14 mils increase in erosion to Manifold Piping @ corrosion 10 38. New baseline inspection performed on riser 08/29/04 9 16% B replaced in July 2004 (No Damage) Quarterly Inspection / slight increase of 10 mils to backside of 05/17/04 9 I 12% B Production Header 02/24/04 9 N 12% B Quarterly Inspection 11/25/03 9 N 12% B Quarterly Inspection 08/23/03 9 N 12% B Quarterly Inspection OS/23/03 9 N 12% B Quarterly Inspection Quarterly Inspection slight increase erosion on well house riser 02/22/03 9 I 12% B bottom elbow 11/23/02 9 N 0% A Quarterly Inspection 07/18/02 9 N 0% A Quarterly Inspection 03/24/02 9 N 0% A Start quarterly inspection 01/18/01 9 B 0% A Base Line Inspection Re: 3H-05 (PTD 187-077; Sundry 304-244) ) -) Subject: Re: 3H-05 (PTD 187-077; Sundry 304-244) From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Fri, 08 Jul2005 10:37:33 -0800 To: NSK Problem Well Supv <n1617@conocophillips.com> MJ, There is no issue keeping the well on line. As noted, although it was not possible to clean out the well as planned the flow direction has been restored to "standard". We don't require special inspections on all those other wells with standard flow and that now applies here. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: Tom, Thanks, I'll get a letter in the mail this weekend. Is it ok to leave the well onlíne in the mean time? The Sundry expired while we had fill in coverage during my vacation last week. MJ -----Original Message----- From: Thomas Maunder [mailto:tom. maunder@admín.state.ak.us] Sent: Friday, July 08, 2005 10:19 AM To: NSK Problem Well Supv Subject: Re: 3H-05 (PTD 187-077; Sundry 304-244) Hi MJ, I went back and looked at the file. I did write in the flowline inspection requirement, but in retrospect I can't see a reason why. You are correct, the flow is no longer reversed so there isn't the same concern as before. Also in both cases, there isn't a "dead leg" since the entire fluid column is moving. I think that is good news for the well's casing, although it doesn't explain why the electro coil had the problems it did. I think you all should send in a letter asking to be relieved of the inspection requirement. I presume that there still would be some "standard" inspection done or coupons used to assess any corrosion, but it is appropriate to remove the "special" requirement. I look forward to the letter. Tom Maunder, PE AOGCC sr:"jl:NNt=i) JU·L 1 ~~~ 2005 ~~~,_ " ¡. , t;;8.-,' ,J.. ,."..'" ~ " NSK Problem Well Supv wrote: Tom, 3H-05 (PTO 187-077; Sundry 304-244) was worked over last year to pull the failed electro coil completion (ETC) and run a standard GL completion in it's place. The end result of the workover included leaving part of the ETC in the well and setting the production packer at -3200'. The well has been producing on standard gas líft since the workover with Sundry 304-244 (which expired June 30,2005). The only requirement the Sundry had was a carry over from when the well was gas lifted in the reverse direction with the ETC in the ground, - quarterly flowline inspections. The flowline inspections have resulted in no changes since the workover one year ago. ConocoPhillips would líke to pursue canceling the Sundry 304-244 and operating the well as a normal gas lifted producer rather than renewing. Please advise if this is possible and the required method in doing so. 10f2 7/18/2005 6:44 AM 3H-05 Quarterly Erosion Survey Inspection 112404 ) ) Subject: 3H-05 Quarterly Erosion Survey Inspection 112404 From: NSK Problem Well Supv <n1617@conocophillips.com> Date: Mon, 29 Nov 2004 15:29:01 -0900 To: tom _ maunder@admin.state.ak.us \ &''1-·Ù "{.! Tom, Attached is the quarterly flowline inspection for 3H-05 (PTD# 187-077). Please let me know if you have any questions MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 ~NED OCT 3 1 Z005 -----Original Message----- From: NSK Carr DS Coord Sent: Thursday, November 25, 2004 1:24 PM To: CPF3 Prod Supv Cc: CPF3 Prod Engrs; CPF3 Fac Engr; CPF3 DS Lead Techs; CPF3 Control Room; NSK Carr Insp Piping; NSK Carr Chem&Monitoring; NSK Carr Vessel Insp; NSK DS Fac Engr; NSK Engr&Corr Supv; NSK Problem Well Supv Su bject: 3H-05 Quarterly Erosion Survey Inspection 112404 Jeff/Randy, On 11/24/04 we completed an erosion survey inspection on well 3H-05. This inspection is being performed on a quarterly inspection frequency as originally requested by Jerry Dethlefs (NSK Problem Well Supv) as part of a Sundry approval agreement with the AOGCC. Originally this inspection was scheduled to be performed annually over concerns of possible increases in erosion damage due to high solids production through the piping and chokes. The results are as follows: Action Items: Remove tape wrap from lower elbow on the riser so Ultrasonic inspection may be pe rformed. Damage Summary: No increases or changes were noted on this well from our previous inspection on 8/27/04. Our inspection consisted of Ultrasonic inspection of the S-riser, Choke, and manifold piping. For previous inspection history and results please refer to the attached Inspection Log. We would also like to note that the lower elbow on the riser has been tape wrapped and could not be inspected by UT. This tape wrap should be removed from the elbow to l' downstream so we can resume Ultrasonic monitoring of erosion to the elbow during our next scheduled inspection. Future Inspection Plans: We will continue to monitor this well under the quarterly inspection frequency as agreed to with the AOGCC until notified otherwise by Operations. lof2 11/30/20047:37 AM 3H-05 Quarterly Erosion Survey Inspection 112404 ) ) All film and UT data is on file with corrosion and is available for your viewing. If you have any questions contact Spencer/George at ext. 7209 or AI Dahlquist at ext 7773. «3H-05 Quarterly Inspection Log.xls» Regards, George Foley/Spencer Morningstar Kakivik Asset Management Lead Inspection Coordinators NSK-39 n1016@conocophillips.com ext 7209 Content-Description: 3H-05 Quarterly Inspection Log.xls Quarterly Inspection Log.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 20f2 11/30/20047:37 AM 3H-05 Special Inspection Request Log Ds3H 3H-05 Quarterly Inspection erosion survey due to AOGCC sundry agreement 8, I, N - (8 - baseline inspection, I - Increase in % wall loss, N - No change from previous inspection) Date of Inspection # of Worst I t· 8 INCase Wall Damage nspec Ion " Grade Locations Loss % Comments 01/18/01 9 03/24/02 9 07/18/02 9 11/23/02 9 02/22/03 9 OS/23/03 9 08/23/03 9 11/25/03 9 02/24/04 9 05/17/04 9 08/29/04 9 11/24/04 9 B N N N 0% A 0% A 0% A 0% A 12% B 12% B 12% B 12% B 12% B 12% B 16% B 16% B I N N N N I N - Base Line Inspection Start quarterly inspection Quarterly Inspection Quarterly Inspection Quarterly Inspection slight increase erosion on well house riser bottom elbow Quarterly Inspection Quarterly Inspection Quarterly Inspection Quarterly Inspection Quarterly Inspection / slight increase of 10 mils to backside of Production Header Quarterly Inspection/14 mils increase in erosion to Manifold Piping @ corrosion 10 38. New baseline inspection performed on riser replaced in July 2004 (No Damage) No changes noted from previous inspection - ",- cÞ .J í o J ~ RE: OOA Cement Top-off's ) ') ~~ f\D \~ Subject: RE: OOA Cement Top-offs From: NSK Problem Well Supv <nI617@conocophillips.com> Date: Mon, 27 Sep 2004 16:45 :56 -0800 To: Thomas Maunder <tom _ maunder@admin.state.ak.us> Tom, There is a couple reasons for the excess cement. The depth is calculated by a string, so if that hangs up on any debris in the OOA, it may give us a false depth. Also since there is no way to circulate, your right, we rely on the hose to fill up the OOA. We just wanted to make sure we had enough cement to fill to surface. Brad Gathman Problem Well Supervisor 907-659-7224 -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Monday, September 27, 2004 9:44 AM To: NSK Problem Well Supv Subject: OOA Cement Top-offs ~CANNE[) OCT 0 2: 2004 MJ and Brad, I was looking at the packet recently sent on the 6 wells that had the OOAs topped-off. It appears that the pumped volumes varied anywhere from 1.3 to 2.2 times calculated. Was XS cement circulated to assure that the OOA was full?? That would seem prudent, since it may not have been possible to get the hose all the way down. Thanks in advance for your reply. Tom Maunder, PE AOGCC ~"G -0 d C <è.. ~~. -"",,)0 \ ~ \¡"--"..~ ~ Sö.~Q- \ \ ~ d~-~~ \ ~~-O(O '~~-O(ô ~ \--0,\ ?'\-\-o5' \ l 0 \ '- ¥ r d~d \, 'ì \ ~ <r 'fO 1 of 1 10/1/2004 8:28 AM FW: 3H-05 Quarterly Erosion Survey Inspection ") } $~~ject:: FW:3~~Q5iq~:~~i'îY~~.9Sio~:·SUtYeY~$peç1i9~.. ...... ...............:..... J?r?~:.·...1fS.~.tr~bl{þ11).··VJ.yll....~p~~.·.~~.~·?~..?@.c.onocopl1i11ips;Q?rri?··. Ie: rue;n$e ig~M ·l'~(i:~i!L;î~~~, Tom, Here is the latest flowline inspection data for 3H-05 as inspected on 8/29/04. The riser was replaced after the 7/2004 RWO, so there is a new baseline now. Looking thru our files, it appears these reports are submitted electronically. Please let me know if this isn't sufficient as I haven't sent one of these in before. Please let me know if you have any questions. Marie McConnell Problem Well Supervisor 659-7224 -----Original Message----- From: NSK Corr DS Coord Sent: Monday, August 30, 2004 10:36 AM To: CPF3 Prod Supv Cc: CPF3 Prod Engrs¡ CPF3 Fac Engr¡ CPF3 DS Insp Piping¡ NSK Corr Chem&Monitoring¡ NSK Corr Well Supv Subject: Lead Techs¡ CPF3 Control Room; NSK Corr Vessel Insp¡ NSK DS Fac Engr¡ NSK Problem RE: 3H-05 Quarterly Erosion Survey Inspection Jeff/Randy, We apologize for the confusion as your e-mail regarding the replacement of the riser was missed between shift changeout. The data for the old riser should have been moved to the repaired section of our Corrosion Database and a new "baseline" inspection performed on the replacement riser. This has now been remedied and last night I had our crews perform baseline radiographic and ultrasonic inspections on the riser and there is no damage to the recently replaced riser. The erosion increase of 14 mils to the manifold piping @ corrosion ID 38 is valid as none of the manifold piping was replaced after the workover. We will continue to monitor this well under the quarterly inspection frequency as agreed to with the AOGCC until notified otherwise by Operations. For previous inspection history and results please refer to the attached Inspection Log. Regards, George Foley/Spencer Morningstar Kakivik Asset Management Lead Inspection Coordinators NSK-39 nl016@conocophillips.com ext 7209 . '>ijÜ!» SCN'\NEü NO\l 0 1 ¡. «3H-05 Quarterly Inspection Log.xls» -----Original Message----- From: CPF3 Prod Supv Sent: Sunday, August 29, 2004 9:09 AM To: NSK Corr DS Coord Cc: CPF3 Prod Engrs¡ CPF3 Fac Engr¡ CPF3 DS Insp Piping¡ NSK Corr Chem&MOnitoring¡ NSK Corr Well Supv Subject: Lead Techs¡ CPF3 Control Room¡ NSK Corr Vessel Insp¡ NSK DS Fac Engr¡ NSK Problem RE: 3H-05 Quarterly Erosion Survey Inspection All: Disregard the note below. new riser was installed. therefore erroneous. 3H-05 riser etc. was replaced after the 3H-05 workover, and a The data below is relative to the old riser's readings, and is George will take some additional readings since we need new baseline data, and will send out a revised report. Bottom line, we don't think we have any erosional increases. 10f2 11/30/20049: 14 AM FW: 3H-05 Quarterly Erosion Survey Inspection ) ìt You can discard the note below, and a new report should be forthcoming in a day or so. thanks, Randy Black/Jeff Huber CPF3 Production Supervisors n1175 659-7682 -----Original Message----- From: NSK Corr DS Coord Sent: Saturday, August 28, 2004 5:56 PM To: CPF3 Prod Supv Cc: CPF3 Prod Engrs¡ CPF3 Fac Engr¡ CPF3 DS Lead Techs¡ CPF3 Control Room¡ NSK Corr Insp Piping¡ NSK Corr Chem&Monitoring¡ NSK Corr Vessel Insp¡ NSK DS Fac Engr¡ NSK Engr&Corr SUpV¡ NSK Problem Well Supv Subject: 3H-05 Quarterly Erosion Survey Inspection Jeff/Randy, On 8/27/04 we completed an erosion survey inspection on well 3H-05. This inspection is being performed on a quarterly inspection frequency as originally requested by Jerry Dethlefs (NSK Problem Well Supv) as part of a Sundry approval agreement with the AOGCC. Originally this inspection was scheduled to be performed annually over concerns of possible increases in erosion damage due to high solids production through the piping and chokes. The results are as follows: Action Items: Remove tape wrap from lower elbow on the riser so Ultrasonic inspection may be performed. Damage Summary: A few increases due to erosion were discovered in the riser and manifold piping during our inspection. A 25 mil increase was discovered at corrosion ID 9 (top tee on the riser) which now displays> 16% wall loss by UT. A 14 mil increase due to erosion was discovered at corrosion ID 38 (crossover tee to test & production) which now displays <10% wall loss by UT. No other changes were noted on this well from our previous inspection on 5/17/04. Our inspection consisted of Ultrasonic inspection of the S-riser, Choke, and manifold piping. For previous inspection history and results please refer to the attached Inspection Log. We would also like to note that the lower elbow on the riser has been tape wrapped and could not be inspected by UT. This tape wrap should be removed from the elbow to l' downstream so we can resume Ultrasonic monitoring of erosion to the elbow during our next scheduled inspection. Future Inspection plans: We will continue to monitor this well under the quarterly inspection frequency as agreed to with the AOGCC until notified otherwise by Operations. All film and UT data is on file with corrosion and is available for your viewing. If you have any questions contact Spencer/George at ext. 7209 or Al Dahlquist at ext 7773. Regards, George Foley/Spencer Morningstar Kakivik Asset Management Lead Inspection Coordinators NSK-39 nlO1.6@conocophillips.com ext 7209 « File: 3H-05 Quarterly Inspection Log.xls » Content-Description: 3H-05 Quarterly Inspection Log.xls 3H-05 Quarterly Inspection Log.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 20f2 11/30/20049: 14 AM . Conoc~illips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 15, 2004 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 RECEIVED SEP 1 7 2004 Alaska Oil & Gas Cons. Commission Anchorage Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the'Kupâruk and Tam fields. Each of these wells was found to have a void in the conductor by surface casing annulus. The voids were filled with cement to the top of the circulation ports in the conductor, or in some cases holes were cut in the conductor to facilitate fill-up. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The top-fill operation was completed on September 14, 2004. Dowell-Schlumberger batch- mixed Arctic Set I cement to 15.8 ppg in a blender tub. The cement was placed in the conductor from the bottom-up via a hose ran to the bottom of the void. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volume used on each conductor. Note that in most cases these wells<bave been previously reported as having surface casing leaks and have either been repaired by ~xcavation and patching or injection of sealant material. Please call Marie McConnell or me at 907-659-7224, if you have any questions. Sincerely, çz~ _1'C~ Jerry Dethlefs ConocoPhillips Problem Well Supervisor Attachment SCANNED NO\ll 5 2004 ConocoPhillips Alaska, Inc. Surface Casing by Conductor Annulus Cement Top-off (~1:tJ'7-1 Kuparuk and Tarn Fields September 14, 2004 WELL PTD# SERVICE CEMENT TOP VOLUME REASON NAME TYPE ft Bbls . 2G-02 1841210 Producer 82 14.5 SC leak @ 321 previously sealant repaired 2N-341 1981030 Producer 3 0.5 Wobbly tree 38-06 1850760 Producer 8 2 Post SC leak patch repair; Sundry 304-225 3F-06 1852440 Producer 40 11.8 SC leak @ 641 previously sealant repaired 3F-09 1852700 Producer 17 3.9 SC leak @ 241 previously sealant repaired 3H-05 1870770 Producer 8 2 Post SC leak patch repair; Sundry 304-228 All cement pumped is Arctic Set I 15.8 PPG Cement This report is submitted in substitution for Sundry 10-404, Report of Sundry Operations . SCANNED NOVl 5 2004 NSK Problem Well Supervisor TUBING (0-3147, OD:3.500, 10:2.992) COil (3248-6363, OD:2.375, 10:1.939) ESP (6351-6510, OD:5.130) TUBING (6510-6557, OD:4.500, 10:3.958) 1" GlV Wobble Ring (6719-6720, OD:1.000) Perf (6760-6831 ) Perf (6839-6859) Perf (6869-6889) Perf (6894-6914) ) ConocoPhilUps Alaska, Inc. 1, '¡If,- KRU 3H-05 3H-05 API: 501032007700 SSSV Type: NIPPLE Annular Fluid: Reference Log: 31' RKB Last Tag: 7026 Last Tag Date: 3/24/2000 Casing String. ALL STRINGS Description CONDUCTOR SURF CASING PROD CASING Tubing String. TUBING Size Top 3.500 0 2.375 3248 4.500 6510 Peñorations Summary Interval TVD 6760 - 6831 5869 - 5927 Angle ~ TS: 36 deg ~ 6764 Angle ~ TO: 36 deg ~ 7166 Rev Reason: Set OV Last Update: 8/21/2004 Well Type: PROD Orig Completion: 9/16/1987 Last W/O: 6/28/2004 Ref Log Date: TO: 7166 ftKB Max Hole Angle: 36 deg ~ 6300 Size Top Bottom TVD Wt Grade Thread 16.000 0 115 115 62.50 H-40 9.625 0 3454 3127 36.00 J-55 7.000 0 7150 6186 26.00 J-55 Bottom TVD Wt Grade Thread 3147 2867 9.30 L-80 EUE8rdMod 6363 5546 3.70 Continuous CT 6557 5704 12.60 L-80 Buttress Status Ft SPF Date Type Comment 71 8 8/30/1988 IPERF 2 1/8 EnerJet; 60 ph Zone UNIT D,C-4,C-3 A-5,A-3 A-2 A-2,A-1 20 20 20 8 8/30/1988 IPERF 2 1/8 EnerJet; 60 ph 4 8/30/1988 IPERF 2 1/8 EnerJet; 60 ph 1 12/8/1987 APERF 4" Csg Gun; 120 ph VOD Latch Port TRO Date Vlv Run Cmnt 1.5 RKP 0.188 0 7/2/2004 6839 - 6859 5933 - 5950 6869 - 6889 5958 - 5974 6894 - 6914 5978 - 5994 Gas Lift MandrelsNalves St MD TVD Man Man Type V Mfr V Type Mfr 1 3052 2787 CAMCO MMG OV Other (plugs, equip., etc.) - ORIGINAL COMPLETION Depth TVD Type 6351 5537 ESP ID 0.000 6510 5666 PACKER Description Electrocoil ESP Pump & Motor Assembly w/2.375" Deployment Sub PUMP INSTALLED BELOW MOTOR ASSEMBLY Baker FB-1 Packer, w/4" Seal Bore; Baker snap latch & seal assembly w/guide sub landed in packer OAL=13.16' Baker 80-40 Petroline TPACs valve Petroline FSV Valve 4.000 2.900 2.500 3.968 4.000 6513 5668 SBE 6532 5684 TPAC 6541 5691 FSV 6557 5704 WLEG Other (plugs, equip., etc.) - WORKOVER JEWELRY Depth TVD Type 31 31 HANGER 533 533 NIP 3108 2834 PACKER 3136 2858 NIP 3146 2866 WLEG Fish - FISH Depth Description 6719 1" GLV & Wobble Ring 6720 1/2" SS Bands General Notes Date Note 6/17/2000 7" CASING DAMAGE AT 6544' SEE USIT LOG 3/26/00 6/28/2004 REMAINING CONTINUOUS COIL BELOW 3147' IS CORRODED, IN PIECES. ESP STILL WORKING, PRODUCING THROUGH 3.5" TUBING SET DURING 2004 WORKOVER. 7/20/2004 PATCH SURFACE CASING LEAK ~ 110" BELOW OA VALVE, WITH 24" WELDED SLEEVE. Description ID 2.992 2.875 2.940 2.812 3.000 FMC TUBING HANGER CAMCO 'OS' NIPPLE, set 6/28/04 BAKER GHL (#781-20-3595) RETRIEVABLE PACKER set 6/28/04 CAMCO 'OS' NIPPLE set 6/28/04 BAKER WIRELlNE GUIDE Comment Lost Downhole Could still be in hole after workover See WSR's 3/31/00 and 4/4/00 ;' ~i ¡¡="[- \\1 0... \3 .~"" ? 0 [I" SCANn:1r.::> ) 1'!' 1. ~ '- J ¡-f FW: 3H-05 surface casing repair 10-404 is in the l1:\ai1. ) ) Subject: FW: 3H-05 surface casing repair 10-404 is in the mail. From: NSK Problem Well Supv <nI617@conocophillips.com> Date: Thu, 22 Jul 2004 07:42:48 -0800 To: "Tom Maunder AOGCC (E-mail)..<tom_maunder@admin.state.ak.us> Tom, I was just looking over the 10-404 I put in the mail last night and noticed that the date on the MITOA form attached has a typo: 7-21-05. It has already left the mail room, so I would appreciate it if you would pencil in the correct date of 7-21-04 when they arrive in your office. Thanks, Marie -----Original Message----- From: NSK Problem Well Supv Sent: Wednesday, July 21, 2004 11:35 PM To: Tom Maunder AOGCC (E-mail) Subject: 3H-05 surface casing repair 10-404 is in the mail. Tom, 3H-05 surface casing repair has been completed (this is the one Lou come over on Sunday and photographed the damage.) The MITOA passed this morning. I just finished the sundry and put it in the mail. I included several photos, one set in color. Marie. SCANNED NOV 0 12005 1 of 1 11/30/20049: 11 AM Re: 3h-05 SURF CASING PIX It e \~l-CJ 1'\ Subject: Re: 3h-05 SURF CASING PIX From: Lou Grimaldi <Iou _grimaldi@admin.state.ak.us> Date: Mon, 19 Jul2004 09:15:25 -0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us> CC: Jim Regg <jimJegg@admin.state.ak.us> Hi Tom, Yes, to all ? The casing was cleaned up nicely when I got there, Marie has been good to work with. There was evidence of cement directly below the cut-off point (conductor x surf). Marie has some good pictures of the repairs on the last well. I called and left her a message to send you those pix. Lou Thomas Maunder wrote: Hi Lou, I presume that the surface casing was cleaned off prior to you getting to see it. Was there any discussion of how it looked once they got it uncovered?? Could you see a TOC between the conductor and surface casing?? I do not see on in the pictures. Tom Lou Grimaldi wrote: Hi Jim/Tom, I went out and looked at 3H-05 last night. Looks like they dodged a bullet on this one. Lou C'\ I\.. ,f ~\<tc...\~,",~ú CJ?\'>'t~~<? ~~roû c"'- ~ \ \ ~ ð"'\--JQ 1 of 1 11/30/2004 9:04 AM (JPEG Image, 64Qx480 pixels I of I (JPEG Image, FW: 3H-05 Quarterly Inspection Log.xIs ) ) Subject: FW: 3H-05 Quarterly Inspection Log.xls From: NSK Problem Well Supv <n 1617@conocophillips.com> Date: Thu, 01 Jul2004 16:46:00 -0800 To: "Tom Maunder AOGCC (E-mail)..<tom_maunder@admin.state.ak.us> Tom: This attachment has a summary of the flowline inspections to date on 3H-05. You could include this with my previous data. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7224 -----Original Message----- From: CPF3 Prod Engrs Sent: Thursday, July 01, 2004 3:14 PM To: NSK Problem Well Supv Subject: 3H-05 Quarterly. Inspection Log.xls «3H-05 .xls» Quarterly Inspection Content-Type: application/vnd.ms-excel Content-Encoding: base64 1 of 1 11130/2004 9:03 AM 3H-05 Special Inspection Request Log DS3H 3H-05 Quarterly Inspection erosion survey due to AOGCC sundry agreement 8, I, N - (8 - baseline inspection, I - Increase in % wall loss, N - No change from previous inspection) Date of #of Worst Damage Inspection 8, I, N Case Wall Comments Inspection Locations Loss % Grade 01/18/01 9 B 0% A Base Line Inspection 03/24/02 9 N 0% A Start quarterly inspection 07/18/02 9 N 0% A Quarterly Inspection 11/23/02 9 N 0% A Quarterly Inspection Quarterly Inspection slight increase erosion on well house riser 02/22/03 9 I 12% B bottom elbow OS/23/03 9 N 12% B Quarterly Inspection 08/23/03 9 N 12% B Quarterly Inspection 11/25/03 9 N 12% B Quarterly Inspection 02/24/04 9 N 12% B Quarterly Inspection Quarterly Inspection / slight increase of 10 mils to backside of 05/17/04 9 I 12% B Production Header ~ ',-' Re: 3H-05 Rig Workover Procedure ) ) Subject: Re: 3H-05 Rig Workover Procedure From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Wed, 05 May 2004 14:47:29 -0800 To: "Worthington, Aras J" <Aras.J.Worthington@conocophillips.com> Thanks Aras. This will do. Only request is if you or your associates send in more sundries for workovers, please include a one line procedure like this. Tom Maunder, PE AOGCC Worthington, Aras J wrote: Tom, As per our discussion, here is a very basic step-by step procedure. Let me know if you need more information. Thx, Aras «3H-05 RWO Procedures.doc» 1 of 1 11130/2004 9:00 AM ) ) 3H-05 Rig Workover Procedure Pre-Ria Work: 1. RU pump, KilllA/7" x CT annulus wi brine. 2. ND Tree, NU Mstr. Valve. Ria Work 1. MIRU Workover Rig. 2. Verify well (7" annulus & top hat) is dead. If not bullhead well to appropriate KWF. 3. NU BOPS. Test the BOPE to 4000 psi. 4. Pull CT hanger, CT & ESP from packer. Note condition of CT continuously. If CT is corroded, consider running USIT log in corrosion mode across 7" casing. 5. After ESP is recovered: 6. RU EL & run USIT log across all of 7" in corrosion mode (if applicable; see step 4). 7. PU completion tbg & run test packer into well. Set at same depth as proposed new completion packer. Test 7" to 2500 psi or minimum pressure required if USIT log indicates corroded casing. 8. Test 9 518" casing (OA) to 1800 psi. 9. Run storm packer, change-out wellhead spool. 10. Run tbg completion wi packer. PT tbg to 3000 psi. MITIA to 2000 psi (tests packer). Re: 3h-05 SURF CASING PIX ) ) \~l-CJ },\ Subject: Re: 3h-05 SURF CASING PIX From: Lou Grimaldi <lou_grimaldi@admin.state.ak.us> Date: Mon, 19 J ul 2004 09: 15 :25 -0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us> cc: Jim Regg <jim_regg@admin.state.ak.us> Hi Torn, Yes, to all ? The casing was cleaned up nicely when I got there, Marie has been good to work with. There was evidence of cement directly below the cut-off point (conductor x surf). Marie has some good pictures of the repairs on the last well. I called and left her a message to send you those pix. Lou Thomas Maunder wrote: Hi Lou, I presume that the surface casing was cleaned off prior to you getting to see it. Was there any discussion of how it looked once they got it uncovered?? Could you see a TOC between the conductor and surface casing?? I do not see on in the pictures. Tom Lou Grimaldi wrote: Hi Jim/Tom, I went out and looked at 3H-05 last night. Looks like they dodged a bullet on this one. Lou C\ t,- '\, ~\~c..\tQ~, C\ c.J:?,?"'''-S ">~íßJ C~ ~ \ \ "> ð\-'\~Q 1 of 1 11/30/2004 9:04 AM 1. Operations Performed: Abandon Alter Casing ,j STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 0 Suspend 0 Operation Shutdown 0 0 Repair Well 0 Plug Perforations 0 0 Pull Tubing 0 Perforate New Pool 0 Other 0 Variance D:! ~nular Dlsp. 0 Periorate 0 Stimulate 0 Change Approved Program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 76' Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 187-077/ 6. API Number: 50-1 03-20077-00 4. Current Well Status: Development - B Stratigraphic 0 Exploratory 0 Service 0 9. Well Name and Number: 3H-05 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURF CASING PROD CASING Perforation depth: 10. Field/Pool(s): Kuparuk Oil Pool measured 7166' feet true vertical 6199' feet measured 6400 feet true vertical 5576 feet Length Size MD 115' 16" 115' 3378' 9-5/8" 3454' 7074' 7" 7150' Plugs (measured) Junk (measured) Burst Collapse TVD 115' 3127' 6186' Measured depth: 6760-6831,6839-6859,6869-6889,6894-6914' true vertical depth: 5869-5927,5933-5950, 5958-5974, 5978-5994' Tubing (size, grade, and measured depth) 3-1/2", L-80, 3147 MD. Packers & SSSV (type & measured depth) Baker FHL 3108' MD no SSSV no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A 13. Treatment descriptions including volumes used and final pressure: Oil-Bbl Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Tubinq Pressure Caslnq Pressure Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run- Daily Report of Well Operations _X 15. Well Class after proposed work: Exploratory 0 Development 0 Service 0 16. Well Status after proposed work: oil0 GasD WAGD GINJD WINJ 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 304-258 WDSPLD Contact Dethlefs/McConnell 659-7224 Printed Name ~rie McConnell Signature 1f%¿p7 /Ø~~~ Title Phone Problem Well Supervisor Date 7/21/2004 Pref)3red tol' Sr'arC'n AflSUf).Drake 263-4612 Form 10-404 Revised 2/2003 . ~e;Bfl JUl a 3. 2UUJ¡ OR\G\NAL SUBMIT IN DUPLICATE 3H-05 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 7/17/2004 Excavated cellar to 12' below grade 7/18/2004 Cut 42.5" conductor window 64" below top of conductor top. Removed OOA cement from 8' to 10.5" below OA valve, exposing surface casing. Found surface casing leak at 110" below OA valve. Surface casing corroded from 94" to 120" below OA valve. See pictures. Damaged witnessed by Lou Gramaldi 7/20/2004 Installed external surface casing patch. Patch was 24" long section of 10-3/4" csg, split and welded to surface casing across corroded casing. See pictures. 7/21/2004 MITOA to 1800 psi passed. Held for 60 mins. See attached MITOA report. Installed coating on the patch and exposed surface casing. Patched conductor window and installed hose down OOA for upcomming cmt top job. See pictures. MEC~.r'\NICAL INTEGRITY TEST (M\ . J FORM 3H-05 I WELL TYPE: prod I i,e,: Prod, Prod AIL, MI, SWI, PWI MIT TEST TYPE: IDA I i.e., Tbg, IA / 9-5/8", OA /13-3/8", T x IA combo, etc. REQUIRED TEST PRESSURE: 11800 I psi. Note: Please consult the PWS if there's any question @ 7224, pager 909. FLUID TYPE(S) USED TO PRESSURE TEST: IDiesel Record all Wellhead Pressures before and durinq Test. PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE I PRESSURES PRESSURES PRESSURES PRESSURES (PSI) (PSI) (PSI)* (PSI)** 540 540 540 540 0 1 00 1 00 1 00 0 1800 1730 1690 TUBING IA 19-5/8" OA /13-3/8" 1 COMMENTS: Continue for additional 30 minutes PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE 1 PRESSURES PRESSURES PRESSURES PRESSURES (PSI) (PSI) (PSI)* (PSI)** 540 540 540 540 100 100 100 100 1690 1690 1680 1680 WELL NO.: T START TIME: 19:30 E S T T START TIME: 110:00 E S T TUBING IA / 9-5/8 II OA 113-3/8" 2 COMMENTS: Second half of 1 hour test. MISC COMMENTS: DATE: 17-21-05 PASS OR FAIL PASS OR FAIL Passed " Start the MIT over if press loss is = 5% @ 15 minutes. ~" Repeat the MIT if press loss is = 10% @ 30 minutes. Note: Test must exhibit pressure stabilization - press loss second 15 min < 50% press loss first 15 min FINAL STEPS MUST BE COMPLETED AND CHECKED OFF!!! m -- FLAG THE CASING VALVE WITH LOAD AND TEST INFORMATION D -- FLAG THE WING VALVE IF SI AT TIME OF LOADING AND TESTING. m -- NOTIFY DSO OF TEST RESULTS, VOLUMES PUMPED AND STATUS OF WELL. W.t I Brake / Rogers I ness: cc: PWS 6/3/00 Photo I: Conductor window. IS! cue top of cement exposed. 7- I 8-04. I . ! ! . - " '1 :. ~~ -.~:.~~ ~:.:~i ~ ; .. .to-8T-L .~'\[eA va ^\OI~q ..0 r I )[U~[ ~U!SUJ ~JeJJns :z oJoqd -"...".. ~~ j". ?'" J'" . ..' I, r Photo 3: Surface csg corrosion 94"- 120" below OA valve. West side. 7-18-04. ,\ (':- , ' ConocoPhillips Alaska. Inc. "I'{)"'~ ,'. . This photo i:.copyright protected b} "~;,' :',,'" " . ',~)., :_~to;~,~<~t.':. -, '.. ' ,:' '. 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"'".;'?ð'''~;''' '\"~" .. " '" .'..\,'''..'',1 ::~~~\ ~~'"'¡'.;''' ' '" . " ......."., ," ~, '~I. ' " ',': '~"::/o:~ 'u,'.~~ \.; ~,:¡,; ~':,' ", . . .'. ,f,.~ "l(o\"A' d', . ~ \0 ",\..\t'.. .\' '-..~ , " '(' , . .:.~,t.~,"}\'~,'¡''''~'~I.~-,."",\~~.\,\~,I'i~~~', . ,"'" I,~ ..\..,'~:,-:,,".,..~.~\,~r,'I.~.~L~~\.~II'Þ~':.~' I ..J......~\,"~\ I"tl, . '''I'..''''.:,~..:..~"\'' 'I '~'~I :....1'':,'''.' y /.;.. \"A."" ".4\t\'I"" it"..~. I I;, ~' " .. ": 'f", '~f'" \~. 'l. \ '" I\. ~ I~ I \ I I. 41 .~ .,' .I""".,~,"" ~ ...~'II-!' \""\\*'~~".'Ii"'" 1:\, :.~ . ":,, '" ,,';>¡~,,> <.t ;\,":'," ~ ~,' ..''.' """. :." ' "'" .' "'~.~.,~\,\.,," ,,\.~..I~ . :,~ "::',)~ ?:':'.:'/i:~. : ~:;;t~i:J:,\,',.~,:~:~::({!t ,"~ ,II ... . .i. . '~,r,. . , " STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Repair Well 0 Alter Casing 0 - I{¡'/PulI Tubing 0 Change Approved Program ø tloperat. ShutdownD 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 7, KB Elevation (ft): RKB 76' a, Property Designation: ADL 25531, ALK 2657 Plug Perforations 0 Perforate New Pool 0 Perforate D 4. Current Well Status: Development - 0 Stratigraphic D 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: Stimulate D Waiver 0 Other Exploratory D Service D 187-077/304-170/304-244 6. API Number: 50-103-20077 -00 9. Well Name and Number: 3H-05 10. Field/Pool(s): Kuparuk River Field / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURF CASING PROD CASING CSG WINDOW Perforation depth: measured 7166' feet true vertical 6199' feet measured 7026' feet true vertical 6085' feet Length Size MD 115' 16" 115' 3378' 9-5/8" 3454' 7074' 7" 7150' Plugs (measured) Junk (measured) 3136' 6719' TVD Burst Collapse 115' 3127' 6186' Measured depth: 6760'-6831'.6839'-6859',6869'-6889',6894'-6914' true vertical depth: 5869'-5927', 5933'-5950', 5958'-5974', 5978'-5994' .'1 "" . prill . 1\ '11 Tubing (size, grade. and measured depth) 2.375" / 3.5" /4.5", L-80. 3147'16363'/6557' MD. Packers & SSSV (type & measured deplh) Baker GHL relr, Pkr. Baker FB-1 pkr pkr @ 3108',6510' no SSSV 12. Slimulation or cement squeeze summary: n/a Inlervals Ireated (measured) n/a 13. Treatmenl descriptions including volumes used and final pressure: Prior to well operation Subsequenllo operation 14. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations_X Oil-Bbl 329 SI Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casinq Pressure Tubinq Pressure 114 322 855 15. Well Class after proposed work: Exploratory D Development 0 Service 0 16, Well Status after proposed work: Oil0 GasD WAGD GINJD WINJ 0 17, I hereby certify that the foregoing is true and correct 10 the best of my knowledge. Sundry Number or NlA if C,O. Exempt: Abandoned D WDSPLD Contact Aras Worthington @ 265-6802 p~inted Name ~as W~rthin. ...;1 Title Wells Group Engineer ....,/..,' . ¿ Signature ff ~ -- --' / Phone ;2 G S ~ 6 'l D:J- ~ Date 7/c2ól..-j-J-oo 1 ß- /'. 0 RIG I N A [",,,00,,s",,00""UOD""263".'2 ~ ...~', JR. ,a;) . Submit Original Only Form 10-404 Revised 04/2004 Page 1 of 5 ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 3H-05 3H-05 WORKOVER/RECOMP Nabors 3S 6/16/2004 From - To Hours Code Sub Phase Code 22:00 - 22:30 0.50 MOVE DMOB WRKOVR 22:30 - 23:30 1.00 MOVE MOVE WRKOVR 23:30 - 00:00 0.50 MOVE DMOB WRKOVR 00:00 - 02:00 2,00 MOVE MOVE WRKOVR 02:00 - 04:00 2.00 MOVE RURD WRKOVR 6/17/2004 04:00 - 05:00 1,00 MOVE RURD WRKOVR 05:00 - 06:00 1,00 MOVE RURD WRKOVR 06:00 - 10:00 4.00 MOVE RURD WRKOVR 10:00 - 15:00 5,00 MOVE RGRP WRKOVR 15:00 - 23:30 8,50 WELCTL NUND WRKOVR 23:30 - 00:00 0,50 WELCTL NUND WRKOVR 6/18/2004 00:00 - 06:00 6.00 CMPL TN NUND WRKOVR 06:00 - 08:00 2.00 WELCTL BOPE DECOMP 08:00 - 10:00 2,00 WELCTL BOPE DECOMP 10:00 - 11 :00 1.00 WELCTL SFTY DECOMP 11 :00 - 13:30 2.50 WELCTL BOPE DECOMP 13:30 - 14:00 0.50 WELCTL BOPE DECOMP 14:00 - 19:00 5.00 WELCTL BOPE DECOMP 19:00 - 20:00 1,00 WELCTL SFTY DECOMP 20:00 - 21:15 1,25 WELCTL OBSV DECOMP 21 :15 - 22:45 1.50 WELCTL OBSV DECOMP 22:45 - 23:25 0.67 WELCTL OBSV DECOMP 23:25 - 00:00 0.58 WELCTL OBSV DECOMP 6/19/2004 00:00 - 01 :30 1,50 WELCTL CIRC WRKOVR 01 :30 - 02:30 1.00 WELCTLCIRC WRKOVR 02:30 - 03:00 03:00 - 04: 15 0.50 WELCTL SFTY WRKOVR 1.25 WELCTL CIRC WRKOVR Start: Rig Release: Rig Number: 6/17/2004 Spud Date: 9/9/1987 End: Group: Description of Operations Prepare Rig for move. Move Rig camp from 1 E to 3H and set up communications. Notified Field of Rig move and notified Doyon of Rig move for confined space entry concerns, Moved Rig from 1 E pad to 3H pad Lay Mats around the wellhead and Spread out Herculite, Put down Handy Berm, Get Rig Modules into position for backing over the wellhead and mating up same. Set BOPE and new wellhead equipmenl behind rig. Moved Carrier Sub over the wellhead, Set up secondary containment. Hook up pipoe shed and pits. Accept Rig @10:00 am, Work on bleeding off 200# SIWHP. Valve not holding. Attempt to grease with rig grease system, No luck, Call out APC grease crew. Load 154 BBLS 11,3 PPG heavy brine into pits. NU BOPE. Having problems with the small amount of clearance left between the rig floor and the top of the BOP Stack, Had to Lift BOP Stack with the Blocks because of the clearance problem and the capability of the Bridge cranes. Install BOP's with some difficulty. Prepare for BOP test. Confirm all equip needed on loc. Rebuild BOP's with 4.5" pipes. Prepare for function test of BOP. Continue to replum cumey system, Install primary press valve on coiled tubing BOP's. RE-hose gauges. and prep for BOP test. Shut down for Pre-spud meeting. Aras, Curtis to reside, Chuck Seavy waived BOP lest. Prepare for BOP test. BOP testing. Continue to BOP test. Call out valve service crew for 7" leaking valve. Supper succer on location for mouse hole, BOPE Test Completed, Held pre-workover Mlg, IA has 200 psi on it. Begin bleeding down to bleed tank. Bled down to 100 psi. RU pump line to the lA, Shot a fluid level and the fluid is @ 100', Continue bleeding IA pressure down to 30 psi. starting spitting fluid (oil). S/I in IA and monitor for build up. Open up tubing ISIP = 500 psi. Bleed tubing down. II bled to 0 psi rapidly. Left open and monitor for fluid returns. S/ no returns observed, IA pressure has built back up to 55 psi. Tubing pressure staying at 0 psi. RU to pump down the coilded tubing and lake returns from the lA, Set up to pump down the tubing and take returns from lA, Found super choke 10 nol be working correctly. Worked on super choke awhile then gave up, Charge pump nol charging figured oul whal was wrong with it. Ready to circulate. Had a spill. when choke line was moved down to the IA the block valves on the mudcross were not blocked. and the hcr was open. spilled 15 gallons of brine.. Corrected the problem and cleaned up the spill. Reported to everyone, Held a safety stand down meeting Started pumping 11,3# brine down the tubing taking returns from the IA 10 the pits. Lots of oil and gas coming back. Had Vac truck skim oil off of pits while circulating, Pump rate 1 BPM, Tubing pressure @ 1900 psi. After pumping 53 bbls started getting good clean brine, Had to shut down to manage fluid in the pits. IA went on a vac after pump was Pr,nte-d 7'15'2004 314:22 PM Page 2 of 5 ConocoPhillips Alaska Operations Summary Report Legal Well Name: 3H-05 Common Well Name: 3H-05 Event Name: WORKOVER/RECOMP Contractor Name: Rig Name: Nabors 3S Date From - To Hours Code Sub Phase Code 6/19/2004 03:00 - 04:15 1.25 WELCTL CIRC WRKOVR 04:15 - 05:30 1.25 WELCTL CIRC WRKOVR 05:30 - 09:15 3.75 WELCTL CIRC WRKOVR 09:15 - 10:35 1.33 WELCTL OBSV WRKOVR 10:35 - 11 :35 1,00 WELCTL SFTY WRKOVR 11 :35 - 12:30 0.92 CMPL TN PULD DECOMP 12:30 - 18:00 5.50 CMPL TN PULD DECOMP 18:00 - 20:00 2.00 CMPL TN PULD DECOMP 20:00 - 20:30 0.50 CMPL TN PULD DECOMP 20:30 - 00:00 3.50 CMPL TN PULD DECOMP 6/20/2004 2,50 CMPL TN PULD WRKOVR 00:00 - 02:30 02:30 - 03:00 0,50 CMPL TN PULD WRKOVR 03:00 - 04:00 1,00 FISH PULD WRKOVR 04:00 - 07:00 3.00 FISH SLlN WRKOVR 07:00 - 11 :00 4,00 FISH PULD WRKOVR 11 :00 - 12:00 1.00 FISH PULD WRKOVR 12:00 - 13:00 1.00 FISH PULD WRKOVR 13:00 - 15:00 2.00 FISH TRIP WRKOVR Start: Rig Release: Rig Number: 6/17/2004 Spud Date: 9/9/1987 End: Group: Description of Operations shutdown for a few minutes, Start pumping again slowly walked rate up from 1/2 BPM to 1 BPM, Begin getting returns afer pumping 5 BBLS away. Pumping @ 1 BPM, Tbg Pressure @ 1800 psi. Continued circulaling at 1 BPM. Losing 16 BPH while circulating. Good clean 11.3# brine coming back in returns, Shut pumps down after 11,000 strokes. 151 BBL total loss while circulating from both night and day shift. While monitoring well for flow. prep all lines for circulating across the top of the hole. Pre-job or tool box safety meet. Discuss all operations that will begin. Mentioned that there is no set proceedures, we will be adjusting on the fly. Begin initial pull of tubing. 32K up weight. Weight went up to 42K while pulling hanger seals out of hanger. Weight fell off to 27K, Pull hanger to floor very slowly. All looks good. Prepare all floor equip for cutting procedures. Excercise cutters. Make firsl cut with hydraulic cutters, All but tech wire cut. Utilized snips tor tech wire. Talked to the crew after the first cut. and all agreed that this system will work, We will improve as we go along, Walked all floor hands. driller. and 1001 pusher through the coil connector stabing proceedures, All cuts are going well. No safety nor enviromenlal issues. Had a fluid level shot and fluid level is at 220', Instruct night shift to spend 20 minutes on the rig floor and watch the day crews handling of the coiled tubing. Asked them if Ihey have an improvement to please implement. We started out with 7.5 minute cuts and handeling. now down to 3.5. Found tubing cracked on 1 side and very corroded. Continued pulling tubing cutting every 13' - 15', filling the hole wI 1 BBL of 11.3# every 150' . Found another cracked spot on 1 side of the tubing, again very corroded, Continued pulling and filling, Found 5 more cracks between 1800' & 2500' down. Tubing IS coming out very corroded and starting to pull wetter. Conlinued pulling tubing cutting every 13' - 15'. filling the hole wI 1 BBL of 11.3# every 150' , Have used 18 bbls of 11,3# since starting pull. Conlinued pulling tubing. multiple cracks & holes. Tubing is is still coming out very corroded and wet. Cutting every 13' - 15'. filling the hole wI 1 BBL of 11 ,3# every 150' , AI app: 3000' out found electracoil to be parted. Prepare for Washover & Overshot run, Called out a Slline unit to check depth of electracoillfish. Ordered out Washover I Fishing string, Baker Fishing Hand & Overshot. Prepped pipe shed and rig floor. Slline unit on location and setting up. RIH w/ 5,5" gauge ring and lagged up on fish @ 3081' rkb (Nabors 3S RKB). RIH w/ 5,5" LIB to 3081'. LIB shows tubing & I-wire. Found fluid level @ 190', RID S/line unit. Load Pipe Shed wI 4-1/2" 12,6# L-80 SLHT (225 joints). Strap & Tally tubing, Pick up 4-1/2" tongs, slips. elevators, Install wear ring, Begin to pick up BHA of Baker Kelo socket. beginning to pick up 4.5" SHL T 12.6# work string, Install and test new floor valve with two crossovers. Begin to RIH with 4.5" SLHT and Baker Kelo socket. Changed out pipe dope after first joint to the correct dope. Prlnled 7/15/200..\ 3' 4 22 PM ConocoPhillips Alaska Operations Summary Report Page 3 of 5 Legal Well Name: 3H-05 Common Well Name: 3H-05 Spud Date: 9/9/1987 Event Name: WORKOVER/RECOMP Start: 6/17/2004 End: Contractor Name: Rig Release: Group: Rig Name: Nabors 3S Rig Number: Date From - To Hours Code Sub Phase Description of Operations Code 6/20/2004 15:00 - 16:00 1.00 RIGMNT RGRP WRKOVR Lay down machine will not work. Begin working out issues. 16:00 - 17:30 1.50 WELCTL COND WRKOVR Line up to circulate. Crude and rubber from coiled tubing ESP cable floating to surface. Pump until clean brine on turnabout. 17:30 - 22:30 5.00 FISH TRIP WRKOVR Continued tripping in hole w/ 4-1/2" stopped @ 3040 Jt #98 and prepared to circulate bottoms up, 22:30 - 22:50 0.33 FISH CIRC WRKOVR Circulated btms up, 11.3# heavy. 4 BPM, 280 psi. down the tbg, 60 bbls, 11,31# heavy coming back. just a trace of oil. 22:50 - 00:00 1.17 FISH TRIP WRKOVR Tagged up on top of electracoil @ 3088' rotated pipe with power tongs and swallowed top of electracoil. Worked over slowly continued as it takes weight 3K-7k rotate the pipe until we get the weight back and continue down, 6/21/2004 00:00 - 01 :00 1,00 FISH FISH WRKOVR Worked over electracoil by rotating and slacking off slowly, Made hole from 3088' to 3167' would not go any farther. Unable to rotate anymore, Very springy wwhen trying to go down, Pulled up to 50k and came free,No exlra weight. Decided to trip out. 01 :00 - 03:30 2.50 FISH TRIP WRKOVR Tripped pipe out racking back doubles. On suriace with fish. 03:30 - 04:30 1.00 FISH PULD WRKOVR Two pieces of electracoil were wedged along side of each other in the Overshot. Total length of eleclracoil retrieved was 34'. Broke down Overshot and layed down pieces of coil. Redressed Overshot and prepared to trip back in hole with same BHA. 04:30 - 08:30 4,00 FISH TRIP WRKOVR Trip pipe in hole, Begin wash-over process. DWN wt = 34K up wt = 40K. Initial toque = 1.0001t, 08:30 - 09:45 1.25 FISH PULD WRKOVR Unable to make it further. Stacking out wt. Dwn 20K. Utilizing the power tongs to spin is a bit difficult. POOH to check bait. 8K overpull. 09:45 - 14:00 4,25 FISH TRIP WRKOVR 10,2' of fish inside of overshot. It is apparent that we need to goto the next stage, 14:00 - 23:30 9,50 FISH PULD WRKOVR Pick -up power swivel and prepare for next run, and Kelo overshol w/ 2-3/8" Grab, 23:30 - 00:00 0.50 FISH TRIP WRKOVR Begin Trip in w/ Kelo Overshot & 4-112" 26# L-80 SLHT tubing, 6/22/2004 00:00 - 03:30 3.50 FISH TRIP WRKOVR Tripped in Hole w/ 4-1/2" 12.6# L-80 SLHT tbg and 5-3/4" x 2-38" Kelo Overshot. Stopped @ 3167', 03:30 - 05:30 2.00 FISH RURD WRKOVR Make up power swivel. 05:30 - 06:00 0.50 FISH CIRC WRKOVR Ciculate suriace to suriace 107 bbls @ 4-1/2 BPM, 380 psi, 11,3# brine. 06:00 - 07:00 1.00 FISH WASH WRKOVR Unable to make any hole, Using various torque values and dwn wt's to enhance our chances, Prep to POOH, 07:00 - 08:00 1.00 FISH TRIP WRKOVR POOH and inspect bait. Prepare for new BHA, 08:00 - 12:30 4.50 FISH TRIP WRKOVR OOH, No fish. Mule shoe worn in the extrusion mode. Appears that we are milling on bent over or side by side coil. Prep lor washover shoe run with wash pipe. 12:30 - 18:00 5,50 FISH RURD WRKOVR Prepare suriace equip for on going fishing operations, Wait on equipment from Prudhoe, Rebuild lower BOP with 3,5" pipe/slips. 18:00 - 21 :00 3.00 WELCTL BOPE WRKOVR Periorm BOP test-- AOGCC waived (Lou Gramaldi) witnessing test. 21 :00 - 00:00 3,00 FISH TRIP WRKOVR Begin RIH w/ new BHA-- 6" full-open shoe, 3 jts 5-3/4" washpipe. 97 jts 4.5" SLHT pipe. 6/23/2004 00:00 - 03:00 3.00 FISH RURD WRKOVR Rig up power swivel. Conduct BOP drill. Circulate bottoms up, RIH and and tag top of fish at 3189', 03:00 - 06:00 3.00 FISH MILL WRKOVR Attempt to wash over nub; PUW=43k, RIW=38k unable to get over ii, begin milling. Milled approx 3' to 3192'. Difficult milling; shoe hanging up on fish causing pwr swivel 10 torque over. Pump bottoms up: discuss options. 06:00 - 11 :00 5.00 FISH FISH WRKOVR Started raising torque values and up to 15K dwn wt. Made 28' after burning through original obstruction. It is obvious that we will need to Pr,r,rEtd' 7/15,2004 3'14'22 PM Page 4 of 5 ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 3H-05 3H-05 WORKOVER/RECOMP Nabors 3S 6/23/2004 From - To Hours Code Sub Phase Code 06:00 - 11 :00 5.00 FISH FISH WRKOVR 11 :00 - 12:00 1.00 FISH CIRC WRKOVR 12:00 - 00:00 12,00 FISH RURD WRKOVR 00:00 - 02:00 2.00 FISH MILL WRKOVR 02:00 - 06:00 4,00 FISH TRIP WRKOVR 06:00 - 09:30 3,50 FISH TRIP WRKOVR 6/24/2004 09:30 - 14:00 4,50 WAlTON EOIP WRKOVR 14:00 - 15:00 1.00 FISH PULD WRKOVR 15:00 - 20:30 5.50 FISH TRIP WRKOVR 20:30 - 22:00 1.50 FISH MILL WRKOVR 22:00 - 00:00 2,00 FISH TRIP WRKOVR 6/25/2004 00:00 - 03:30 3.50 FISH TRIP WRKOVR 03:30 - 10:00 I 6.50 WAlTON ORDR WRKOVR 10:00 - 11 :00 1,00 CMPL TN DEOT DECOMP 11 :00 - 13:30 2.50 WAlTON OR DR DECOMP 13:30 - 20:00 6.50 WELCTL KILL DECOMP 20:00 - 00:00 4.00 WELCTL COND DECOMP 6/26/2004 00:00 - 03:30 3.50 WELCTL COND WRKOVR 03:30 - 05:00 1.50 WELCTL KILL WRKOVR 05:00 - 09:00 4.00 WELCTL KILL WRKOVR 09:00 - 11 :00 2,00 CMPL TN OBSV WRKOVR 11 :00 - 13:15 2.25 CMPL TN TRIP WRKOVR 13:15 - 14:15 1,00 WELCTL COND WRKOVR Start: Rig Release: Rig Number: 6/17/2004 Spud Date: 9/9/1987 End: Group: Description of Operations rotate with a higher torque while attempting to swallow the 2 3/8" coiled tubing. Found extra crossovers and preparing to install Kelly. Pump 2°'0 lubetex around for friction reduction. Allow to soak while picking up kelly. Influx of gas migrating to surface: begin circulating. Finish rigging up Kelly. Set down on trash--Iocate again at 3217'. Begin milling trash, Work down approx 3', slow going. Lost torque w/ 8k dn wgt as cir press increased, Unable to make any more hole; lost the 3" we had gained. Substantial amt of cable insulation/plastic in rtns, Pump bottoms up and pooh to inspect shoe, clear pipe, OOH with ESP cable and coiled tubing jammed into the washover pipe. 22' total inside, Having a new cutlip guide hotshotted from Prudhoe. Decided to run a cutlip with a bit of carbide on the leading edge only. New cutlip guide showed up, Prepare to rig up BHA, Begin rig up of BHA, RIH 10 top of trash: close bag and rev-circ moitoring rtnsnno fluid loss. pump bottoms up. Attempt to slip over fish, w/o rotating, then rotating slowly. No progress. increase speed. work slowly down to 3237'. Unable to make further progress, seeing little torque w/ 1 Ok# down. pump bottoms up, stand back Kelly, and trip back out of hole. Cont. Iripping out of hole. AI suriace, "wad" of coiled tbg 1 cable bound up in shoe/washpipe, Cutrite on cut-lip guide worn smooth, leading edge on cut-lip worn, od of guide flared/split. Waiting decision from state on running USIT: crew periorming rig maintenance / cleaning rig. Pump inlo formalion at 1 bpm, Max pressure achieved was 800# before breakover. Injection rate at 1 BPM 3401t IA pressure. No noticable increase on the OA pressure. Appears that the 7" X 9 5/8" integrity is intact. Waiting decision from state on running US IT: crew periorming rig maintenance / cleaning rig. Have recieved word from lown as to conlinue with short completion. While waiting for word from town, SIWHP has climbed to 250 PSI. Prep for lube and bleed. Lou Grumaldi has granted a stay on our BOP test. until we have changed out the tree spools and are prepared to run the short completion. Prior to running completion we will have to perform a BOP test. Malerials on loc. Begin increasing brine wgllo 12.41t. Moniloring SIWHTP: up 10 440 psi. continue 10 wgt up brine 10 12.4#, Move Baker equip 10 floor, round up proper x-overs, Make up bridge plug assembly, Begin pumping kill. Work rate up 10 3.25 bpm, 2500 psi. SIWHTP=260 psi. Displace w/ 250 bbls 12.4# brine. Shut down and monitor SIWTP. Monitor well while adjusting for all of the crossovers that is needed for this program, Begin make up of BHA with baker bridge plug on 4.5" SHTL work string, Begin to RIH with bridge plug asym for casing pressure test. Also 10 set a storm packer for spool change out on well head asym. Kick at the drill pipe, Prepared floor valve for installation within 45 sec valve stabed and shut. Commence well circulation to circ crude out of drill pipe. Small amount of gas in fluid, Pnnred: 7/15/2004 3,14:22 PM 6/26/2004 6/27/2004 6/28/2004 6/29/2004 Page 5 of 5 ConocoPhillips Alaska Operations Summary Report 3H-05 3H-05 WORKOVER/RECOMP Nabors 3S From - To Hours Code Sub Phase Code 14:15 - 18:00 3,75 CMPLTN TRIP WRKOVR 18:00 - 21 :00 3,00 CMPL TN PCKR WRKOVR 21 :00 - 00:00 3.00 CMPL TN NUND WRKOVR 00:00 - 06:00 6.00 CMPL TN RURD WRKOVR 06:00 - 08:00 2.00 CMPL TN RURD WRKOVR 08:00 - 15:00 7,00 CMPL TN RURD WRKOVR 15:00 - 18:30 3,50 CMPL TN RURD WRKOVR 18:30 - 21 :00 2,50 CMPL TN NUND WRKOVR 21 :00 - 00:00 3,00 CMPL TN SEaT WRKOVR 00:00 - 06:00 6.00 WELCTL BOPE CMPL TN 06:00 - 07:00 1.00 CMPL TN TRIP CMPL TN 07:00 - 08:45 1.75 CMPLTN TRIP CMPL TN 08:45 - 09:45 1.00 WELCTLCIRC CMPL TN 09:45 - 19:00 9,25 WELCTL OBSV CMPL TN 19:00 - 21 :00 2.00 CMPL TN PULD CMPL TN 21 :00 - 00:00 3,00 CMPL TN RUNT CMPL TN 00:00 - 03:30 3.50 CMPL TN RUNT WRKOVR 03:30 - 05:00 1.50 CMPL TN CIRC WRKOVR 05:00 - 07:00 2,00 CMPL TN PCKR WRKOVR 07:00 - 13:00 6.00 CMPL TN DEOT WRKOVR 13:00 - 14:00 1,00 CMPL TN DEOT WRKOVR 14:00 - 15:00 1.00 CMPL TN NUND WRKOVR 15:00 - 18:00 3,00 CMPL TN NUND WRKOVR 18:00 - 20:00 2.00 CMPL TN NUND WRKOVR 22:00 - 23:00 1,00 CMPL TN SEaT WRKOVR 23:00 - 00:00 1.00 CMPL TN RURD WRKOVR Start: Rig Release: Rig Number: Spud Date: 9/9/1987 End: G rou p: Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 6/17/2004 Description of Operations Mo,nitor well, prepare to continue RIH. Set 7" bridge plug at - 3100'. Break off, pull 3 stands. set storm packer @ - 75'. Begin nippling down stack in prep for wellhead work. While nippling down V-block from csg head. found casing had "grown" and was in compression. Discuss options: call out for Baker hand wI spear. welder, etc. Call tool house for cold tap, air compressor. extra hoses, Bleed off all gas pressure from OA. Begin tool box safety meet. Prepare to pull Flow V off of well. Measure LEL. Prepare for 7" casing cut. Lock down the drill site. Total 7" cut = 2.5" dressed off and hammered the slip segments into place. Pressure test packoff to 3.00011'. Pressure test new adapter to 3,000#, Begin install new pack-off. casing head adapters and BOP's for completion. Pressure test to 3.000#. Began prepping for BOP test. State witnessing of test waived by John Crisp @ 19:00 per telephone conversation. Begin weekly BOP test. 250 psi low test, 4000 psi high, 3500 psi Hydrill. Bop test and prepare for pulling work string. Shear our storm packer and monitor well for flow. Prep to POOH. POOH and prepare for completion, Gas breaking out of fluid. Begin to circulate gas out 01 the hole 3.5 bpm. 220 psi. Monitor well. Lay down the Kelly. Very time consuming, Continue to POOH monitoring well bore fluid, Out of holew/ workstring/bridge plug, Remove wear bushing, Prep to run 3,5" tbg. Begin running 3,5" completion. Ran 3-112" completion per final tally. 35k up wgt, 32k down. Spot CRW-132 corrosion pill on top of packer in inner annulus, Drain stack. Land hanger. RILDS, Drop ball & rod. Pressure up on tbg to 3000 psi to set packer With annulus open, pressured 3-1/2" tubing 102500 psi, leaking off, After eliminating all surface equipmenlleaks, pressured up to 2500 psi again still leaking off. Bled press off, pulled tesl jt. closed blinds and pressured again to 2500 psi continues to bleed off. With 1500 psi on tubing press tested IA to 2500 psi for 30 min. (charted test), Bled press off tubing with 2500 psi on IA to dump kill valve. did not shear. Raised pressure on annulus to 2850 to shear dump kill valve in GLM, Pull landing jt. ND test equipment, drain stack. Install BPV. ND BOPE, Blow down mud lines. suction lines. kill, choke, cement line. Wash stack. de-energize koomey and remove hoses and turnbuckles, remove annular bag and set back, N/D BOP's. double gate's. mud cross N/U adaptor & tree. install blind flange on annulus. Pull TWC & install test plug. Test tree 250/5000 psi.. Pull test plug. Clean up tools, remove tbg, tools f/ rig floor, UD rat hole. Release rig @ 2400 hrs. PnnlseJ, 7'151200-1 3'14:22 PM Conoc;Phillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 5, 2004 ¡ ~7- ð77 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 3H -05. The Sundry regards approval to repair a surface casing leak. A previously approved repair on 3B-06 has been initiated but has been slowed by the need to de-water a nearby reserve pit to stop water encroachment. The goal is to have both these wells repaired and back in service during the next few weeks. Please call Marie McConnell or me at 659-7224 if you have any questions. Sincerely, -0~~ (~. Jerry Dethlefs Problem Well Supervisor .F. '4\,ii'0>\\1." JPI!/",,,,,, . ~'~6""" ri1")' t..~ JUL 0 ~} '2004 Attachments o¡¡ g, 1. Type of Request: Abandon Alter casing Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 76' 8. Property Designation: Kuparuk River Unit STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROV~b, 20 AAC 25.280 Operation Shutdown 0 Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: \ 0 0 0 Suspend 0 Repair well 0 Pull Tubing 0 11. Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 7166' 6199' 6400 Casing Length Size CONDUCTOR 115' 16" SURF CASING 3378' 9-5/8" PROD CASING 7074' 7" Perforation Depth MD (ft): 6760.6831,6839-6859,6869-6889,6894-6914' Packers and SSSV Type: Baker FHL no SSSV 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: 9. Well Name and Number: 3H-05 10. Field/Pool(s): Kuparuk Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): 5576 MD 115' Development - 0 Stratigraphic 0 3454' 7150' ,( ;:1).'.'"'.~! t ,,\ A . 2004'~ 1~ ~~ ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Jerry Dethlefs Signature Jl~ c-O~yP' Commission Use Only .., ;~3 L. .--, Perforate 0 Stimulate 0 Variance 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: Annular Disp. 0 Other 0 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity 0 BOP Test 0 Exploratory 0 Service 0 187-077 6. API Number: 50-1 03-20077-00 Mechanical Integrity Test 0 TVD 115 Burst Collapse 3127 6186 Perforation Depth TVD (ft): 5869-5927,5933-5950,5958-5974, 5978-5994' Packers and SSSV MD (ft) 3108' MD no SSSV 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 Immediately Date: Tubing Size: 3-1/211 Tubing Grade: L-80 Tubing MD (ft): 3147 Service D Plugged D WINJ 0 Abandoned 0 WDSPL 0 Contact: Dethlefs/McConnell 659-7224 Title: Problem Well supe~~ Phone 659-7224 Date;7 /&/,ð f¡i Sundry Number: 304-¡;;'5" ~ Location Clearance 0 Other: LO"'\<J..c...\- L~~\o\.~\-Ð~~~;~L ~O \"<)V~c..\- ~\J~C9.~E C.ù-~\~~ ~~x. ?n~\~ ~"-'ì.....s. "",Ù'i'ho--~_~t:o...",. JLì1\.\2 - Subsequent Form Required: ~ 0 RIG I N A L iØ)MS afl Approved bØ/~ COMMISSIONER ~~~~~~~~~ION Date: ø ~ tfv Fonn 10-403 Revised 2/2003. SUBMIT IN DUPLI'LEV { ConocoPhillips Alaska, Inc. SUNDRY NOTICE 10-403 Kuparuk We1l3H-05 (PTD 1870770) July 5, 2004 This application for Sundry approval for we1l3H-05 (PTD 1870770) is for the repair of a surface casing leak. In June 2004 the well had a workover to remove a failed ESP completion and replace it with a packer/tubing completion designed for standard gaslift service. Post workover activities included an MIT on the Outer Annulus (OA). During the MIT diesel was noted coming to surface up the conductor (test form attached). The AOGCC was notified of the problem on 7/4/04. Diagnostics have been performed to characterize the leak. The leak rate from the OA to conductor is approximately 12 gpm @ 1600 psi. Injecting nitrogen down the OA established the leak depth at 8.5-feet below the OA annular valve. This depth is considered reasonably shallow to excavate from the surface and attempt a repair of the casing. Repairing the surface casing will require the following general steps. A more detailed procedure is attached. 1. Shut-in and safe-out the well with plugs and load with seawater and freeze protection. 2. Remove the wellhouse, platforms, and equipment from around the wellhead. 3. Excavate gravel from around the well to approximately 2-feet below the leak site. This will require removal of approximately 5-feet of gravel pad (subject to CPAI safety requirements). 4. Cut away the conductor casing and remove cement around surface casing for inspection. 5. CPAI Mechanical Engineers will determine appropriate patch and/or repair to return the casing to operational integrity. 6. QAlQC the repair and MIT-OA for final check. 7. Replace the conductor and fill void with cement. 8. Backfill gravel around wellhead. 9. Remove plugs and return the well to production. 10. File 10-404 post repairs. MEC~",NICAL INTEGRITY TEST (M\.) FORM 3H-05 I WELL TYPE: I Prod I ¡,e,: Prod, Prod AIL, MI, SWI, PWI MIT TEST TYPE: IMITOA J i.e., Tbg, IA / 9-5/811, OA /13-3/811, T x IA combo, etc. REQUIRED TEST PRESSURE: 11800 1 psi. Note: Please consult the PWS if there1s any question @ 7224, pager 909. FLUID TYPE(S) USED TO PRESSURE TEST: IDiesel WELL NO.: DATE: 17-02-04 Record all Wellhead Pressures before and durinQ Test. PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE I PRESSURES PRESSURES PRESSURES PRESSURES (PSI) (PSI) (PSI)* (PSI)** TUBING 950 950 950 950 IA 19-5/811 950 950 950 950 OA/13-3/811 0 1800 480 480 1 COMMENTS: Well breached to surface via OOA T STARTTIME: 12:00 E S T T START TIME: I E S T PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE I PRESSURES PRESSURES PRESSURES PRESSURES (PSI) (PSI) (PSI)* (PSI)** TUBING IA I 9-5/811 OA 113-3/811 2 COMMENTS: T START TIME: I E S T PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE PRESSURES PRESSURES PRESSURES PRESSURES (PSI) (PSI) (PSI) (PSI) TUBING IA 19-5/811 OA/13-3/811 3 COMMENTS: MISC COMMENTS: PASS OR FAIL FAIL PASS OR FAIL PASS OR FAIL * Start the MIT over if press loss is = 5% @ 15 minutes. ** Repeat the MIT if press loss is = 10% @ 30 minutes. Note: Test must exhibit pressure stabilization - press loss second 15 min < 50% press loss first 15 min FINAL STEPS MUST BE COMPLETED AND CHECKED OFF!!! D -- FLAG THE CASING VALVE WITH LOAD AND TEST INFORMATION D -- FLAG THE WING VALVE IF SI AT TIME OF LOADING AND TESTING. D -- NOTIFY DSO OF TEST RESULTS, VOLUMES PUMPED AND STATUS OF WELL. Witness: I cc: PWS 6/3/00 f ConocoPhillips Alaska, Inc. 3H-05 SURFACE CASING REPAIR PROCEDURE Obiective Repair the leak in the surface casing. The leak is known to be approximately 8-feet below the surface casing annular valve. The extent of damage is unknown; the conductor casing will require partial removal to expose the damaged surface casing. Excavation around the wellhead will be necessary to provide adequate workroom. Maior Steps 1. Excavate around wellhead as needed to provide workroom. Will require As-built review for buried lines or utilities. Excavation depth will be approximately 7 -feet below pad level. Remove cellar box if needed for access. Excavation must conform to Safety Department requirements. 2. Cut windows in and/or remove conductor to expose damaged surface casing. Remove cement sheath from surface casing. 3. Inspect surface casing for damage and leak path. Remove additional conductor for access as necessary. Identify failed or corroded area for repair. Prepare welding repair plan as needed (seal weld, patch, or other). 4. Repair casing, OA/OC. Cover with corrosion protection materials. 5. Install new conductor casing and back-fill void area with cement. 5. Replace excavated gravel and cellar box as needed. Install well house and floor kit. General 1. Network number: 10033047 Activity code: ZX12 2. The surface casing to be repaired is 9-5/8" 36# J-55 casing. The conductor to be removed is 16" 62.5# H-40. 3. The well is an oil producer. The safe-out procedure includes displacing the tubing and inner annulus with water and a diesel cap for freeze-protection. A tubing tail plug will be installed to secure the well from the formation. The well is isolated from the facility; a flowline has not yet been installed. Energy isolation lockout & tag-out procedures apply. A nitrogen purge will be maintained on the inner annulus (IA), outer annulus (OA) and conductor during hotwork operations with continuous monitoring of 02 and LEL levels. 4. The well house and floor kit are already removed as part of the prior Drilling activity. The cellar box will require removal for the excavation and repair. 5. Anyon-site personnel have the authority to stop or suspend the job should any safe-out or procedural conditions become suspect. Safety is everyone's responsibility. Repair Preparation: 1. Prepare In-Service package for cutting and welding. (WG, EN G) 2. Shut-in and secure well. Set tubing tail plug and dummy gaslift valves. Displace tubing and IA with seawater. Leave diesel freeze-protection fluids on tubing and IA to 2000'. (WG) 3. Bleed tubing, IA (3-1/2" x 7") and OA (7" x 9-5/8") to zero psi. Verify flow is zero; inability to maintain zero psi prior or during job will cancel the welding operation. (APC & WG) 06/08/04 1 NSK Problem Well Supervisor ( 4. Prep 9-5/8" casing head: Pull VR plug and install opposing valve on casing head for N2 purge. (WG & Valve Shop) 5. Prep 7" casing head: Pull VR plug and install opposing valve on casing head for N2 purge. (WG & Valve Shop) 6. Verify OA fluid level is below repair point; remove fluid via suction hose as needed. (APC & WG) 7. Excavate around wellhead as needed for access to surface casing below grade. 8. Drill and tap a hole in the conductor pipe near ground level for N2 purge of conductor during cutting and removal. 9. Install stick scaffold around wellhead for access to wellhead valves. 10. Install purge lines from N2 bottle rack to lA, OA and conductor. Discharge to bleed trailer will be monitored for LEL and 02 levels and must be accessible. Position bleed trailer downwind and as far from wellhead as is practical. (APC) 11. Station several hand-held extinguishers around wellhead. (APC & WG) 12. Inspect and remove any combustibles in accordance with Hot Work standard. (APC) 13. Install welding blankets to cover ground around wellhead. (APC) 14. Hold pre-job safety meeting and ensure all permitting is in order. (WG) Job Procedure 1. Safety department will check entire well area before Hot Work commences. Sniff entire piping layout around wellhead to check for any potential flammable material sources. (APC and/or CPA) 2. Purge the lA, OA and conductor with nitrogen, venting to slop trailer. Purged gas is to be monitored throughout job for LEL and 02 levels. Target 02 level is < 5%. The heating / cutting operation may commence after target 02 level is reached. (WG) (APC Safety) 3. Establish fire watch and begin hot work, including prepping surface with torch, brushes, grinding or buffing as required. (APC) 4. Cut windows in conductor to expose surface casing and cement. The Wells Group will mark the conductor for the initial area to be cut for access. 5. Chip out and remove cement sheath from surface casing for inspection. 6. Cut conductor away as needed to fully expose damaged area of casing (note-the conductor can be entirely removed and replaced later). 7. Stop N2 purge and remove low-pressure equipment from well. 8. Inspect casing damage and acquire data to formulate a welding and/or patch plan. 9. Pick up all trash and debris for disposal. Please leave a clean location! (ALL) Repair Plan Procedure 1. Prepare welding/repair plan as per Facility Engineer recommendations. 2. Repeat Job Procedure steps for purging and energy isolation as described above. 3. Repair surface casing as per Facility Engineer plans. 4. Note: Replacement of the conductor will be performed after the repair is done and QA/QC is complete. 06/08/04 2 NSK Problem Well Supervisor Post Weldinq Plan 1. QA/QC repair. Install corrosion protection surface materials on surface casing. 2. MITOA to 1800 psi to check for any external leaks in wellhead repair. (WG) 3. Replace conductor casing (weld) and fill with cement. 4. Replace excavated gravel and cellar box as needed. 5. Remove the additional annular valves on IA and OA. (WG & Valve Shop) 6. Return well to production. Monitor 9-5/8" annular pressure and conductor area for 30 days. (DSO) 06/08/04 3 NSK Problem Well Supervisor Re: Kuparuk 3H-05 Surface Casing Leak Subject: Re: Kuparuk 3H-05 Surface Casing Leak From: Thomas Maunder <tom - maunder@admin.state.ak.us> Date: Tue, 06 Jul2004 08:54:36 -0800 . To: NSK Problem Well Supv <n1617@conocophillips.com> \~~._.C)'l '1 Good moves. I will look for the sundry. To NSK Problem Well Supv wrote: Tom: The IA tested OK on the rig. But as you know they had to set a shallow packer on that well, which is above the surface casing shoe. With a known leak in the surface casing we end up with only one barrier--the production casing. I have just prepared the 10-403 to send you for the excavation and repair of the casing; you should get it in a day or two. We will not be flowing the well at all until this is repaired. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7224 -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak. .mmmmmmmmmmm Sent: Tuesday, July 06, 2004 6:28 AM To: NSK Problem Well Supv Subject: Re: Kuparuk 3H-05 Surface Casing Leak Jerry, Thanks for the information. completion?? Another one to Tom Maunder, PE AOGCC I presume that the IA tested OK after the add to the list. Keep us advised. NSK Problem Well Supv wrote: Tom: As part of the post RWO work on Kuparuk well 3H-05 (PTD 1870770) we found a leak in the surface casing. It was discovered in the process of performing an MIT on the OA (note there was not a spill) with fluids from the OA coming back to surface up the conductor. Diagnostics today by the DHD crew found the leak at 8-feet down from the OA annular valve. The well will remain shut-in for now until we have more information. I suspect we will decide to dig this up, cut away the conductor, and inspect/repair the surface casing. We will submit a 10-403 for the proposed work when we make a final decision on our plan. Please call if you have any questions. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7224 10f2 7/6/20048:54 AM 1. Type of Request: j ~ R!r"'" If~ "E ~~' §Jf~).c¡ < ~"... ~ ' 1! ~) \r~"'.' . ~....,. ~.1_.... , ik.,"", APPLICATION F?o~~~.~?RY APPROVAL JUN 2 4 2004 GI ~ 11\1 ~ O'! & '~''''': '''Mr'' C"'''''''-~~¡'''''¡''i-¡S Abandon 0 Suspênd 0 Operation Shutdown 0 Perforate 0 H j i:J ;:>I\~ai~er ,"; ~v <..' ~~nul~~ i~i~p~b' ;\1 4J~,¡ \ ~:, n .\~ Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0 Time Extensio~ . tJ' .,::;¡, " Other 0 Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 it ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 8. Property Designation: ADL 25531, ALK 2657 11. Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 7166' 6199' 7026' Casing Length Size 5. per~ Drill Number: Exploratory 0 187-077 7 304-170 Service 0 6. API Number: Ý 50-103-20077 -00 9. Well Name and Number: 3H-05 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): 4. Current Well Class: Development - 0 Stratigraphic 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 76' PROD CASING 7074' 7" MD TVD Burst Collapse 115' 115' 3454' 3127' 7150' 6186' CONDUCTOR SURF CASING 115' 3378' 16" 9-5/8" Perforation Depth MD (ft): Perforation Depth TVD (ft): 6760'-6831',6839'-6859',6869'-6889', 6894'-6914' 5869'-5927',5933'-5950',5958'-5974',5978'-5994' Packers and SSSV Type: Packers and SSSV MD (ft) Baker FB-1 pkr @ 6510' no SSSV no SSSV 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: June 28, 2004 Oil 0 Gas 0 16. Verbal Approval: Date:<øI~.S-oY. WAG 0 GINJ 0 Commission Representative: hç:~~ \ ~ ~ Ù 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name ~s WO.rt~1i~qt~..O ~ /. - Signature d ;d4/PÞ- Commission Use Only Tubing Size: " 2.375" 14.5" Tubing Grade: CT / L-80 Tubing MD (ft): 6351' 1 6557' Service 0 Plugged 0 WINJ 0 Abandoned 0 WDSPL 0 Phone Aras Worthington @ 265-6802 Wells Group Engineer Date Ip /2+/04- Contact: Title: Conditions of approval: Notify Commission so that a representative may witness ber' L( Sundry Num 'c:yy..¡~;;.L/ Plug Integrity 0 BOP Test 0 Mechanical Integrity Test D Location Clearance D Other: c..a~\-\t'\~@ <J:)~~\{3~ ~,,\\o\'l.~ O.~ .ç~'>0\\~ C;t')Q~\\:LJ Q~ V'<\Q-..J tJ...\ Q;--( \>\ \'\G ~ ~:...J ,,<:c ~C\ d.a~ S Q,NJ ~Ck'i \0 ~ ~- t\(S~~v SUbsequent~orm R Ã.r :' ~ y:; \, . O~\G\N~l Approved bY:! ~ . COMMISSIONER _BfL JUN ~ 8 7nO~, BY ORDER OF L£rhC£ THE COMMISSION Date: ,,~/ Or Form 10-403 Revised 12/2003 INSTRUCTIONS ON REVERSE Submit in Duplicate 3H-05 Procedure A rig workover was attempted on 3H-05 to remove the Electrocoil (ECT) completion and run a standard gas-lift tubing completion in it's place. In the course of attempting to remove the ECT completion from the wellbore of 3H-05 the severely corroded ECT parted at - 3200' MD. Numerous fishing attempts were made to recover the ECT resulting in recovery of only -60' of ECT. The ECT continually wadded up and fishing became prohibitively expensive and non-productive. ConocoPhillips Ak Inc. proposes that we run a packer in the well at -3200' and 3 Y2" tubulars with gas-lift to complete the well as-is and bring it online. CPAI committed to running a casing inspection log both before and after the first ECT completion was run. The baseline log was run before the ECT completion. At this point, however, it appears that there is little benefit to running a subsequent USIT log because we can only get a log of roughly the upper 3000' of 7", We plan to pressure test the upper -3000' of 7" after the new completion (and packer) is run to verify mechanical integrity prior to production. Current Completion .... .... 3H-05 Proposed Workover 9 5/8" Casing ~ 7" Casing 2 2/8" ECT .... ESP Pump , ~ PrODosed Completion ..... II .... 3 %" Tbg wI landing nipple @ 500', in Ttail, & GLM iI ~ %" X 7" Packer ~ ~(jO 2 3/8" ECT Fish Ii - <O'\~l) =c.o<;\~ ~ ~ t 7::>5~O ~ Re: 3H-05 Workover/Completion Subject: Re: 3H-05 Workover/Completion From: Thomas Maunder <tom - maunder@admin.state.ak.us> Date: Fri, 25 Jun 2004 13:29:01 -0800 To: "O'Dell, Brian J" <B.O'DELL@conocophillips.com> cc: Mike Mooney <m.mooney@conocophillips.com> Brian, This confirms our discussion regarding 3H-05. Be advised that you have approval to forgo the USIT log and run the gas-lift completion with the packer at about 3000'. Approval to complete and produce the well is valid for one year and is renewable. Please call with any questions. Tom Maunder, PE AOGCC O'Dell, Brian J wrote: Tom, As we discussed, here is my address. Or simply reply to this note. Brian O'Dell/Howard Gober Wells Coordination Supervisor Conocophillips Alaska, Inc. C P AI We 11 s Coo rd .~.~P"y'.~~.,~.?,~.~,?,.Ç..2.P..~~.~.,~..~..~.P.!?...:..Eg.~.~ (907) 659-7235 1 of 1 6/25/2004 1 :31 PM Note to File 3H-05 (187-077...304-244) Kuparuk River Unit (Kuparuk) ConocoPhillips Alaska, Inc Phillips has made application for an unconventional completion for the subject well. This document examines the pertinent information for the well and recommends approval of ConocoPhillips' request. --3H-05 was one of 2 wells (3H-11 the other) completed with experimental pumping equipment known as electro-coil. The experiment has not been a success due to the electrical failure of the pumping equipment and the ultimate failure of the coil due to corrosion. --Corrosion is of concern, however based on the surface monitoring performed (quarterly flowline inspections and corrosion coupons and a casing log on 3H-11), any corrosion appears to be confined to the coil. The exact mechanism is uncertain. --After the pumping equipment failed, CPAI has been able to keep the well producing since it will flow. According to the production reports, the well is making around 1200 bbls of total fluid per day with 25 - 30% oil. The well has been producing under variance since late February 2002. --The new completion proposal is the result of failing to be able to clean the wellbore of the electro-coil. CAPI has been fishing, with the top of junk around 3200' and little prospect for cleaning out the wellbore. --CPAI's proposal is to run normal tubing and a packer, setting the latter above the junk. The result will be nearly 3500' of production casing remaining exposed to the produced fluid. In the early phases of the present workover, the production casing was exposed to pressures up to 3500 psi as the well was killed. --CPAI is uncertain if the proposed completion attempt will be successful since fluid losses experienced early in the workover have ceased and it is possible that their attempt to clean out the well has resulted in plugging of the perforations. The only way that can be determined is to provide the means to produce the well. --If the well does not produce, then the new completion would facilitate preparing the well for abandonment and possible sidetrack. CPAI is aware that the potential abandonment of this well will be more complicated and different than other abandonments done at Kuparuk. Based on examination of the submitted information, I recommend approval of ConocoPhillips' request for the subject well. ~~~ Tom Maunder, PE Sr. Petroleum Engineer t.p 6--s --0 l1 G:\common\tommaunder\Well Infonnation\By Subject\Annular Flow\040625--3H-05 _shallow packer.doc 1. Type of Request: Abandon D Alter casing D Change approved program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 76' REGEl' I'-'E~ ~ STATE OF ALASKA VI QJ ~ ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 05 2004 ~...-..'\ APPLICATION FOR SUNDRY APPROV ALAlaska Oil & G C ~ 20 AAC 25.280 as ons. Commission Operation Shutdown D Perforate D Variance AMDr~ular Disp. D Plug Perforations D Stimulate D Time Extension D Other D Perforate New Pool D Suspend D Repair well 0 Pull Tubing D Re-enter Suspended Well D Development Stratigraphic 0 D Exploratory D Service D 5. Permit to Drill~mber: 187-077 6. API Number: .../ 50-103-20077-00 4. Current Well Class: 8. Property Designation: ADL 25531, ALK 2657 11. Total depth MD (ft): 7166' Casing CONDUCTOR SURF CASING Total Depth TVD (ft): Effective Depth MD (ft): 6199' 7026' Length Size 9. Well Name and Number: 3H-05 10. FieldlPool(s): Kuparuk River Field / Kuparuk Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): PROD CASING 7074' 7" MD TVD Burst Collapse 115' 115' 3454' 3127' 7150' 6186' 115' 3378' 16" 9-5/8" Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: 6760'-6831',6839'-6859',6869'-6889', 6894'.6914' 5869'-5927',5933'-5950',5958'-5974',5978'-5994' 2.375" /4-1/2" CT / L-80 Packers and SSSV Type: Packers and SSSV MD (ft) Baker FB-1 pkr pkr @ 6510' no SSSV no SSSV 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program D BOP Sketch D Exploratory D Development 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: June 1, 2004 Oil 0 Gas D 16. Verbal Approval: Date: WAG D GINJ D Tubing MD (ft): 6351' / 6557' Service D Plugged D WINJ D Abandoned D WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Mike Moonev Signature * Contact: Title: Phone Aras Worthington @ 265-6802 Wells Group Team Leader Date*" Commission Use Only Conditions of approval: Notify Commission so that a representative may witness ISUndry Number: V .30<1.. 170 Plug Integrity D BOP Test ~ Mechanical Integrity Test D Location Clearance D Other: S500~,>'\ ""'\ t'-..t M'.) k. \Sa ~ ~~-\- f(fØIlð ef\.. ~t« \ () 1~\\~ App",,"" by ~ AJ( ~ ~ BY ORDER OF THE COMMISSION ¥f;f Date: -¿!JIo/-)j: Subsequent Form Required: ~D ~ Form 10-403 Revised 2/2003 . (1 q \ G \ N A L SUBMIT IN DUPLICATE 3H-O5 Rig Workover Procedure Pre-Ria Work: 1. RU pump, KilllA/7" x CT annulus wI brine. 2. NO Tree, NU Mstr. Valve. Ria Work 1. MIRU Workover Rig. 2. Verify well (7" annulus & top hat) is dead. If not bullhead well to appropriate KWF. 3. NU BOPS. Test the BOPE to 4000 psi. 4. Pull CT hanger, CT & ESP from packer. Note condition of CT continuously. If CT is corroded, consider running USIT log in corrosion mode across 7" casing. 5. After ESP is recovered: 6. RU EL & run USIT log across all of 7" in corrosion mode (if applicable; see step 4). ---- 7. PU completion tbg & run test packer into well. Set at same depth as proposed new completion packer. Test 7" to 2500 psi or minimum pressure required if USIT log indicates corroded casing. 8. Test 95/8" casing (OA) to 1800 psi. 9. Run storm packer, change-out wellhead spool. 10. Run tbg completion wI packer. PT tbg to 3000 psi. MITIA to 2000 psi (tests packer). ConocoPbillips Alaska, Inc. 3H-O5 ESP (6351.æ10, OD:5.130) TUBING (651Q.Q557, OD:4.5( (), ID:3.958) 1'GLV Wobble Ring (671%720, OD:1.000) Perf (6760-6831) Perf (6839-6859) Perf (6869-6889) Perf (6894-0014) KRU 914;O5'<"12":'J;;,,'u8""" , API: 501032007700 SSSV Type: NONE Well Type: PROD Orig 9/16/1987 Completion: Last W/O: 3/27/2000 Ref Log Date: TD: 7166 ftKB .MaXH~I~ ~n~~e:,~6 deQ .~"630.~,, ..,. "',",m, Angle @ TS: 36 dell @ 6764 Angle @ TD: 36 deg @ 7166 Rev Reason: ESP note Last Update: 5/29/2003 Annular Fluid: Reference Log: Last Tag: 7026 Last Tag Date: 3/24/2000 :eààing:Stiing;:~'AI;.t:'$:T;RU\oGS:;':; , Description Size CONDUCTOR 16.000 SURF CASING 9.625 PROD CASING 7.000 ;iWiñi1Stnna,!Î(I"USING",,; .",,', " Size I Top I Bottom 2.375 0 6351 4.500 6510 6557 PêifOfätiOnsISWömârv ' Interval TVD 6760 - 6831 5869 - 5927 ,"" Top Bottom TVD Wt Grade Thread 0 115 115 62.50 H-40 0 3454 3127 36.00 J-55 0 7150 6186 26.00 J-55 TVD Wt I Grade 5537 0.00 5704 12.60 L-80 Status Ft SPF Date Type Comment 71 8 8/30/1988 'PERF 21/8 EnerJet; 60 ph 20 8 8/30/1988 IPERF 21/8 EnerJet; 60 ph 20 4 8/30/1988 IPERF 21/8 EnerJet; 60 ph 20 1 12/8/1987 APERF 4" Csg Gun; 120 ph Zone UNIT D,C-4,C-3 6839 - 6859 5933 - 5950 A-5,A-3 6869 - 6889 5958 - 5974 A-2 6894 - 6914 5978 - 5994 A-2f.-1 Other þlugs"eQuiÞ..,etc,. -JEWELRY' Depth TVD Type 6351 5537 ESP 6510 5666 Description Electrocoil ESP Pump & Motor Assembly w/2.375" Deployment Sub PUMP INSTALLED BELOW MOTOR ASSEMBLY Baker FB-1 Packer, w/4" Seal Bore; Baker snap latch & seal assembly w/guide sub landed in packer OAL=13.16' Baker 80-40 Petroline TPACs valve Petroline FSV Valve 4.000 2.900 2.500 3.968 ID 0.000 PACKER 4.000 6513 5668 SBE 6532 5684 TPAC 6541 5691 FSV 6557 5704 WLEG 'Ff$1ì'~FISI4':":";:c;;', ";,, , Depth 1 Description I Comment :~~~ ~;2~~~ ~:n~~ble Ring ~~:t ~~~~~~ ~/~~~~~I~~Z¿~ hole after workover Gênerâliríiótes"i:,.. n'"":' ' " . ., Date INote 6/1712000 7" CASING DAMAGE AT 6544' SEE USIT LOG 3/26/00 3/18/2002 PACKERLESS COMPLETION: FTS WELL Conoc~ ill i ps Mike Mooney Wells Group Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 April 29, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ¡th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Application for Sundry Approval for 3H-05 (APD # 187-077) Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for a Sundry Approval to workover the Kuparuk well 3H-05. 3H-05 has a Coil-Tubing Electro-Submersible Pump (CT -ESP) that was installed in 2000. The pump/motor assembly has since failed and the well has continued to produce unassisted. The rig workover will consist of pulling the CT-ESP, pressure-testing the 7" casing, and running a conventional tubing string and production packer with gas-lift capability. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, I!(tJiÍ M. Moon~ Wells Group Team leader CPAI Drilling and Wells MM/AW/skad RECEIVED MAY 0 5 2004 Alaska Oil & Gas Cons. Commission Anchorage ORIGINAL CPAI 1st Quarter 2004 Flowline Inspections Subject: CP AI I st Quarter 2004 Flowline Inspections From: NSK Problem Well Supv <nI617@conocophillips.com> Date: Sun, 04 Apr 2004 14:07:31 -0800 To: "Tom Maunder AOGCC (E-mail)" <tom_maunder@admin.state.ak.us> Tom: Attached are the latest flowline inspection reports for ConocoPhillips note that wells ID-I05A and ID-121 are both shut-in with reservoir problems inspections. We will resume the inspections if and/or when the wells return and inspections will continue, but the well will (hopefully) get a workover annular flow. wells that have annular flow. Please and we have suspended the flowline to production. Well 3H-05 is flowing this summer and will no longer have Please call if you have any questions. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7224 «lD-I05A Qrty Inspection.doc» «lD-121 Qrty Inspection.doc» «3H-05 Qrty Inspection.doc» Content-Description: ID-I05A Qrty Inspection.doc :lD-IO5A Qrty Inspection.doc Content-Type: applicationfmsword Content-Encoding: base64 Content-Description: ID-121 Qrty Inspection.doc ID-121 Qrty Inspection.doc Content-Type: applicationfmsword Content-Encoding: base64 ? \<=6'\ -0'\\ .' -- - - -- - ì I : Content-Description: 3H-05 Qrty Inspection.doc ' 3H-O5 Qrty Inspection.doc Content-Type: applicationfmsword Content-Encoding: base64 I of I 4/5/20047:46 AM -----Original Message----- From: NSK Corr DS Coord Sent: Friday, February 27, 2004 7:33 PM To: CPF3 Prod Supv Cc: CPF3 Prod Engrs; CPF3 Fac Engr; CPF3 DS Lead Techs; CPF3 Control Room; NSK Corr Insp Piping; NSK Carr Chem&Monitoring; NSK Carr Vessel Insp; NSK DS Fac Engr; NSK Engr&Corr Supv; NSK Problem Well Supv 3H-OS Quarterly Erosion Survey Inspection Subject: Randy/Jeff, On 2/24/04 we completed an erosion survey inspection n well 3H-05. Th inspection is being performed on a quarterly inspection frequency as iginally request by Jerry Dethlefs (NSK Problem Well Supv) as part of a Sundry approval ag ement with e AOGCC. Originally this inspection was scheduled to be performed annu r concerns of possible increases in erosion damage due to high solids production through the piping and chokes. The results are as follows: Action Items: None Damage Summary: No changes were noted on well 3H-05 from our previous inspection on 11/25/03. Our inspection consisted of Ultrasonic inspection of the S-riser, Choke, and manifold piping as well as radiographic inspection of the choke. For previous inspection history and results please refer to the attached Inspection Log. Future Inspection Plans: We will continue to monitor this well under the quarterly inspection frequency as agreed to with the AOGCC until notified otherwise by Operations. All film and UT data is on file with corrosion and is available for your viewing. If you have any questions contact Spencer/George at ext. 7209 or AI Dahlquist at ext 7773. Regards, George Foley/Spencer Morningstar Lead Inspection Coordinators NSK-39 N 1 016@conocophillips.com ext7209 RE: 3H-05 Subject: RE: 3H-05 From: NSK Problem Well Supv <n1617@conocophillips.com> Date: Tue, 09 Mar 2004 14:01 :53 -0900 To: Thomas Maunder <tom_maunder@admin.state.alcus> !~)¡~O\~ Tom: I forwarded your request to town, I think I can get someone to find some data for you on 3H-11. Jerry -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Tuesday, March 09, 2004 1:49 PM To: NSK Problem Well Supv Subject: Re: 3H-OS I have looked at the 3H-ll file and I would agree that I doubt if another electo-coil will be deployed. I found Mike Winfree's justification letter. Oh well, it was a good idea at the time. We both have had a few of them. In looking through the file, I cannot find any work reports for the CT fishing job for the electro-coil or the running of the USIT that you mentioned. I am not sure that you are the one that would/could provide that information, however I would appreciate someone sending in those work reports so we can complete the files. I still need to check the log file for the UIST. That is something that should be in the file as well. I will get back to you on that. Tom NSK Problem Well Supv wrote: Tom: I don't know about actual run time of the ECT, but I do have dates the equipment was ran. 3H-11 was ran in May 1999. 3H-05 completion was ran in April of 2000. So it is a little newer, but not much. I am not sure if it makes any difference how long the ECT pumps actually ran, but exposure to wellbore fluids is our main concern. I understand that lab analysis of the fluids indicates 3H-05 should not be as corrosive as 3H-11 was, but we are not banking on that. The experience with 3H-11 was that as the CT was pulled over the goose-neck it would break, being held together just with the internal cable. It was a real mess. This time they will either pull straight pieces and cut them as they come out, or use tubing-conveyed wash pipe to overshot the CT to pull. It all depends on if they can unstring the pump from the downhole receptacle. The pump sits in a "packer-type" receptacle that may not budge. If that is the case there will be a lot of fishing with this operation. This is not a project anyone is looking forward to. Needless to say, we will probably not be running any of these kinds of completions again. Jerry -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.a.k.us] S en t: Tue s da y, March 0'9";"'''''''2''6Ù'4''''''''i''';''õs''''''''PM''''''''''''''''''''''''''''''''''''''''''''''''''''''''''....................................................................... To: NSK Problem Well Supv Subject: Re: 3H-05 Jerry, Do you have some relative "run-time" information to compare 3H-05 to 3H-11?? I wonder if the -2500' to 3400' depth is where the gas comes 10f3 ~Cl~~~~~'U;:C; Wt~\H 1. 7 2004 3/9/2004 3 :09 PM RE: 3H-05 out of solution. Having this well on the priority list is a good thing. Needing to keep the well in production in order to keep the pressures down is not the best mode to be in. I take it the the electro-coil is not retrievable with just a coil tubing unit?? Thank s , Tom NSK Problem Well Supv wrote: Tom: 3H-05 was orignally on last years' workover program but was not ultimately done. Due to the ECT completion it is significantly more complex and was not attempted last year. It is on this years' WO program and the completion will be replaced with a standard tubing/packer setup. This well is very high on the priority list for a workover since there is concern about degradation of the coil tubing from corrosion over time. The experience with 3H-11 was that it may come up in pieces, making for long fishing jobs. We do not want the existing completion left in the ground any longer than necessary. We also think this well is safer to operate in a flowing condition to keep wellhead pressures down than it would be to shut it in. Due to the ECT we cannot run plugs into the well, and close tolerances through the pump prohibit solids (sand, CaC03, etc.) from being pumped to plug the perfs. The end result will be high wellhead pressures which we would like to avoid. The purpose for the Sundry extension is to bridge the time gap between the current Sundry expiration and the workover. I have not seen the final schedule to know when the workover will be attempted, but we are scheduled to start them on or around April 15. So it should be only a few months at most until the 3H-05 workover takes place. I put "not to exceed one year" on the Sundry just to cover all those unknowns that happen when planning goes down the drain. We will be performing a casing inspection log and casing MIT as part of the workover. The only similar casing inspection log was ran on 3H-11 on June 14, 2001 as part of the workover. Some casing damage was noted on the USIT ran on that well. The description I can find is as follows from that operation: "USIT log was run late in the evening; the casing had heavy corrosion (both build-up and pitting). Up to 30-50% wall loss in pits. Worst is -2500' to 3400' and then tapers off, although still present. On one good point, there is no real evidence of any erosion at the pump discharge depth. " Recent workovers at West Sak on ESP wells did not find any degradation at all from the casing inspection logs. Let me know if you have any additional questions. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7224 -----Original Message~---- From: Thomas Maunder [~~ilto:tom maunder@admin.state.ak.us] Sent: Tuesday, March 09, 2004 9:52 AM To: NSK Problem Well Supv Subject: 3H-05 Jerry, Marie, Nina or MJ: 2of3 3/9/2004 3 :09 PM RE: 3H-05 Did I miss anyone?? I am looking at the sundry application for 3H-05. Wasn't there another eltro-coil installation out there that was worked over?? Was there any log of the casing in that workover?? On some of the failed ESP wells that were recently worked over, inspection logs were run. I don't remember the specific comments, but I don't thing there was any "damage" noted. Let me know what you might have on these inspection logs. Thanks in advance. Tom 30f3 3/9/2004 3 :09 PM y ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 7, 2004 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well3H-05 (PTD 1870770). The request regards extending the time period to produce the well with a failed ECT pump. Please call Marie McConnell or me at 659-7224 if you have any questions. Sincerely, fl. /LO~ Jerry Dethlefs U Problem Well Supervisor Attachments , :t~:,' .. tJ MAR 0 9 ZOOt Cn:~(:rm'i.':£:¡(ln Oq\G\NAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operation Shutdown D Plug Perforations D Perforate New Pool D 1. Type of Request: D D D Suspend D Repair well D Pull Tubing D Abandon Alter casing Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 76' 8. Property Designation: Kuparuk River Unit 11. Total depth MD (ft): 7166' Casing CONDUCTOR Total Depth TVD (ft): Effective Depth MD (ft): 61991 6400 Length Size 115' 33781 16" SURF CASING PROD CASING 9-5/8" 70741 7'1 Perforation Depth MD (ft): 6760-6831, 6839-6859, 6869-6889, 6894-6914' Packers and SSSV Type: no packer no SSSV 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program D BOP Sketch D 14. Estimated Date for Variance 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 187-077 / 6. API Number: V 50-103-20077 -00 9. Well Name and Number: 3H-05 10. Field/Pool(s): Kuparuk Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): 5576 MD Perforate D Stimulate D 4. Current Well Class: Development - 0 Stratigraphic D Exploratory D Service D TVD 115' 34541 115 7150' 3127 6186 Perforation Depth TVD (ft): 5869-5927,5933-5950, 5958-5974, 5978-5994' Packers and SSSV MD (ft) Commencing Operations: 16. Verbal Approval: Immediately Date: Signature Tubing Size: 4-1/2" no SSSV 13. Well Class after proposed work: Exploratory D Development 0 15. Well Status after proposed work: Oil 0 Gas D WAG D GINJ D Contact: Title: Phone 659-7224 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Other: ~Q~\'O.)Q. \ t."{..~\\<:.. So S I~\ -DS' . . l:: &' . \ ,. . 'WAR 0 9 ZOO .ç \C\J..) l\. "'Jê \,,' ~~c""'t a "- ~ ~C;¡~(:;r~;ì; :;\- Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance D ~l. 00' <) 3/0/9 Annular Disp. D Other D Junk (measured): Burst Collapse Tubing Grade: L-80 Tubing MD (ft): 655T Service 0 Plugged D WINJ D Abandoned D WDSPL D Dethlefs/McConnell 659-7224 Problem Well Supervisor Date Sundry Number: .3 Date:,r!)~"/J' 0 SUBMIT IN DUPLICATE ConocoPhillips Alaska, Inc. Kuparuk We1l3H-05 (PTD 1870770) March 7, 2004 The purpose of this Sundry Notice is for an extension to produce ConocoPhillips' Kuparuk well 3H-05 without assistance of the electric submersible pump (ESP). On February 27,2002, the AOGCC was notified the ESP pump had become inoperable. The ESP failed on 2/17/02 while attempting to restart the pump after shut down for a scale inhibition squeeze. Diagnostics on 2/25/02 confirmed the ESP is electrically grounded down hole. The reservoir has sufficient pressure for the well to flow freely without the assistance of the ESP, although at lower rates. On 03/27/02 the AOGCC approved the initial variance to flow the well for a one-year period (#302- 102). On 02/27/03 the AOGCC approved the first one-year extension, which expires 03/31/04 (#303-058). Due to the configuration of the coiled tubing ESP, production has been up the annulus from the time the completion was installed in November 2000. The well is not capable of flow up the coiled tubing as it is only a conduit for the ESP cable. Therefore, production fluids will continue to flow up the annulus to the flowline unassisted. Recent production well tests are as follows: ~s\\~\ ~<;,\~~\\ l\t ~\\~\1 ~O'\\~~~~C/ ~~tl0-t\ ., Flow Rate Flowing Water Cut Oil Rate (BLPD) Press IA % BOPD 1230 113 75 313 1082 117 70 320 1305 113 72 369 1290 115 72 365 DATE 02/22/04 02/01/04 01/18/04 12/28/03 Comment ESP ino erable ESP ino erable ESP ino erable ESP ino erable Corrosion and erosion monitoring of the surface piping riser, including both UT and X-ray surveys, has been performed as a condition of the initial variance. The monitoring results are tabulated on the following page from the NSK Corrosion Group. ConocoPhilliDs DrODoses that: 1. The AOGCC approve this extension request for a time period not to exceed 12 months from the approval date; . 2. Perform quarterly flowline inspections and submit same to the AOGCC; 3. Should a workover not be completed within the approved time period the AOGCC will be contacted for a review and discussion of the plan forward. 3H-05 Special Inspection Request Log DS3H 3H-05 Quarterly Inspection erosion survey due to AOGCC sundry agreement 8, I, N - (8 - baseline inspection, I - Increase in % wall loss, N - No change from previous inspection) Date of # of Worst Damage Inspection 8, I, N Case Wall Comments Inspection Locations Loss % Grade 01/18/01 9 B 0% A Base Line Inspection 03/24/02 9 N 0% A Start Quarterly inspection 07/18/02 9 N 0% A Quarterly Inspection 11/23/02 9 N 0% A Quarterly Inspection Quarterly Inspection slight increase erosion on well house 02/22/03 9 I 12% B riser bottom elbow OS/23/03 9 N 12% B Quarterly Inspection 08/23/03 9 N 12% B Quarterly Inspection 11/25/03 9 N 12% B Quarterly Inspection 02/24/04 9 N 12% B Quarterly Inspection OS/24/04 ConocoPhillips Alaska, Inc. KRU 3H-05 3H-05 API: 501032007700 Well Type: PROD AnQle @ TS: 36 deQ @ 6764 SSSV Type: NONE Orig 9/16/1987 Angle @ TD: 36 deg @ 7166 Completion: Annular Fluid: Last W/O: 3/27/2000 Rev Reason: ESP note Reference LOQ: Ref LOQ Date: Last Update: 5/29/2003 Last TaQ: 7026 TD: 7166 ftKB Last TaQ Date: 3/24/2000 Max Hole AnQle: 36 deQ @ 6300 Casing String - ALL STRINGS DescriDtion Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 115 115 62.50 H-40 ESP SURF CASING 9.625 0 3454 3127 36.00 J-55 (6351-B510, PROD CASING 7.000 0 7150 6186 26.00 J-55 00:5.130) Tubina String - TUBING Size I Top I Bottom I TVD I Wt I Grade I Thread 2.375 I 0 I 6351 1 5537 1 0.00 I I w/Cable inside 4.500 I 6510 I 6557 1 5704 1 12.60 I L-80 I Buttress Perforations Summary Interval TVD Zone Status Ft SPF Date Tvpe Comment 6760 - 6831 5869 - 5927 UNIT 71 8 8/30/1988 IPERF 2 1/8 EnerJet; 60 ph D C-4,C-3 6839 - 6859 5933 - 5950 A-5 A-3 20 8 8/30/1988 IPERF 2 1/8 EnerJet' 60 ph 6869 - 6889 5958 - 5974 A-2 20 4 8/30/1988 IPERF 2 1/8 EnerJet' 60 ph 6894 - 6914 5978 - 5994 A-2,A-1 20 1 12/8/1987 APERF 4" CSq Gun; 120 ph Other ( plugs equip.. etc. - JEWELRY DeDth TVD Type Description ID TUBING 6351 5537 ESP Electrocoil ESP Pump & Motor Assembly w/2.375" Deployment Sub 0.000 (6510-6557, PUMP INSTALLED BELOW MOTOR ASSEMBLY 00:4.500, 6510 5666 PACKER Baker FB-1 Packer, w/4" Seal Bore; Baker snap latch & seal assembly 4.000 10:3.958) w/Quide sub landed in packer OAL=13.16' 6513 5668 SBE Baker 80-40 4.000 6532 5684 TPAC Petroline TPACs valve 2.900 6541 5691 FSV Petroline FSV Valve 2.500 -- I 6557 5704 WLEG 3.968 ; ...:J:::¡ t:::::I:: Fish - FISH II I Depth I Description I Comment ~ 6719 11" GLV & Wobble Rinq I Lost Downhole Could still be in hole after workover 6720 11/2" SS Bands I See WSR's 3/31/00 and 4/4/00 General Notes .. Date I Note 6/17/200017" CASING DAMAGE AT 6544' SEE USIT LOG 3/26/00 3/18/20021 PACKERLESS COMPLETION: FTS WELL I (I 1" GLV ~ Wobble Ring \ 1 (6719-6720, Ö 00:1.000) -- - r-- Perf -- -- (6760-6831) - - -- - - -- - -- - - -- Perf - -- (6839-6859) - -- - -- - -- Perf - -- - -- (6869-6889) - -- - -- - -- Perf - -- - -- (6894-6914) - -- - -- - -- Quarterly flowline inspection reports Subject: Quarterly flowline inspection reports Date: Mon, 6 Oct 2003 13:02:53 -0800 From: "NSK Problem Well Supv" <n1617@conocophillips.com> To: tom_maunder@admin.state.ak.us, bob_fleckenstein@admin.state.ak.us CC: "rtl 617" <rtl 617@conocophillips.com> Tom, Here is a copy of the quarterly flowline inspection reports required to fulfill the Sundry requirements for the following wells. 1D-1 1D-1 1D-1 1D-1 1D-1 1D-1 02: PTD 2000750, Sundry #302-101 05A: PTD 2012020, Sundry #302-294 10A: PTD 2000390, Sundry #302-227 21: PTD 1971810, Sundry #302-304 27: PTD 1981090, Sundry #353-057 29: PTD 1972130, Sundry #303-092 1 D-140: PTD 2001360, Sundry #302-376 3H-05: PTD 1870770, Sundry #302-102 Please let me know if you have any questions. Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224, 659-7043 (See attached file: 3H-05 Quarterly Inspection Log.xls)(See attached file: 1 D-102 Insp Log.xls)(See attached file: 1 D-105 Inspection Log.xls)(See attached file: 1D-110 Insp Log.xls)(See attached file: 1 D-121 Inspection Log.xls)(See attached file: 1D-127 Inspection Log.xls)(See attached file: 1 D-129 Inspection Log.xls)(See attached file: 1 D-140 Inspection Log.xls) Ir---:-. .I Name: 3H-05 Quarterly Inspection Log.xls tt ~b~ 3H'05 Quarterly ...... Inspection Log.xlsI Encoding'Type: base64EXCEL File (app ication/msexce ) [~ ~ . ~ ~ ~'~ r-- .................................................................... f .......................................................................................................................................... /I _.. i Name: 1D-102 Insp Log.xls J I ~1D-102 Insp Lo.q.xlsl Type: EXCEL File (application/msexcel) I ~{~(~-(~t ~" t, :, base64 IEncoding: -" ! ...........: ii;' ~ 1 D-105 Inspection Loq xlsl Type' EXCEL File (application/msexcel) ~Oc~ ~-~1D-110 Insp Lo,q.xls Type: EXCEL File (application/msexcel)t '- Encoding: base64 ~1D-121 Inspection Lo.q.xlsI Type: EXCEL File (application/msexcel)l ]Encoding: base64 ./'£ I ............ ......................... i /~1D-127 Inspection Lo.q.xlsi Type: E~'CEL File (application/msexcel)i - l, Encoding: base64 1 of 2 10/6/2003 3:17 PM Quarterly flowline inspection reports ¢/1r~ 1 D-129 Inspection Lo.q.xls Name: 1D-129 Inspection Log.xls 1 Type: EXCEL File (application/msexcel)l Encoding: base64 I ,~~ 1 D-140 Inspection Lo,q.xls Name: 1 D-140 Inspection Log.xls Type: EXCEL File (application/msexcel) t Encoding: base64 2 of 2 10/6/2003 3:17 PM 3H-05 Special Inspection Request Log DS3H 3H-05 Quarterly Inspection erosion survey due to AOGCC sundry agreement B, I, N - (B - baseline inspection, I - Increase in % wall loss, N - No change from previous inspection) # of Worst Date of Inspection B, I, N CaseWall Damage Comments Inspection Locations Loss % Grade 01/18/01 9 B 0% A Base Line Inspection 03/24/02 9 N 0% A Start quarterly inspection 07/18/02 9 N 0% A Quarterly Inspection 11/23/02 9 N 0% A Quarterly Inspection ~ -----~ Quarterly Inspection slight increase erosion on well house riser 0 9 I 12% B ' ~bottom elbow 05/,2~3/03 9 N 12% B Quarterly Inspection 08/23~5--~ ....... 9 N 12% B ,...J Quarterly Inspection Quarterly Flowline line inspections Subject: Quarterly Flowline line inspections Date: Mon, 7 Jul 2003 16:08:20 -0800 From: "NSK Problem Well Supv" <n1617@conocophillips.com> To: tom_maunder@admin.state.ak.us CC: bob_fleckenstein@admin.state.ak.us, "rtl 617" <n1617@conocophillips.com> Tom, Here is a copy of the quarterly flowline inspection reports required to fulfill the Sundry requirements for the following wells. 1D-1 1D-1 1D-1 1D-1 1D-1 1D-1 02: PTD 2000750, Sundry #302-101 05A: PTD 2012020, Sundry #302-294 10A: PTD 2000390, Sundry #302-227 21: PTD 1971810, Sundry #302-304 27: PTD 1981090, Sundry #353-057 29: PTD 1972130, Sundry #303-092 1 D-140: PTD 2001360, Sundry #302-376 3H-05: PTD 1870770, Sundry #302-102 Please let me know if you have any questions. MJ Loveland Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224, 659-7043 (See attached file: 3H-05 Quarterly Inspection Log.xls)(See attached file: 1 D-102 Insp Log.xls)(See attached file: 1 D-105 Inspection Log.xls)(See attached file: 1D-110 Insp Log.xls)(See attached file: 1 D-121 Inspection Log.xls)(See attached file: 1 D-127 Inspection Log.xls)(See attached file: 1D-129 Inspection Log.xls)(See attached file: 1D-140 Inspection Log.xls) ['~3H-05 Quarterly Inspection Log.xls Name: 3H-05 Quarterly Inspection Log.xls: Type: EXCEL File (application/msexcel) Encoding: base64 ¢r~ 1D-102 Insp Lo.q.xls Name: 1D~102 Insp Log.xls Type: EXCEL File (application/msexcel) Encoding: base64 Name: 1 D-105 Inspection Log.xls ~1 Inspection Log...X..! .S. Type: (application/msexcel) D-1 05 EXCEL File Encoding: base64 Name: 1D-110 Insp Log.xls __1D-110 Insp Lo,q.xls Type: (application/msexcel) EXCEL File Encoding: base64 Name: 1D-121 Inspection Log.xls r~1D-121 Inspection Loq.xls Type: (application/msexcel) EXCEL File Encoding: base64 ~'~'~.¢,'4f-',~ ,,,, ;,:;,,, . 1 of 2 SC"'A NED 'JUL 2 6 2:003 7/14/2003 10:39 AM 3"-05 Special Inspection Request Log ~,(~ ~'~-~) ~ DS3H 3H-05 Quarterly Inspection erosion survey due to AOGCC sundry agreement B, I, N - (B - baseline inspection, I - Increase in % wall loss, N - No change from previous inspection) # of Worst Damage Comments Date of Inspection B, I, N Case Wall Grade Inspection Locations Loss % 01/18/01 9 B 0% A Base Line Inspection 03/24/02 9 N 0% A Start quarterly inspection 07/18/02 9 N 0% A Quarterly Inspection 11/23/02 9 N 0% A Quarterly Inspection Quarterly Inspection slight increase erosion on well house riser 02/22/03 9 I 12% B bottom elbow 05/23/03 9 N 12% B Quarterly Inspection C STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of r~luest: Abandon_ Suspend_ Operational shutdown _ Alter casing _ Repair well _ Plugging _ Change approved program _ Pull tubing _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchora~le, AK 99510-0360 5. Type of Well: Development __X Exploratory __ Stratigraphic _ Service_ 4. Location of well at surface 1444' FNL, 4997' FEL, Sec. 12, T12N, R8E, UM At top of productive interval 4014' FNL, 1374' FEL, Sec. 11, T12N, R8E, UM At effective depth (asp°s 498655, 6000211) At total depth 4222' FNL, 1480' FEL, Sec. 11, T12N, R8E, UM (asp's 496894, 5997433) 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length CONDUCTOR 115' SURF CASING 3378' PROD CASING 7074' Size 16" 9-5/8" 7" 7166 6199 6400 5576 feet Plugs (measured) feet feet Junk (measured) feet Cemented 255 sx AS I 1250 sx AS III, 425 sx Class G 400 sx AS I Re-enter suspended well _ Time extension_~..,~t~ Stimulate Variance _X ~- Perforate _ Other _ 6. Datum elevation (DF or KB feet) RKB 76 feet 7. Unit or Property name Kuparuk Unit 8. Well number 3H-05 9. Permit numbe~ approval number 187-077 10. APl number 50-103-20077 11. Field / Pool Kuparuk Oil Pool Measured Depth True ve~icalDepth 115' 115' 3454' 3127' 7150' 6186' Perforation depth: measured true vertical Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 6760-6831',6839-6859', 6869-6889', 6894-6914' 5869-5927', 5933-5950', 5958-5974',5978-5994' 4.5",12.6#,1-80 @ 6557',2.375"coiltubing @ 6351' BakerFB-1 w/4"SealBora @ 6510' No SSSV RECEIVED FEB 2 6 2005 Alaska 0ii & Gas Cons. Co~ami~ol Anchorage 13. Attachments Description summary of proposal _X Detailed operations program __ BOP sketch __ 14. Estimated date for commenci.~g operation March 27, 2003 -- 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __X Gas __ Service Suspended__ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /~'~ ~ ~'~'- ~)~ Title: Problem Well Supervisor Jerr~ethlefs FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Questions? Call Jerry Dethlefs 659-7224 Date ~,~'~.~' Approval no. Plug integrity_ BOP Test_ Location clearance _ Mechaniqal Int~fi~Test ~ / ~ Subsequent fo~equired 10- .. Approved by order of the Commission ~~ ~ Commissioner Date Please return to: Form 10-403 ~ev 06115188 · NSK Problem Well Supe~isor NSK-69 SUBMIT IN T~IPLIOATE ConocoPhillips Alaska, Inc. Kuparuk Well 3H-05 (PTD 1870770) SUNDRY NOTICE 10-403 VARIANCE EXTENSION 02/23/03 The purpose of this Sundry Notice is for an extension to produce ConocoPhillips' Kupamk well 3H-05 without assistance of the electric submersible pump (ESP). On February 27, 2002, the AOGCC was notified the ESP pump had become inoperable. The ESP failed :on 2/17/02 while attempting to restart the pump after shut down for a scale inhibition squeeze. Diagnostics on 2/25/02 confirmed the ESP is electrically grounded down hole. The reservoir has sufficient pressure for the well to flow freely without the assistance of the ESP, although at lower rates. On 03/27/02 the AOGCC approved the initial variance to flow the well for a one-year period (#302- 102). Due to the configuration of the coiled tubing ESP, production has been up the annulus from the time the completion was installed in November 2000. The,welt4s not capable offlow upthe coiled tubing as it is only a conduit for the ESP cable. Therefore, production fluids will continue to flow up the annulus to the flowline unassisted. Production well tests are as follows: Flow Flowing Water Oil Rate Comment DATE Rate Press (IA) Cut % (BPD) BOPD 02/07/03 1195 123 79 252 ESP inoperable 1/10/03 1105 117 78 242 ESP inoperable 12/15/02 977 112 74 259 ESP inoperable 1Qtr 2001 3400 78 748 Maximum sustained rate after ESP installed 11/2000 Corrosion:and erosion monitoring of the surface piping riser, including both UT and X-ray surveys, has been performed as a condition of the initial variance. The most recent monitoring results are tabulated on the following page from the NSK Corrosion Group. ConocoPhillips proposes that: 1. The AOGCC approve this extension request for a time period not to exceed 12 months from ~"~ the approval date; 2. Perform quarterly towline inspections and submit same to the AOGCC; / 3. Should a workover not be completed within the approved time period the AOGCC will be contacted for a review and discussion of the plan forward. .SGANhlED ~AR 8 7 2.003 ConocoPhillips Alaska, Inc. CORROSION INSPECTION RESULTS Kuparuk Well 3H-05 (PTD 1870770) 02/23/03: Originally this inspection was scheduled to be performed annually over concerns of possible increases in erosion damage due to high solids production through the piping and chokes. The results are as follows: Action Items: None Damage Summary: No changes ~to the manifold piping inside of the drillsite module were noted on well 3H-05 from our previous inspection on 11/23/02. A slight increase in erosion was noted on the well head riser from 10% erosion to ~1..2'yoeresien (B grade) was noted. This erosion survey consisted of Ultrasonic and Radiographic inspection of the S-riser, Choke, and Manifold piping. Future Inspection Plans: We will schedule quarterly erosion survey inspections on well 3H- 05 until notified otherwise by operations. 11/23/02 Corrosion Report: On 11/23/02 we completed an erosion survey inspection on well 3H-05. This inspection was moved to a quarterly inspection schedule per email from NSK Problem Well Supervisor as part of a Sundry approval agreement with the AOGCC. Originally this inspection was scheduled to be performed annually over concerns of possible increases in erosion damage due to high solids production through the piping and chokes. The results are as follows: Action Items: None Damage Summary: No changes were noted on well 3H-05 from our previous inspection on 7/19/02. This erosion survey consisted of Ultrasonic and Radiographic inspection of the S- riser, Choke, and Manifold piping. Future Inspection Plans: We will schedule quarterly erosion survey inspections on well 3H- 05 until notified otherwise by operations. 7/19/02 Corrosion Inspection results: Action Items: None Damage Summary: Ne~changes.were noted on wells 3H-05 & 3H-11 from our previous inspections back in January 02'. Our inspection consisted of Ultrasonic inspection of the S- riser, Choke, and manifold piping as well as radiographic inspection of the chokes. Future Inspection Plans: We will schedule annual erosion survey inspections on these wells until notified otherwise by operations. SCANNED MAR 0 ? 20(33 PHILLIPS Alaska, Inc. KRU 3H-05 A Subsidiary oi= PHILLIPS PETROLEUM COMPANY COIL TUBING~ ! ~ ~ 3H-05 (0-6351, O~:2.375,[ APl: 501032007700 Well Type: PROD Angle @ TS: 36 deg @ 6764 ID:1.939) · SSSV Type: Orig Compltn: 9/16/87 Angle @ TD: 36 deg @ 7166 Annular Fluid: Last W/O: 3/27/00 Rev Reason: Modify Schematic; JWP. Reference Ref Log Date: Last Update: 1/8/01 ESP (6351-6510, Log: OD:5.130) Last Tag: 7026 TD: 7166 ftKB Last Tag Date: 3/24/00 Max Hole 36 deg @ 6300 Angle: CaSing Strings - All Description Size Top Bottom TVD Wt Grade Thread PROD CASING CONDUCTOR 16.000 0 115 115 62.50 H-40 (0-7150, OD:7.000, SURF CASING 9.625 0 3454 3127 36.00 J-55 PROD CASING 7.000 0 7150 6186 26.00 J-55 Wt:26.00) Tubing strings - All: ToP0 TV~537Wt Description Size Bottom I Grade Thread COIL TUBING 2.375 6351 0.00 w/Cable inside TUBING 4.500 6510 6557 5704 12.60 L-80 Buttress PerforatiOns Summary Interval TVD Zone Status Ft SPF Date Type Comment 6760 - 6831 5869 - 5927 UNIT 71 8 8/30/88 IPERF 2 1/8 EnerJet; 60 ph D,C-4,C-3 6839- 6859 5933 - 5950 A-5,A-3 20 8 8/30/88 IPERF 2 1/8 EnerJet; 60 ph 6869- 6889 5958 - 5974 A-2 20 4 8/30/88 IPERF 2 1/8 EnerJet; 60 ph 6894 - 6914 5978- 5994 A-2,A-1 20 1 12/8/87 APERF 4" Csg Gun; 120 ph TUBING Other ',plugs, equip,, etc.) - jEWELRy (6510-6557, Depth TVD Type Description ID OD:4.500, 6351 5537 ESP Electrocoil ESP Pump & Motor Assembly w/2.375" Deployment Sub 0.000 ID:3.958) 6510 5666 PACKER Baker FB-1 Packer, wi4" Seal Bore; Baker snap latch & seal 4.000 assembly w/guide sub landed in packer OAL=I 3.16' 6513 5668 SBE Baker 80-40 4.000 6532 5684 TPAC Petroline TPACs valve 2.900 TPAC (6532-6533, 6541 5691 FSV Petroline FSV Valve 2.500 OD:5.855) 6557 5704 WLEG 3.968 Fish - FISH, Depth I Description Comment 6719 11" GLV & Wobble Ring Lost Downhole Could still be in hole after workover FSV (6541-6542, 6720 1!2" SS Bands See WSR s 3/31/00 and 4/4/00 OD:5.935) General Notes Date Note 6/17/00 7 CAS NG DAMAGE AT 6544' SEE USIT LOG 3/26/00 WLEG (6557-6558, OD:5.187) 1" GLV _Wobble Ring (6719-6720, OD:1.000) 1/2" SS Bands (6720-6721, OD:1.000) Pen' (6760-6831) ,__ Pen' (6839-6859) _ Pen' (6869-6889) _ __ CANNE MAR 0 ? ?_003 Perf (6894-6914) __ h~e: MOnltonng r<epor~ JM-u=) =)unanj ~F.~uz--~ Subject: Re: Monitoring Report 3H-05 Sundry #302-102 Date: Tue, 30 Jul 2002 06:52:39 -0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: NSK Problem Well Supv <n1617@ppco.com> Pete, Thanks for the update. Tom No change is a good observation. NSK Problem Well Supv wrote: Well 3H-05 is a coiled tubing ESP completion. A Sundry fk302-102 was obtained to continue flow up the annulus after the ESP failed. As required by the sundry an UT inspection was completed in 07/02 and the results are as follow: Damage Summary: No changes were noted on well 3H-05 from our previous inspection back in January 02: Our inspection consisted of Ultrasonic inspection of the S-riser, Choke, and manifold piping as well as radiographic inspection of the chokes. > All film and UT data is on file with corrosion and is available for > viewing. If you have any questions please contact myself or Jerry > Dethlefs. > Peter Nezaticky > Phillips Alaska Inc. > 907-659-7224 Tom Maunder <tom maunder~admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 of 1 7/30/2002 6:53 AM PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 18, 2002 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a 10-403 Sundry for Phillips Alaska, Inc., well 3H-05 for approval to flow the producer with a failed ESP. Attached is a discussion and well schematic diagram. Please call Pete Nezaticky or me at 907-659-7224, or Hai Hunt/Marie McConnell at 659-7871 if you have any questions. Sincerely, Jerry Dethlefs Phillips Problem Well Supervisor Attachment STATE OF ALASKA ~:;~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _X Perforate _ Other 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 76 feet 3. Address Exploratory _ 7. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 Service__ Kuparuk Unit 4. Location of well at surface 8. Well number 1444' FNL, 4997' FEL, Sec. 12, T12N, RSE, UM (asp's 498655, 6000211) 3H-05 At top of productive interval 9. Permit number / approval number 4014' FNL, 1374' FEL, Sec. 11, T12N, RSE, UM 187-077 At effective depth 10. APl number 50-103-20077 At total depth 11. Field / Pool 4222' FNL, 1480' FEL, Sec. 11, T12N, R8E, UM (asp's 496894, 5997433) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 7166 feet Plugs (measured) true vertical 6199 feet Effective depth: measured 6400 feet Junk (measured) true vertical 5576 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 1 15' 16" 255 sx AS I 1 15' 1 15' SURF CASING 3378' 9-5/8" 125o sx AS III, 425 sx Class G 3454' 3127' PROD CASING 7074' 7" 4oo sxAS ~ 7150' 61 86' Perforation depth: measured 6760-6831', 6839-6859', 6869-6889', 6894-6914' ~ "~ ~-, '~ true vertical 5869-5927', 5933-5950', 5958-5974', 5978-5994' ?', ! ~ Tubing (size, grade, and measured depth 4.5", 12.6#, 1-80 @ 6557', 2.375" coil tubing @ 6351' ! · Packers & SSSV (type & measured depth) Baker FB-1 w/4" Seal Bore @ 6510' No SSSV 13. Attachments Description summary of proposal X Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: March 20, 2002 16. If proposal was verbally approved Oil __X Gas __ Suspended __ Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Jerry Dethlefs 659-7224 SignedJer~ethl~efs~ ~ ~ Title: Problem Well Supervisor Date FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approval no. Plug integrity __ BOP Test __ Location clearance __ I "-~' ~ ~, · Mechanical Integrity Test__ Subsequet~t form required 10- t%~:~t",,~ ~,IN-~:~N~',,~.~ ~.t'%[~ Approved by order_of the Commission 6~m.m._¥ fl_eeh.di Commissioner Date ~)/(~-7 / NSK Problem Well Supervisor NSK-69 Form 10-403 Rev 06/15/88' SUBMIT IN TRIPLICATE Phillips Alaska, Inc. Kuparuk Well 3H-05 (PTD 1870770) SUNDRY NOTICE 10-403 VARIANCE REQUEST 3/18/02 The purpose of this Sundry Notice is for approval to produce Phillips Kuparuk well 3H-05 without assistance of the electric submersible pump (ESP). On February 27, 2002, the AOGCC was notified the ESP pump had become inoperable. The ESP failed on 2/17/02 while attempting to restart the pump after shut down for a scale inhibition squeeze. Diagnostics on 2/25/02 confirmed the ESP is electrically grounded down hole. The reservoir has sufficient pressure for the well to flow freely without the assistance of the ESP, although at lower rates. The intention is to flow the well until a future workover is performed that will configure the well with a traditional gas lift completion. The workover is not yet scheduled. Due to the configuration of the coiled tubing ESP, production has been up the annulus from the time the completion was installed in November 2000. The well was put online December 1, 2000. The well is not capable of flow up the coiled tubing as it is only a conduit for the ESP cable and does not contain a gas lift string. Therefore production fluids will continue to flow up the annulus to the flowline unassisted. Well tests have been performed prior to, and after, the pump failed showing a lower flow rate on natural flow as follows: DATE Flow Water Oil ESP FBHP Comment Rate cut Rate Freq psi (BPD) BOPD 03/14/02 1253 71% 368 0 Hz 2226 Stabilized rate post ESP failure 01/08/02 2165 73% 581 44 Hz 1220 Last test at normal pump speed prior to ESP failure 1Qtr 2001 3400 78% 748 42 Hz 1300 Maximum sustained rate after ESP installed 11/2000 Corrosion and erosion monitoring of 3H-05 surface piping riser has been performed at an increased frequency compared to flowing or gas lifted wells due to a higher percentage of solids in the production stream. ESPs typically have higher solids production rates due to lower flowing bottom hole pressures resulting in higher formation drawdown. Additional erosion/corrosion monitoring was implemented after severe corrosion was observed while pulling an identical ESP completion on 3H-11 in June 2001. Erosion inspections have included both UT and X-ray and have not identified any problems. Radiography performed on the riser and manifold piping on 6/21/01 showed slight erosion to the riser and no damage detected to the manifold piping. A follow-up radiography inspection on 12/28/01 showed no significant change in the riser or manifold piping. There were no increases in wall loss between a UT inspection on 1/18/01 and our most recent UT inspection on 1/18/02. A follow-up inspection is scheduled for July 2002. Inspections will be scheduled annually on this well if no increases in damage are found during the follow-up inspection in July. If any changes are noted during our July 2002 inspection we will evaluate the inspection interval and increase frequency as needed. Phillips proposes that the AOGCC approve this request for a time period not to exceed 12 months from the approval date. Should a workover not be completed in that time the AOGCC will be contacted for a review and discussion. Attached is a wellbore diagram with completion details. PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY COIL TUBING -- (0-6351, OD:2.375, ID:1.939) ESP (6351-6510, OD:5.130) PROD CASING (0-7150, OD:7.000, Wt:26.00) TUBING (6510-6557, OD:4.500, ID:3.958) TPAC (6532-6533, OD:5.855) FSV (6541-6542, OD:5.935) WLEG (6557-6558, OD:5.187) 1" GLV _Wobble Ring (6719-6720, OD:1.000) 1/2" SS Bands (6720-6721, OD:I.000) Perf (6760-6831) - Perf (6839-6859) - Perf (6869-6889) - Perf (6894-6914) - l KRu 3H-05 APl: 501032007700 PROD 3H-05 SSSV Type: Annular Fluid: Well Type: Odg Compltn: Last W/O: 9/16/87 3/27/00 Angle (~ TS: Angle @ TD: Rev Reason: 36 deg @ 6764 136 deg @ 7166 Modify Schematic; JWP. Reference Ref Log Date: Last Update: 1/8/01 Loc LastTa¢ 7026 TD: 7166ftKB Last Tag Date: = 3/24/00 36 deg @ 6300 Max Hole Angle: ICasing Strings - All Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 1151 1151 62.50I H-40 I SURF CASING 9.625 0 3~5~I 3127 36.00 J-55 PROD CASING 7.000 0 7150 6186 26.00 J-55 Tubing Strings - All Description Size Top Bottom I TVD I Wt IGrade I Thread COIL TUBING 2.375 0 6351 5537 0.00 w/Cable inside TUBING 4.500 6510 6557 5704 12.60 L-80 Buttress Perforations Summary Interval TVD Zone Status Ft SPF Date Type Comment 6760 - 6831 5869 - 5927D,C-4,c-3UNIT 71 8 8/30/88 I IPERF 12 1/8 EnerJet; 60 ph 6839- 6859 5933- 5950 A-5,A-3 20 8 8/30/88 I IPERF 12 1/8 EnerJet; 60 ph 6869- 6889 5958- 5974 A-2 20 4 8/30/88 IPERF 2 1/8 EnerJet; 60 ph 6894- 6914 5978- 5994 A-2,A-1 20 I 12/8/87 APERF 4" Csg Gun; 120 ph Other (plugs, equip., Depth TVD Type 6351 155371 ESP 6510 5666 PACKER 6513 I 5668 I SBE 6532 156841 TPAC 6541 5691I FSV 6557 5704 WLEG etc.) - JEWELRY Description 4.000 4.000 2.900 2.500 3.968 Electrocoil ESP Pump & Motor Assembly w/2.375" Deployment Sub Baker FB-1 Packer, w/4" Seal Bore; Baker snap latch & seal assembly w/guide sub landed in packer OAL=13.16' Baker 80-40 Petroline TPACs valve Petroline FSV Valve DepthI Description Comment 6719 1" GLV & Wobble Ring Lost Downhole Could still be in hole after workover 6720 1/2" SS Bands See WSR's 3/31/00 and 4/4/00 General Notes Date Note 6/17/00 7" CASING DAMAGE AT 6544' SEE USIT LOG 3/26/00 Re: Phillips 3H-05 ESP failure ) ) Subject: Re: Phillips 3H-05 ESP failure From: Tom Maunder <tom_maunder@admin.state.ak.us> Date: Wed, 27 Feb 2002 10:07:49 -0900 To: NSK Problem Well Supv <n1617@ppco.com> \ ~'ì'-O~'\ Jerry, Yes you should plan to submit a 403 much the same as was done previously. Be sure erosion and flow line inspections are addressed. That just makes sure we all have done the homework to avoid another 7-8. Based on the well test reports, the glr is relatively low so erosion shouldn't be much concern. Thanks for asking. Tom NSK Problem Well Supv wrote: Tom: The following email is from one of our PEls regarding the failure of Phillips 3H-05 ESP producing well. As you can see from the production tests the well will flow without the ESP running. As was the case with 3H-11, our intent will be to work the well over sometime this coming year. In the interim I am asking for permission to keep the well on line. Should we submit a 10-403 variance request for this interim production? Thanks for the feedback. Jerry Dethlefs Phillips Problem Well Supervisor ----- Forwarded by NSK Problem Well Supv/PPCO on 02/27/02 08:47 AM ----- CPF3 Prod Engrs Sent by: Hai L Hunt 5CANNED NOV 0 1 2005 02/27/02 08:35 AM To: NSK Problem Well Supv/PPCO@Phillips cc: John C Patterson/PPCO@Phillips, NSK Artificial Lift/PPCO@Phillips Subject: 3H-05 ESP failure Jerry, 3H-05's Electrocoil ESP was turned off on 2/16 to do a scale inhibition squeeze. The pump would not start back up after the squeeze. On 2/25, Centrilift confirmed that there is a downhole short (that the ESP is really dead). The well is currently producing with the ESP turned off. Here is the production data. The top test is with the pump off. There is a chance that the scale inhibition treatment is affecting the numbers in this test (we'll scheduled to get another welltest soon). The next test is with the pump at close to minimum speed. The third test is with the pump at close to target/maximum speed. (Embedded image moved to file: pic15341.pcx) thanks -Hai Hai Hunt / Marie McConnell CPF3 Production Engineer Phillips Alaska Inc. ph: (907) 659-7871 1 of2 11/30/20048:58 AM Re: Phillips 3H-05 ESP failure ,) ) fax: ( 9 0 7 ) 6 5 9 - 7 6 0 9 ------------------------------------------------------------------------ Name: pic15341.pcx pic15341.pcx Type: PCX Image (application/x-unknown-content-type-pcxfile) Encoding: base64 20f2 11/30/2004 8:58 AM ~ -FO RM- -- FORM-- TOTL Pump Suction OS WL ----TEST END--- LENGTH STAT CHK FTP FTT SAND OIL WAT %WC FLUID GAS GOR GLR Sp eed PRES 3H 5 2/1912002 17:55 20:00 GD-A 37 110 126 AC. 399 1674 81 2073 386 966 186 0 1999 3H 5 2/111200220:36 17:13 GD-A 37 225 131 AC. 485 1201 71 1686 328 677 195 35.8 1571 3H 5 1 Æl12002 20:35 16:35 GD-A 37 210 138 AC. 581 1584 73 2165 375 645 173 44 1220 ~ ,-- oQ J í o J ,J Re: Phillips 3H-05 Subject: Re: Phillips 3H-05 ESP failure Date: Wed, 27 Feb 2002 10:07:49 -0900 From: Tom Maunder <tom_maunder@admin.state.ak. us> To: NSK Problem Well Supv <n1617@ppco.com> Jerry, Yes you should plan to submit a 403 much the same as was done previously. Be sure erosion and flow line inspections are addressed. That just makes sure we all have done the homework to avoid another 7-8. Based on the well test reports, the glr is relatively Iow so erosion shouldn't be much concern. Thanks for asking. Tom NSK Problem Well Supv wrote: Tom: The following email is from one of our PE's regarding the failure of Phillips 3H-05 ESP producing well. As you can see from the production tests the well will flow without the ESP running. As was the case with 3H-11, our intent will be to work the well over sometime this coming year. In the interim I am asking for permission to keep the well on line. Should we submit a 10-403 variance request for this interim production? Thanks for the feedback. Jerry Dethlefs Phillips Problem Well Supervisor ..... Forwarded by NSK Problem Weft Supv/PPCO on 02/27/02 08:47 AM ..... CPF3 Prod Engrs Sent by: Hal L Hunt 02/27/02 08:35 AM To: NSK Problem Well Supv/PPCO@Phillips cc: John C Patterson/PPCO@Phillips, NSK Artificial Lift/PPCO@Phillips Subject: 3H-05 ESP failure Jerry, 3H-O5's Electrocoil ESP was turned off on 2/16 to do a scale inhibition squeeze. The pump would not start back up after the squeeze. On 2/25, Centrilift confirmed that there is a downhole short (that the ESP is really dead). The well is currently producing with the ESP turned off. Here is the production data. The top test is with the pump off. There is a chance that the scale inhibition treatment is affecting the numbers in this test (we'll scheduled to get another welltest soon). The next test is with the pump at close to minimum speed. The third test is with the pump at close to target/maximum speed. (Embedded image moved to file: pic15341.pcx) thanks 1 of 2 3/21/02 12:02 PM Re: Phillips ~H-Ub I=~P tallure ~ -Hai Hai Hunt/ Marie McConnell CPF3 Production Engineer Phillips Alaska Inc. ph: (907) 659-7871 fax: (907) 659-7609 Name: pic 15341.pcx pic15341.pcx Type: PCX Image (application/x-unknown-content-type-pcxfile) Encoding: base64 Tom Maunder <tom maunder~.admin.state.ak, us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 2 of 2 3/21/02 12:02 PM pH LIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 May 22, 2001 Commissioner Camille Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 3H-05 (187-077) Dear Ms. Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent well work on KRU well 3H-05. If there are any questions, please contact me at 263-4574. Sincerely, Staff Engineer Phillips Drilling MM/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other_X Run ElectroColl 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1444' FNL, 4997' FEL, Sec. 12, T12N, RSE, UM At top of productive interval 4014' FNL, 1374' FEL, Sec. 11, T12N, RSE, UM At effective depth At total depth 4222' FNL, 1480' FEL, Sec. 11, T12N, RSE, UM 5. Type of Well: Development __X Explorato~__ Stratigraphic_ Service__ (asp's 498655, 6000211) (asp's 497000, 5997647) (asp's 496894, 5997433) 6. Datum elevation (DF or KB feet) RKB 76 feet 7. Unit or Property name Kuparuk Unit 8. Well number 3H-05 9. Permit number / approval number 187-077 / 10. APl number 50-103-20077 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length CONDUCTOR 80' SURFACE 4899' PRODUCTION 8484' 7166 feet Plugs (measured) 6199 feet 6400 feet Junk (measured) 5576 feet Size Cemented Measured Depth 16" 255 sx AS I 1 15' 9-5/8" 125o Sx AS III cmt, 425 Sx Class 3454' G, 100 sx AS I top job 7" 400 sx AS ~ 7150' True vertical Depth 115' 3127' 6186' Perforation depth: measured 6760'-6831',6839'-6859',6869'-6889',6894'-6914' true vertical 5869'-5926', 5933'-5949', 5958'-5974', 5978'-5994' Tubing (size, grade, and measured depth) 4.5", 12.6#, L-80 @ 6557' MD, 2.375" coil tubing @ 6351' Packers & SSSV (type & measured depth) Baker FB-1 w/4" Seal Bore @ 6510' MD No SSSV 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl 677 Representative Daily Average Production or Injection Data Gas-Mcr Water-Bbl 990 1960 790 359 2238 Casing Pressure Tubing Pressure - 173 122 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X 16. Status of well classification as: Oil uX Gas u Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SignedMike Mooney ~~..- ~?/~,,¢xu~¢/~ Title Staff Engineer Form 10-404 Rev 06/15/88 · Questions? Mike Mooney 263-4574 Date Prepared by Sharon A//sup-Drake 263-4612 SUBMIT IN DUPLICATE Date Comment 3H-05 Event History 11/16/00 MIRU DOWELL CTU. INSTALL PUNCH LOCKDOWN SCREW IN WELLHEAD. MU TRONIC CONNECTOR, PULL TEST TO 40K#. MU REMAINDER OF TRONIC HEAD. WAITING ON MISSING PART TO COMPLETE PRESSURE TEST. TEST BOP'S- TEST JOINT PARTS DURING TEST OF PIPE RAMS LEAVING STUB IN SLIPS. WORKING ON FISHING TEST JOINT STUB. [ESP Work] 11/17/00 FISH TEST JOINT STUB FROM STACK. COMPLETE MU UPPER TRONIC CONNECTOR, MEG & PHASE CABLE. LOAD COIL WITH HYDRAULIC FLUID. ADDRESS CONCERN ABOUT OVERPRESSURING BAKER SENTRY GAUGES. BE~GIN MU ESP BHA- STINGER & SEAL ASSY, PUMP, THRUST CHAMBER, MOTOR, EXPANSION CHAMBER. CONTINUE MU BHA AT REPORT TIME. [ESP Work] 11/18/OO COMPLETE MAKING UP PUMP AND MOTOR ASSEMBLY, INSTALL TRONIC CONNECTOR, RIH AT 25 FPM TESTING CABLE AND I-WIRE. STING INTO PACKER/SBE AND MARK PIPE AT 6530.6' CTM (2.5' ABOVE TAG). MARK PIPE, HOT TAP TUBING AND PREPARE TO CUT COIL TUBING. [ESP Work] Page I of I 5/24/01 xover for KRU 3A-03 Subject: Workover for KRU 3A-03 Date: Mon, 3 May 1999 09:25:25 -0900 From: "Chip Alvord" <CALVORD~mail.aai.arco.com> To: Blair_wondzell@admin. state, ak.us CC: "Mark A Chambers" <MCHAMBE2~mail.aai.arco.com> Blair, As a follow up to our discussion this past weekend: I misinformed you on the two wells I thought had previously had sundrys approved for electrcoil recompletions - I told you the wells were 3H-11 and 3H-03 and they are actually 3H-11 and 3H-05. These recompletions are coil deployed ESP completions. The ESP cable is inside the 2-3/8" coil tubing and the well is produced via the 2-3/8" x 7" tbg/csg annulus. The scope of the rig preparation for these wells will be to kill the well, retrieve the existing completion and clean out to PBTD (3H-11 had a single selective completion and 3A-03 is a packerless ESP completion with a failed ESP). A USIT log will be run as a caliper to ensure the casing is of sufficient thickness where flow exits the crossover from the packer bore to the annulus, near the top of the packer assembly. The lower packer assembly contains dual flapper vavles, wellbore shut-off devices. The rig will finally install the proper wellhead equipment to for the ESP installation. After the rig is released the final ESP/electro-coil completion will be run with a coiled tbg unit 3A-03 was selected in lieu of 3H-05 due to the higher PI of the well and the increased oil production to be realised. Sorry for the confusion this past weekend and thanks for you help resolving the situation. Please call if you have any questions (265-6120). Regards, Chip Alvord 1 of 1 5/3/99 10:03 AM ARCO Alaska, Inc. Kuparuk Operations Post Office ~o× 196105 Anchora§e, A~aska 995!9-6! 05 Telephone 907 659 2821 February 4, 1998 Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Wondzell' In response to your request for additional information during our meeting of January 21s', the following comments are supplied. Corrosion There will be corrosion effects on the casing over time. The extent of the corrosion or rate of corrosion has not been quantified at this time. However, based on observations of corrosion in conventional tubing it is expected that the rate of corrosion would not be greater than what has been observed to date in uncoated production tubing. There are corrosion coupons currently installed on the Kuparuk production flowlines. The coiled tubing deployed pumps would also have the corrosion monitoring coupons installed. The coupon inspection program would probably be more frequent in the early life of the pump installation until a base line could be established. Currently nearly all the conventional wells yield "A" grade coupons which translates to wall loss less than 1 mil per year and pit loss less than 5 mil per year. Velocity assisted corrosion would not likely be a factor, due to the moderate velocities produced by the pumps. Since the coiled tubing deployed pumps take all the wellbore fluid through the pump the fluid will be highly emulsified. Production fluids will probably be an oil external emulsion until the water phase reaches 80%, then the emulsion would become water external. This will tie up a substantial amount of the free water, which would help in reducing free water induced corrosion. Hydrogen Sulfide is present in many parts of the field. concentrations will require a more rigorous evaluation candidates fOr Coil tUbing deployed pumps. Areas with high before becoming ARCO Alaska, Inc. is a Subsidiary of AHanticRichfieldOompany Blair Wondzell February 4, 1998 Page 2 Erosion Presently the coiled tubing deployed pumps have exit ports aligned at approximately 30 degrees to the axis of the casing so there will be some degree of impingement. At maximum rates the exit velocity of the fluid is expected to be approximately 15 fi/sec. Manufacturer's recommended maximum velocity to achieve acceptable wear is 25 fi/sec based on testing various pump stages in their test facility sand loops. Abrasive materials aisc wiii erode pump internals causing them to loose efficiency, which in turn reduces volume and velocity. These figures are also confirmed by our frequent inspection of surface piping downstream of our chokes where no erosion problems have occurred when velocities are 25 fi/sec or less. Initial installations of the two pumps will have a casing inspection Icg run prior to running the pump in order to establish a base line. A follow up Icg will be run when the pump is removed for the first time. The initial target run life for the pump is 3 to 5 years. Sincerely yours, ~CPF_3 Dri~up(~~l or ' !il cc; M. Zanghi, ATO-1276 S. P. Kruse, ATO-1128 j. B. Kewin, NSK-69 M.W.Wheatall, NSK-22 Schematic of Coil Tubing Deployed ESP Wellhead Feb. 2,1998 power cable high pressure pilot Iow pressure pilot surface casing production casing coil tubing surface saftey valve master valve STATE OF ALASKA AL,,...,,~, OIL AND GAS CONSERVATION COMMISo~ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate X Pull tubing Alter casing Repair well 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 1446' FNL, 281' FWL, Sec. 12, T12N, R8E, UM At top of productive interval 1268' FSL, 1375' FEL, Sec. 11, T12N, R8E, UM At effective depth 1111' FSL,' FEL, Sec. 11, T12N, R8E, UM At total depth 1061' FSL, 1454' FEL, Sec. 11, T12N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 71 5 5 feet 61 90 feet Plugging Perforate __ Other 6. Datum elevation (DF or KB) RKB 76 feet 7, unit or Property name Kuparuk River Unit 8. Well number 3H-05 9. Permit number/approval number 87-77 10. APl number 50-103-20077-00 11. Field/Pool Kuparuk River Field/Oil Pool Plugs (measured) None Effective depth: measured 7 0 6 0 feet true vertical 61 1 2 feet Junk (measured) 1" DV in rathole Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 80' 16" 3415' 10-3/4" 7115' 7" Cemented Measured depth True vertical depth 255 Sx AS I 1 15' 1250 Sx AS III & 3454' 425Sx Class G w/100 Sx AS I top job 300 Sx Class G & 71 5 0' 400 Sx AS I measured 6760'-6831',6839'-6859',6869'-6889',6894'-6914' true vertical 5869'-5926',5933'-5949',5958'-5974',5978'-5994' Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., J-55 @ 6691' Packers and SSSV (type and measured depth) Pkr: Baker FH @ 6617'; SSSV: 115' 3127' 6186' Otis Series 10 @ 1785' 13. Stimulation or cement squeeze summary Fracture stimulate A & C sands on 9/25/97. Intervals treated (measured) 6760'-6831',6839'-6859',6869'-6889',6894'-6914' Treatment description including volumes used and final pressure Pumped 247.8 Mlbs of 20/40 and12/18 ceramic proppant into the formation, fp was 4816 psi 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 614 392 878 1305 165 1 61 1 866 3075 1314 163 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. Form I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Wells Superintendent ARCO Alaska, Inc. KUPARUK RIVER UNIT . , ~' WELL SERVICE REPORT ~ K1(3H-05(W4-6)) ,, WELL JOB SCOPE JOB NUMBER 3H-05 FRAC, FRAC SUPPORT 0625972016.6 DATE DAILY WORK UNIT NUMBER 09/25/97 PUMP "A" & "C" SAND REFRAC _ DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 12 (~) Yes O NoI ® Yes O No DS-YOKUM BLACK FIELD AFC~ CC~ DAILY COST AOOUM COST ~~~Fi~na~l 0 - ESTIMATE KD1214 230DS36HL $153,216 $212,460 Initial Tb.q Press Final Tb.q Press Initial Inner Ann Final Inner Ann I Initial Outer Ann uter Ann 1630 PSI 4820 PSI 200 PSI 500 PSII 450 PSII 500 PSI DAILY SUMMARY I TIME LOG ENTRY 08:30 MIRU DS FRAC (YOAKUM & CREW), LRS & APC. HOLD TGSM (15 ON LOCATION) & CONDUCT JOB OVERVIEW. PT BACKSIDE LINES TO 4000 PSI & PT PUMPING EQUIP / LINES TO 9000 PSI. 12:00 13:15 14:00 PUMP BREAKDOWN @ 15 - 30 BPM 50# XL GW W/1 & 2 PPA STAGES. PUMPED TOTAL OF 403 EELS. STEP DOWNS @ 2825, 2400 & 2200 PSI. ISIP = 1928 & P'O ~: .7"¢'. Si') ~ MONITOR PRESSURES F/CLOSURE. PULSE BACK TO ISIP & MONITOR. PUMP DATA FRAC @ 5-15 BPM 50# XL GW. PUMP TOTAL OF 2'73" BBLS. ISIP=2270 PSI & FG=.89. SD & MONITOR PRESSURES F/CLOSURE. ADJUST PAD TO 840 BBLS FROM 550 BBL DESIGN. PUMP FRAC F/5-15 BPM 50# XL GW. COMPLETED JOB THROUGH FLUSH (2 PPA THRU 12 PPA ENDPOINT). PUMPED TOTAL OF 2830 BBLS FOR JOB (403 BBLS ED, 273 BBLS DF & 2154 BBLS FRAC). PUMPED 257,181 LBS TOTAL PROP W/249,165 LBS PROP DURING FRAC (23,321 LBS 20/40 & 225,844 LBS 12/18). PUMPED TOTAL OF 247,765 LBS IN FORMATION & LEFT 1400 LBS IN PIPE. FREEZED PROTECTED W/40 BBLS DIESEL TO 4600'. 16:30 DEPRESSURE LINES & IA TO 500 PSI. RD LRS. CONTINUE RD. REMOVE TREESAVER (ALL CUPS RETURNED). FINALIZE RD. 17:45 DS OFF LOCATION. WELL SECURED & SI AWAITING POST FRAC WORK. TURNED OVER TO PRODUCTION. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $1,855.00 APC $8,400.00 $14,675.00 ARCO $300.00 $500.00 DIESEL $0.00 $250.00 DOWELL $142,316.00 $159,716.00 HALLIBURTON $0.00 $25,404.00 LR-FLE RED $2,200.00 $10,060.00 TOTAL FIELD ESTIMATE $153,216.00 $212,460.00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Service 4. Location of well at surface 1446' FNL, 281' FWL, Sec. 12, T12N, R8E, UM At top of productive interval 1268' FSL, 1375' FEL, Sec. 11, T12N, R8E, UM At effective depth 1100' FSL, 1400' FEL, Sec. 11, T12N, R8E, UM At total depth 1061' FSL, 1478' FEL, Sec. 11, T12N, R8E, UM Abandon_ Suspend_ Operation Shutdown_ Alter casing _ Repair well _ Plugging _ Change approved program _ Pull tubing 5. Type of Well: Development ~ Exploratory _ Stratigraphic _ 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical 7166' feet 6199' feet 7026' feet ' feet Plugs (measured) Junk (measured) Re-enter suspended well _ Time extension _ Stimulate _ Variance Perforate Other X 6. Datum elevation (DF or KB) 76' RKB feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3H-05 9. Permit number/approval number 87-77 / Apprv. N/A lO. APl number 50-103-2007700 11. Field/Pool Kuparuk River Oil Pool ORI$1NA Casing Length Size Structural Conductor 80' 16" Surface 3419' 10 3/4" Intermediate Production 7115' 7" Liner Perforation depth: measured Cemented Measured depth True vertical depth 215 Sx AS I 115' 115' 1250 Sx AS III & 3454' 3127' 425 Sx Class G performed top job w/100 Sx AS I 650 Sx Class "G" & 7150' 6186' 300 Sx AS I 6760'-6831', 6839'-6859', 6869'-6889', 6894'-6914' MD true vertical 5869'-5927', 5933'-5950', 5958'-5974', 5978'-5994' TVD Tubing (size, grade, and measured depth) 3 1/2" 9.3 Ib/ft, J-55, 6691' MD RKB Packers and SSSV (type and measured depth) Baker FHL PKR. @ 6617', Otis Series 10 SSSV @ 1785' 13. Attachments Description summary of proposal ~ Detailed operation program _ BOP sketch _ CONVERT WELL FROM GAS LIFT TO COILED TUBING DEPLOYED ELECTRIC SUBMERSIBLE PUMP 14. Estimated date for commencing operation JUNE 11 1998 16. If proposal was verbally approved ,l~ame of approver Blair Wondzell Date approved Service 17. I h~y ~ert~y that the foregoing is true and correct to the best of my knowledge.. / Signed ~' ~'~::::~ ~ ~ Title Drillsite Supervisor FOR COMMISSION USE ONLY Conditions of approval: Notify Commiss~n so repres.,~3tative may witness Plug integrity _ BOP Test ._/ Location clearance __ Mechanical Integrity Test_ Subsequent form require 10- ~'~ ~ C ';~!~ai S!gned By [~.\'~d W. Johnston Approved by order of the Commission Commissioner Form 10-403 Rev 06/15/88 15. Status of well classification as: Oil x Gas _ Suspended _ To be reclassified as: Date Date 12/20/97 SI~BMIT IN TRIPLICATE Approved COP'/ Returned -, --2 5/8" COILED TUBING --B.O.T. GAUGE MOUNT(S) -- B.O.T. GAUGE SYSTEM -- TEC WIRE --CENTRILIFT POWER CABLE __ CASING, SHOWN OUT OF POSITION TEC WIRE CONNECTION TRANSITION ASSEMBLY (COIL TUBE-ESP ASM.) SHEAR AREA OF TRANSITION ASM. EXPANSION CHAMBER --&: POWER FEED THRU SERIES 51,3 ACTUAL CROSS SECTION __CASING (7"© 26#/FT.) SHOWN OUT OF SCALE UPPER MOTOR ASM. SERIES ,562 MT __ CENTRALIZER(S) ALL NECK LOCATIONS LOWER MOTOR ASM. SERIES 562 MT -- CAPILLARY TUBE (1/4") THRUST CHAMBER ASM. SERIES 51 5 PUMP DISCHARGE PORTS -- SAND SKIRT ASM. __UPPER PUMP ASM. (MT) SERIES 51.3 AR SPECIAL __ LOWER PUMP ASM. (MT) SERIES 51,3 AR SPECIAL --SPECIAL PUMP INLET INTAKE PRESSURE SENTRY CONNECTION -- STINGER POLISHED BORT RECEPTACLE --(ON/OFF TOOL) -- PACKER ASSEMBLY ~PRODUCTION ZONE/PERFS EQUIPMENT STACK ARCO ALASKA_ INC, F R OI,N: CPF THREE ARCO Alaska Inc Fa]( FAX NO.: 659 7689 12-05-97 10:54R P.01 To; Blair Wondzell From,, Mike Winfree Fax: 276-7542 Pages: 2 w/o cover Phone: 279-1433 Bate: 12/05/97 Re: Annular production CC: n urgent X For Review ~ Please Comment [] please. Reply [] Ple.~ Recycle · Comments; Blair .... As we discussed on the phone, We are looking at applying the technology of coiled tubing deployed ESP's in the Kuparuk field and would like to have consent from the AOGCC for annular production before we commit additional time and money to the project. Please read it over and if you have any questions give me a call on the slope at 659-7407, I'm working a 7 on 7 off schedule and my atternates's name is Ron Marquez. He or I will be able to answer any questions you might have. Thanks .... RECEIVED DEC - 5 ]997 Anchorage FROU: CPF THREE FAX NO.: 659 ?609 12-05-97 10:54A P.02 ARCO Alaska, Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 5, 1997 Mr. David W. Johnston, Chairman Alaska Oil And Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK; 99501 (907) 279-1433 (907) 276-7542 (fax) RECEIVED DEC - 5 199/' Naska 011 & Gas Cons. Commi~ Anchorage Re; Waiver Request to Allow Annular Production in KRU Electric Submersible Pump (ESP) Completions Deployed on Internal Power Cable Coile~J Tubing (ElectroCoil) Gentlemen: ARCO requests a waiver to the AOGCC Regulations covering downhole production equipment. The waiver being requested is to Section (d) of 20 AAC 25.200, which requires wells capable of unassisted flow to have the tubing x casing annulus isolated from produced fluids. The waiver is requested to cover those wells with-in the Kuparuk River Unit, to be completed with electric submersible pumps (ESPs) deployed on Internal Power Cable Coiled Tubing (ElectroCoil). The typical Kuparuk ESP completion is deployed on jointed tubing with the ESP power cable banded to the outside of the tubing. The pump is set immediately above the pedorations and produced liquids are drawn into the pump and discharged into the production tubing. Produced gas is diverted past the pump, up the tubing x casing annulus, and commingled into the production tubing through a shallow gas lift mandrel. Produced fluids exit the well from the production tubing at the wellhead. The proposed 'ElectroCoil' ESP completion is run in the hole on coiled tubing prepped with the ESP power cable inside. The completion is landed in a production packer set immediately above the perforations. Integral to the production packer is a polished bore receptacle and 'flapper type' shut-off valve. When the completion is landed, a seal assembly enters the polished bore creating a hydraulic seal. A stinger run below the seal assembly will open the shut-off valve, allowing communication with the perforations. Production is drawn through the packer by the ESP, and discharge from the pump is into the coiled tubing x casing annulus. Produced fluids flow up the tubing x casing annulus and out the well through the annulus valve in the tubing head. Surface safety systems will be identical to existing conventional trees. However, since production is through the annulus valve, the tree will be in a horizontal position. All wells will be equipped with two high pressure shut-down sensors designed to shut down the pump if the coiled tubing x casing annulus exceeds a pre-determined pressure (significantly below the burst rating of the casing).~ ~hile in production mode, suHace pressure of the coiled tubing x casing ARCO A]asU, lac. ~s a $~bsi~ of AtlanticgichSe]dCo~aoy ~~ ~ O~ ~¢ F~:O~I: CPF THREE FI:IX NO.: 659 7609 12-05-97 10:54Pl P.03 annulus is expected to be equivalent to production header pressure (+/-150 psi). Variations to this pressure should only exist when the well is shut-in or when free flow of produced fluids is restricted. The 'ElectroCoil' completion is desirable to ARCO for several reasons. First, friction pressure consumes approximately 50% of the submersible pump horsepower on current ESP completions. The effective diameter of the coiled tubing x casing annulus is significantly larger than the current production tubing, resulting in substantially lower friction pressures. In addition, the ability to run and retrieve ESP's using a coiled tubing unit will reduce installation and workover cost, as well as pump downtime. Both of these examples will help to substantially redUce ESP operating costs, allowing more ESP installations and increased production rates. It is ARCO's desire to make 'ElectroCoil' ESP completions a safe, efficient, and cost effective operation in the Kuparuk River Unit. ARCO has one 'ElectoCoil' completion installed offshore in Qatar and a second installation is planned for later this year at ARCO's THUMS operation in California. A full-scale test of the proposed system for Kuparuk is currently scheduled for early second quarter of 1998. ARCO is requesting your early approval of this waiver request in order to commit the funds necessary to proceed with this project. We appreciate your consideration of this request. If you have any questions or require any additional information on this matter, please contact me at 265-6206. Sincerely, Cc: Mike Wheatall NSK 22 Mike Zanghi ATO 1276 Bill Isaacson ATO 1290 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] ... 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 87-77 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 103-20077 "4. Location of well at surface 9. Unit or Lease Name 1446' FNL, 281' FWL, Sec.12, T12N, R8E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1268' FSL, 1375' FEL, Sec.ll, T12N, R8E, UM 3H-5 At Total Depth 11. Field and Pool 1061' FSL, 1478' FEL, Sec.ll, T12N, R8E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk Ri vet 0i 1 Pool RKB 76' ADL 25531 ALK 2657 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 09/09/87 09/13/87 03/29/88*I N/A feet MS L 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 7155'MD, 6190'TVD 7060'MD, 6112'TVD YES ~ NO []1 1781 feet MD 1600' (approx.) 22. Type Electric or Other Logs Run DIL/SP/SFL/GR, FDC/CNL, Cal, FMS, CBL, Gyro - , , 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 115' 24" 25,5 ~xA:$ I 9-5/8" 36.0# J-55 Surf "' 3454' 12-1/4" I 1250 sx AS Ill & 425 sx Class G I Top lob performed w/10£ sx AR I 7" 26.0# J-55 Surf 7150' 8-1/2" 300 sx Class G & 400 s~ AS , 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) .. Perforated w/8 spf, 60° phasing 3-1/2" 6680' 6760'-6831 'MD 5869'-5926'TVD 6839'-6859'MD 5933'-5949'TVD 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. Perforated w/4 spf, 0° phasing DEPTH INTERVAL (MD) AMOUNT & KiND OF MATERIAL USED 6869'-6889'MD 5958'-5974'TVD See Addendum attach~:d to well e-nmpletion repnr~ Perforated w/1 spf, 120° phasing dated 4/20/88. for ~ran~..r~. 6894'-6914'MD 5978' -5994'TVD ::'7. PRODUCTION TEST I ' Date First Production Method of Operation (Flowing, gas lift, etc.) N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAV'I'TY-API (corr) Press. 24-HOUR RATE ~i 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chipsl None RECEIVED JUN 2 3 1988 Aia~l~ 0il & Gas Cons. Commission *Note: Drilled RR 9/16/87, Perforated well & ran tubing 12/9/87, Fractured well 3729~I~I. orage Workover performed 5/26/88, Perforations added 5/31/88, Form 10-407 Submit in duplicate ~' , Rev. 7-1-80 CONTINUED ON REVERSE SIDE WC4/77 :DANI ~ 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 6759' 5868' N/A Base Kuparuk C 6836' 5931' Top Kuparuk A 6836' 5931' Base Kuparuk A 6961' 6032' 31. LIST OF ATTACHMENTS Addendum (dated 6/1/88~ 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed {~(J ~")'~./¥(~_, ~_~J,.~)-/,M~ // Title Associate Encjineer Date .... INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' AttaChed supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 4120188 5/30/88 and 5/31/88 3H-5 RU Gearhart. RIH w/strip gun; stopped @ SSSV, POOH. RIH w/CCL/Sinker Bar; stopped @ SSSV. Pmp open w/hot oil truck, POOH. RIH w/gun #1, tagged @ btm GLM; wrk'd w/o success. POOH. Chg decentralizer 30°, RIH; stopped, POOH. RIH w/CCL/Sinker bar; stopped, POOH. RD Gearhart & RU Otis. Pmp SSSV open; leaking badly. TIH w/2.3" impression block, POOH. RIH w/2.5" impression block; machine mark on one side inside of GLM pocket. RIH w/3½" OM locator tool & 1-3/4" impression block; unable to locate in pocket, POOH. RIH w/braided in brush, wrk'd @ btm GLM; unable to wrk into or get past. POOH & RD. RU Gearhart. Perf 6889'-6869' @ 4 SPF, 0° phasing. Perf 6859'-6839' @ 8 SPF @ 60° phasing & 6831'-6760' @ 8 SPF. 60° phasing. D~i~g Super~or RECEIVED JUN 2 ~z 1988 Alaska Oil & Gas Cons. Commission 'Anchorage ,- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM,.....,ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] 'Plugging ~ Perforate ,'~ Pull tubing ~X Alter Casing [] Other I~ WORKOVER 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1446' FNL, 281' FWL, Sec.12, T12N, R8E, UM At top of productive interval 1268' FSL, 1375' FEL, Sec.11, T12N, R8E, UM At effective depth 1111' FSL, 1454' FEL, Sec.11, T12N, R8E, UM At total depth 1061' FSL, 1478' FEL, Sec.11, T12N, RSE, UM 5. Datum elevation (DF or KB) RKB 76' 6. Unit or Property name Kuparuk River Unit 7. Well number 3H-5 8. Approval number 8-367 9. APl number 50-- 103-20077 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical 7155'MD 6190'TVD Effective depth: measured 7060'MD true vertical 6112 ' TVD Casing Length Size Conductor 80' 16" Surface 3420' 9-5/8" Producti on 7115 ' 7" Perforation depth: measured 6894 ' -6914 ' feet feet feet feet Plugs (measured) None Junk (measured) None Cemented Measured depth 255 sx AS I 115'MD 1250 sx AS III & 3454'MD 425 sx Class G Performed top job w/lO0 sx AS I 300 sx Class G & 7150'MD 400 sx AS I True Vertical depth 115'TVD 3127 'TVD Feet 6186 'TVD Date Submit in Duplicate ~/ true vertical 5978'-5994' Tubing (size, grade and measured depth) 3-1/2", J-55, tbg w/tail ~ 6691' Packers and SSSV (type and measured depth) FHL pkr ~ 6617' & TRSV SSSV @ 1785' 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure RECEIVED JIIN ! o 1988 Alaska 0ti & Gas Cons. Commlsslo~l Anchorage 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Workover Wel l[]~tistory & Addendum, dated 5/23/88) Daily Report of Well Operations Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-85 Title Associate Engineer (Dani) SW03/002 ADDENDUM 4~20/88 3H-5 RU Gearhart. RIH w/strip gun; stopped @ SSSV, FOCI-I. RIH w/CL'~/Sinker Bar; stopped @ SSSV. Pmp open w/hot oil truck, PCK~. RIH w/gun #1, tagged @ btm GLM; wrk'd w/o success. ~. Chg decentralizer 30°, RIH; stopped, ~. RIH w/CL-~/Sinker bar; stopped, POCI-I. FiD Gearhart & RU Otis. Prop SSSV open; leaking badly. TIH w/2.3" impression block, FOCI-I. RIH w/2.5" impression block; machine mark on one side inside of GLM pocket. RIH w/3½" ClVI locator tool & 1-3/4" impression block; unable to locate in pocket, B3OH. RIH w/braided In brush, wrk'd @ btm GLM; unable to wrk into or get past. B3Ct{ & I~D. RECEIVED JUN 1 0 19B Alask~i Oil & Gas Cons. Commission ~-l~i, ~n(;ttorage ' ' Dri 1 iing Sf~pervi sor I ARCO O, and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are starled. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ARCO Alaska, Inc. KUPARUK RIVER UNIT County. parish or borough NORTH S:LOP w.. Lease or Unit ADL: 25531 Title WORKOVER 3H-5 IWell no. Field Auth. or W.O. no. AK2483 Operator API: 50-103-20077 t ARCO W I 56.0000 tDate IHour Prior status if a W.O. 05/23/88 2130 HRS ARCO Spudded or W.O. begun ACC'~?T Date and depth as ot 8:00 a.m, 05/24/88 TD: ?B: 7060 SUPV:SC 05/25/88 TD: PB: 7060 SUPV:SC 05/26/88 TD: PB: 7060 SUPV:SC Complete record for each day reposed NORDIC 1 RIH W/ TBG PERFORATOR MW: 9.8 NACL/NABR MOVE RIG TO 3H-5. RIH W/ TBG PERF. PULL OFF PERFORATOR IN SSSV. BULL HEAD WELL FULL OF DIESEL. RIH W/ TUBING PERFORATOR. DAILY:S21,825 CUM:$174,423 ETD:S174,423 EFC:$740,000 REDRESS PBR SEALS PERF TBG F/ 6519-6521'. ND TREE. NU TEST BOPE. MW: 9.8 NACL/NABR PUMP BRIDGE SAL PILL AND KILL WELL. POOH W/ BENT TBG AND GLM. DAILY:S56,337 CUM:$230,760 ETD:S230,760 EFC:$740,000 RIH W/ VALVE MW: 9.8 NACL/NABR RIH W/ TBG OE. LD BENT PIPE. POOH W/ TBG. RIH W/ 3-1/2" COMP EQUIP AND TBG. STING INTO PKR. RU OTIS. RIH W/ 2.7 GR THRU TBG TAIL. RIH W/ STANDING VALVE. DID NOT SHEAR OFF. POOH. CHANGE LATCH. RIH W/ STANDING VALVE. SSSV @ 1785', FHL PKR @ 6617', TAIL @ 6691' DAILY:S32,100 CUM:$262,860 ETD:S262,860 EFC:$740,000 RECEIVED JUN 1 0 1988 Alaska 0il & Gas Cons, Commission Anchorage The above is correct Signature For, ........ ,,o see Proce~urPes M'en~l, S?¢~Ir~nbUlt'O.°n' Drilling, Pages 86 and 87. Date Title 8-7-~ [ ASSOCIATE AR3B-459~1-D INumber all dally well history forms consecutively Page no. as they are prepared for each well. I I ARCO ~jil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned, or Sold. "Final Report" should be submitted also when operations are Suspended for an indefinite or appreciable length of time. On workovers when an official test le not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District ARCO Alaska, Inc. KUPARUK RIVER UNIT County or Parish NORTH SLOPE ILease or Unit ADL: 25531 ITitle WORKOVER State AK 3H-5 [Well no. Auth. or W.O. no. AK2483 API: 50-103-20077 Operator A,R.Co. W.i. ARCO 56.0000 Spudded or W.O. begun Date ACCEPT 05/23/88 Iotalnumber of wells (active or inactive) on this ost center prior to plugging and J bandonment of this well I our I Prior status if e W.O. 2130 HRS Date and depth as of 8:00 a.m. 05/27/88 ( 1 TD: PB: 7060 SUPV:SC Comptete record for each day reported NORDIC 1 RIG RELEASED MW: 6.9 DIESEL TEST TBG TO 1000 PSI TO VERIFY POSITION. SPACE OUT AND LAND TBG. TEST CONTROL LINE TO 5000 PSI, TBG TO 2500 PSI, ANNULUS TO 2500 PSI AND SSSV TO 1500 PSI. ND BOPE. NU AND TEST TREE TO 5000 PSI. DISPLACE WELL W/ DIESEL. TEST CV TO 1000 PSI. SET BPV. RELEASE RIG AT 1330 HRS 5/26/88. DAILY:S32,634 CUM:$295,494 ETD:S295,494 EFC:$740,000 Old TD [ New TD PB Deplh Rel drig .... IDate IK'nd of rig Classifications (oil, gas, etc.) Producing method Potential test data Type completion (single, dual, etc.) IOfficial reservo r name(s) ~ell no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day P~mp size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct ~ ~/r~J]4., .~.~, 5{.~ ~-7-ga~ ASSOCIATE ENGINEER For form preparatioq/al~d distribution, see Procedures Man[u~l, Section 10, Drilling, Pages 86 an"~ 87. AR3B-459-3~C Number all dally well history forms consecutively I Page no. [as they ere prepared f ..... h wel. I Dlvl~/on of AtlantlcRIchfleldCompany STATE OF ALASKA --" ALASK.. OIL AND GAS CONSERVATION COMM._,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~ Operation Shutdown [] Re-enter suspended well Q Alter casing C; Time extension ~ Change approved program © Plugging [] Stimulate []. Pull tubing ~,. Amend order ~ Perforate C~ Other~ 2. Name of Operator ARCO Alaska. Inc, ,. 3. Address P. 0. Box 1 00360, Anchoraqe, AK 99.51 0-0~.60 4. Location of well at surface 1446' FNL, 281' FWL, Sec.12, T12N, R8E, UM At top of productive interval 1268' FSL, 1375' FEL, Sec.ll, T12N, R8E, UM At effective depth 1111' FSL, 1454' FEL, Sec.ll, T12N, R8E, UM At total depth 1061' FSL~ 1478' FEL, S¢c.11: T12N: RRF'; IIM 11. Present well condition summary Total depth: 'measured 7155 ' MD feet Plugs (measured) true vertical 6190 ' TVD feet 5. Datum elevation (DF or KB) RKB 76 ' 6. Unit or Property name K,,.n~r,~k River Ilnil- 7. VVell number 3H -5 8. Permit number 87-77 9. APl number 50-- 1 03-20077 10. Pool None Pool feet Effective depth: measured feet 7060'MD true vertical feet 611 2 ' TVD Casing Length Size Cemented Junk (measured) None Measured depth True Vertical depth Conductor Surface 80 ' 1 6" 3420 ' 9-5/8" 711 5 ' 7" Production Perforation depth: measured 6894'-6914' 255 sx AS I 115'MD ll5'TVD 1250 sx AS Ill & 3454'MD 3127'TVD 425 sx Class G Performed top job w/lO0 sx AS I 300 sx Class G & 7150'MD 6186'TVD 400 sx AS I true vertical 5978'-5994' RECEIVED Tubing (size, grade and measured depth) 3-1/2", J-55, tubing w/tail ~ 6680' Packers and SSSV (type and measured depth) FHL pkr (~ 6606', Otis SSSV ¢ 1781' 12.Attachments Description summary of proposal~,,. Alaska Oil & Gas Cons. Commission Anchorage Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation June 1, 1988 14. If proposal was' verbally approved Name of approver ate approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~,~~ Title Associate Engineer ~ Commission Use Only ( J G ) SA3/96 Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI Date App edby( L:~'"'~ L '~"~~ Form 10-403 Rev~-i'~A-1-85 t/ / Copy Returne~l~.~ C~'~miss~oner the commission Date SuUmit,/fn triplicate Kuparuk River Unit 3H-5 General Workover Procedure Pre-Rig Operations 1. Load tubing with diesel. 2. Set plug in 'D' nipple. 3. Test tubing. 4. Pull dummy valve from GLM above 'FHL' packer. Rig Operations 1. MIRU Nordic Rig #1. 2. Displace tubing and annulus with kill weight brine. 3. ND tree. NU BOPE. 4. Pull tubing, standing back same. Identify restriction in tubing. 5. Re-run single completion. Release rig. Expected BHP = 3000 psi Expected bring weight = 10.0 ppg NaC1/NaBr Anticipated start date = June 1, 1988 HPAD/3H-5a ih Alaska ()ii & Gas Cons, Commissio. Anchorage i ! ! ANNULAR PREVENTER § PIPE RAHS 4 BLIND RAHS 5 TUBIN6 HEAD 1. 16" CONDUCTOR SWAGED TO 9-5/8" 2. 11"-3000 PSI STARTING HEAD 3. 11 "-3000 PSI X 7-1 / 16"-5000 PSI TUBING HEAD 4. 7-1/16" - 5000 PSt PIPE RAMS 5, 7-1/t6" - 5000 PSI BLIND RAMS 6. 7-1/t6" - $000 PSI ANNULAR ACCUMULATOR CAPACITY TEST 1, CHECK AND FILL ACCUMULATOP P. ESEI~\/OIP. TO P~OPE~ LEVEL WITH HYDRAULIC FLUID. .~,'-' Z~$SLI.DE THAT ACCUMLILATOD. PRESSURE tS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR, 3, OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED 'WITH CHARGING PUMP OFF, 4, RECORD ON THE IADC REPORT, THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE, BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2, CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD, RUN IN LOCK-DOWN SCREWS IN HEAD, 3, CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD, 4, TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES, 5, INCREASE PRESSURE TO 1800 PSI AND HOLD FOR 10 MINUTES, BLEED TO ZERO PSI, 6. OPEN ANNULAR PREVENTER AND CLOSE PIPE RAMS, 7, INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES, 8, CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSt TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM, BLEED SYSTEM TO ZERO PSI, 9, OPEN PIPE RAMS, BACKOFF RUNNING JOINT AND PULL OUT OF HOLE, CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES, BLEED TO ZERO PSt, 10, OPEN BLIND RAMS AND RECOVER TEST PLUG, MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION, 11, TEST STANDPIPE VALVES TO 3000 PSI, 12, TEST KELLY COCKS AND INSIDE BOP TO :3000 PSI WITH KOOMEY PUMP, 13, RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM, SIGN AND SEND TO DRILLING SUPERVISOR, 14, PERFORM COMPLETE BORE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BORE DAJL,~." ~..~ ~'~ ,A~chora,ge JG JULY 28, 1986 (NORDIC RIG 9-5/8") ARCO Alaska, Inc, Date: April 20, 198'8 Transmittal #: 7146 RETURN TO: ARCO Alaska, Inc. Attn: Sabrina A. McKnuckles Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one s~gned copy of this transmittal. --'-J 1 G- 16 Kuparuk Well Pressure Report 2- 8 - 8 8 Static 'C' Sand '----~1G-09 KuParuk Well Pressure Report 2- 3- 8 8 'A' Sand ~----~1 G-09 Kuparuk Well Pressure Report 2- 3 - 8 8 Static 'C' Sand 1G-09 KUparuk Well Pressure Report 2- 3- 8 8 Static Both Sands --~%~ 2C-04 Kuparuk Well Pressure Report 1 2- 1 3-8 7 'A'Sand ~ 3H-05 POst-Frac Report 4~6-88 AIIo Frao 10 '"'%3H-02 Post-Frac Report 4- 6-88 AIIo Frac 10 '...----~3 H -03 Post-Frac Report 4 - 6 - 8 8 AIIo Frac 10 "'~'%'~ 3 H- 0 7 Treatment Report 4 - 1 3 - 8 8 '~ 1 Y- 1 4 Pulse Test 3- 1 1 - 8 8 'A' & 'C' Sands Receipt Acknowledged' DISTRIBUTION: D & M ~t~tl~'of 'Alask~ Date: Chevron Mobil SAPC Unocal STATE OF ALASKA ~ ~ ALASKA uiL AND GAS CONSERVATION C(,.,MMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~j~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 87-77 3. Address 8. APl NUmber P. 0. Box 100360, Anchorage, AK 9951 0-0360 50- 103-20077 , 4. Location of well at surface 9. Unit or Lease Name 1446' FNL, 281' FWL, Sec.12, T12N, R8E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1268' FSL, 1375' FEL, Sec.11, T12N, R8E, UM 3H-5 At Total Depth 11. Field and Pool 1061' FSL, 1478' FEL, Sec.11, T12N, R8E, UN Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i l Pool RKB 76' ADL 25531 ALK 2657 12. Date Spudded 13. Date T.D. Reached 14. Date Comp.i ~usr~. or Aband~ I 15. Water Depth, if offshore 116. No. of Completions 09/09/87 09/13/87 _::_ ~///~' J N/A feet MSL ,~/.~ ¢, '~'"~1 17. TotalDepth(MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey --I 20. Depth where SSSV set I 21. Thickness of Permafrost 7155'ND, 6190'TVD 7060'MD, 6112'TVD YES]~] NO [] 1781 feetMD 1600' (approx) 22. Type Electric or Other Logs Run D IL/SP/SFL/GR, FDC/CNL, Cal, FM5, CBL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 115' 24" 255 sx AS I 9-5/8" 36.0# J-55 Surf 3454' 12-1/4" 1250 sx AS ill & 425 ,,x Class C Top job performed w/100 sx AS l 7" 26.0# J-55 Surf 7150' 8-1/2" 300 sx Class G & 400 sx AS I 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) Perforated w/1 spf, 120° phasing "' 3'1/2" 6680' 6606' 6894 ' -6914 ' MD 5978 ' -5994 ' TVD 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED Seeattached Adden. lum~ dated 4/10/88, for fracture d~ 27. kl//~ PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I D~teofTest Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESIZE IGAs-oILRATIO TEST PERIOD II~ Flow Tubing CaSing Pressure CALCULATED.1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 2'~. CORE DATA K ~' ~~ ''~'~'~ ~: " Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. AIas!:z 0i~ & Gas Cons, C0mmissic~ A~cherage *Note: Drilled RR 9/16/87. Perforated well & ran tubing 12/9/87. Fractured well 3/29/88. Form 10-407 WC5/25 :DAN I Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ! 30.: , GEOLOGIC M RS 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 6759' 5868' N/A Base Kuparuk C 6836' 5931' Top Kuparuk A 6836' 5931' Base Kuparuk A 6961' 6032' -- 31. LIST OF ATTACHMENTS Addendum (dated 4/10/88) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~)~ ~j~/~-~j~/ Title Associate Engineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 3/28/88 3/29/88 4/1/88 3H-5 RU Dowell modified tree saver and Dresser Atlas with quartz pressure tool (1-11/16" OD). Test lines and lubricator. RIH w/pressure tool to 6870'. POH w/pressure tool. RD Dowel l/ Dresser. Required 80 bbls of gelled diesel to set tree saver. Frac Kuparuk "A" sand perfs 6894'-6914' in 8 stages as per procedure dated 3/18/88 as follows: Stage 1: 30 bbls gelled diesel 4# 20/40 @ 20 BPM, 3220- 3170 psi Stage 2: 20 bbls gelled diesel 5# 20/40 @ 20 BPM, 3110- 3060 psi Stage 3: 25 bbls gelled diesel 6# 20/40 @ 20 BPM, 2950- 2875psi Stage 4: 25 bbls gelled diesel 7# 20/40 @ 20 BPM, 2810- 2800 psi Stage 5: 22 bbls gelled diesel 8# 20/40 @ 20 BPM, 2810- 2800 psi Stage 6: 20 bbls gelled diesel 9# 20/40 @ 20 BPM, 2740- 2760 psi Stage 7: 20 bbls gelled diesel 10# 20/40 @ 20 BPM, 2780- 2770 psi Stage 8: 124 'bbls gelled diesel flush @ 20 BPM, 4730 psi Fluid to recover: 2468 bbls Sand in zone: 54,055# Sand in casing/tubing: 18,000# MIRU 1-1/2" CTU. Test 1-1/2" tubing to 4000 psi (shut in wellhead pressure 0 psi). Open well - GIH to 3657', tag sand bridges, break circulation 1-1/2 RPM, 3300 psi. Wash f/3657'- 6647'. Soft fill. Tubing tail @ 6647'. Increase pump rate 2-1/4 BPM, +3900 psi, wash to PBTD @ 7026' using 100' bites. CBU while working pipe f/PBTD to tubing tail. Switch over to clean diesel. Spot clean diesel across perfs (used 246 bbls gelled diesel). POOH, displacing well w/diesel to 3500'. POOH w/well shut in. RD CTU. Secure well. Return well to Production. Dr~ng'-Supe ~]~sor December' 21, 1987 Mr. Randy Ruedrich ARCO Alaska, Inc. P.O. Box 360 Anchorage, Alaska 99510 Re: Our 5oss Gyroscopic Survey Job No. AK-BO-70103 Well: 3H-5 Field: Kuparuk Survey Date: November 25, 1987 Operator: D. Harger Mr. Ruedrich: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Ken Broussard District Manager Enclosure NL Sperry-$un/NL Industries, Inc. P.O. Box 190207, Anchorage, Alaska 99519-0207, Tel. (907)522-1737 :: 3H-5 ( :BEC !_.:~ ._ T :L;~_.'[~.. ~2E:E )_ KUPALIRK ALASKA :ANL, HUF-~AbE ALAc, KA : ::: ,.~ ........................... T R U?:._:; c, UB-~EA ' M E A S I..I t::(E'f:t Y E R T t C A I_ Y E R T I C: ~ i .... I]E P TH Dt::-: F"r'Ft I]E F'TH 0 0, C:,() J. (30 10 (). 0() 200 2()0 ,, 00 :.:": ()0 :30 0 ,, C:, 0 4 ()0 40 C,. () 0 50 () 500 ,. 00 60 C:, 6 C:, 0 ,, 0 0 700 70 o. ,, 0 () 800 '7':~'?. '?,'::-, '.:.-;'0 C) 10 ()() 1100 1200 1:300 140 150 C) 160 0 170 · :, E; i~::. R I T Y i 1'4 C I_ i N A T I 0 I',1 I]E:.G I"11 N DE:GRE:E:S I]EG/1 O P E R A T O R-- H A R G E IR TOTAL R E C T A N G IJ L. A R C OOFi: D t N A'I"E S N 0 R 'T Fl / :5; 0 L.t T HE A :F.; 'T / W E F:; T VE F?"I" I C: A i .... :.---.; E:'. C:'T' :[ 0 I,..l .. 0, 00 0 ,, ()5 ,:}, 2'2, C'. ,, ::-.':4 ........ /_25_T Z__~.L .......... () : ';:-::'::": ......... · ::, '7:2. 1 () E 0 ,, i ::3 S 21.30 E (),2'7 !~; 2'7 1':.'? W ':::', C)C) ....... ~ '~ ,_,~.._.._,% _*~_ ....... S:; :lit:.:.:. 1 '? W 4. 10 0 E,f ,i~!4,50 W 1800 2.:: 0 0 21 C)C) :2200 :37 'S :32, 0 W 24 S :::2. E: S,' W 5'f:_.z, .... :'_:j :3:3, 60 W 4C:, S:; :2.:4. :.:.:'.? W ',:-: .._,':' :34 ,6'::? W 3.85 261.84 S 0.54 308.44 S 0.60 ,354.21 S 0.5Z..: :3'.~'?. 1:_--: Si; 0.55 4- 4:3.2,'.':, S · O, 2:4 4:36.84:5; '2:::C~C) 21.5,q., 7 J. 207:5:. 71 2400 :2500 260 C', 27 C) 0 ::ii: :!:: C.:, 0 2 ':';' 0 () .: ..... 1 C) W :-; 35 3':; W 0'44 /.':,,S2 71 c- 4/-,0. :38 W :::c:/, ':"::' ~ ... . ._, ......... ,, .;.. a-. '.E;:2.:5, 0 W O. 2 5 '7 07.4 2 S 4'? 1, '91 t,,4 :: ,'.:-,0 ,, :iii: 7 :'_:i; :3 4, :5:0 t,4 O, 1 7 7 5'2, 4. 4 S 5 2 2. · :.:', ::t W ':::' 15 ,....': ! ......... · .ARCO ALASKA; INC. 3H-5 ( .:,E ._. 12 T 12N R )¢',E ) KUPALtRK ALASI<A ANCHORAOE ALASk::A DATE O'F :=,L RUE Y N.!2!ME:~B.ER ~'._., 1 y,:, 7 · ' ~'"~~' ~ ]~ ~ "~t "~ -~ -.'~, : . :~:;-..:: ::3:':3~:h ::~:::;.. ........ CEI_~L!T~)~~E ....... "::::: ...................... ': NOVEMBER 30, 19G7 ,_lOB NI_INBER ~K-BCm--70103 KELL. Y BUSHZNG EL.E~. = 76.00 F'T'. OF'ER~~H~RGER ~; =-~ i NCL. I NAT Z E,N K, I RE'C T I E,N SEVER Z ]'Y RE C: TANGUL.~R COORD INA TES V ~::I:: ~:"~[~'~& I.... ' KIEG Id I N DEC~REES DEG/1 ()0 NORTH/'.Br3L.ITH EAST/WES]" SECT I , :3 :.:~ :3 S.:,'-' ~..., . 0 W 0. :32 797. :q A '::'...., 554. i-_,/-_, W '::).. '7 c~... ~ 4:3 :? :20 O :3:3 () O 299,f.,, 0 z:l :3'.: 4 0 C) :7 ,:-)..::: (")_ ,, '::;... ]. :3500 :3165 ,, 92 :L::600 :3:25 (), 89 · 27 (') 0 ':"::' ':' ~"] 6, 7 :38 C,(] 34 20, :20 647,6c'-, W :1. i 3 J .... fi:, 4 6'78, 45 W :1. :i. :3,q., 4,'.':':, 7 ()8,99 W 12 ::ii: 7 ,. 0:3 739, 19 W 1 769.42 W 1:342.69 799, '7:2 W 3900 41 C)O 4200 4:300 44.0C} 450C) 4c'-,00 4700 48(}0 4 9 (] 0 5000 5100 5200 :5:L::OC.) 54(':)0 550 () 560 C.) 57, } C ._~ ..... · !5 '.:.:' ,:')C, . .=7- :.:.::3 42d, 4 55 418 · 4.:347 F,/-, 42'71 ~1/-, '-"-' .._.-:,, .... 4.:,._-, ..4_, .:,_7. ......... .-:_ ..-~ 4-4:::'i',0 =-' .... '"- = ..... ' ., ~. 4 ...... :[ :.7, 4'.--.:' -q 4:37.49 ?.: 4 45 '~.:' ,'.!:,.:.._,'"' =' ;l,....~:~ .,_'? ;").. ~ '2 :=; :34 4 678 :::4 4 / (] 2 84 :]7:4 ':.'3::2: '::' u ~ · 47,."-:, i, :..22 46:35, 22 :34 40 4843, :]::'9 ,.fi- 76'7. :2:9 :}.': 4 4,'.3 S 4. P, 4 4.9:3 .i. ~ 0'.-? !::i,:3 :i. :2.7':.7 5 ()'P ,'! ,, 4 :I. t .26 0.40 0.28 0.6,9 0. 1 '7 '0.54 49 :',.i'. 5.3:7 5007 ,. C,':? 5 C, :iii:',3 ,, ·/7 5 :[ '7,:.'.:,...:'[ j · _, ~: .'_--:4 1'? W: 51 S '-"- 50 .:,b:. W 54 S '-"-' 0 W · _"~,,,,,.~ · __.. 4 !:; :::1. :.:.:0 W i 3: ':: ..... ' ...... :, t. 8,';:" 1..J : 0:,. 2'3.? 1.585.20 S 1631.51 S lc, 7~ 14 '-' 172._=;..'_--,'4 177 :'3.0'.--' 075.29. ,N 1:376..'3_'6 _ 106.40 W 1931.25 1:---:7.46 W 1987. O0 168. ('):7.L'. Kt ........_2.0~:2. ZZI:_ ........ 19 7. ':::' 8 1.4 20':::-' L:.':. ,'_":, 5 2:2 7. ,":-, 1 W 2 :i. 5 4, 7 :::.:', 1869.76 S 191:5::. 86 :_--; 1 ':;/- ':'. 6, 5 S 2,'.:' t '.:.?. 0 ]. :;3 ,:::, 6 '.:::.'. :3 ,'.'.::, '.7:11 '.:.:'. 88 L:.'; 1286,. 1:2: W :2:26,'7. :32 12:15.05 W 2:32.'-:4.77 1 ;;~; 4~,.~4_L.i ........ ]. 3 7 ] ,, :5:'7 w 2 4 :.-:':'.::? ,, 51 1:::.:'79.5,.::, 1.4 :;::,:I-'::>'7. :1. :::.', :L!2Z., t_-';_l_ .~ ........... 2.::~:i ::] ~ 7 ARC:O ALASKA, INC. · ..:, H -..., ( .=, E _. :1.: ~ _]7.. ! i.,;Jl N R () 8 E ) K U F'AI..IR K AL. ASI,'::A ANCHORAGE ~A[..A~:~;'I-:,A C:O.MF'LrFA_T !ON DATE NOVEMBER :30.~ 1987 DATE OF SURVEY NOVEMBER 25, t'..:;'::.:.:7 JOB NUMBER AK-BO-7010::4 KE L L Y BIJS FI I N G E L.E V. = 76, 0 () F:-I". OPIERA TOR-HARGER i!i:::: ?i:? ::i ::~:::::P!: ':: :': "I" FilLJ E.'~ ............ ,;;~UD~ .E,,,R__ C:Ot...tRSEE CL]I...IRSE DOG-L EG MEA:::.;i_IRED VtERT I CAI .... VER]' I IS:AL. I NCi_ I NAT' I ON D I F;:t.:=:c"r 113N SEVER I TY DEF'TH DE'i;F']'H DEF'TH .OF:TG M I Iq DEGREE:F.; DEG ? 1 ()(~') :':i::!:'!!'!:'i:' :i::'}):::? ::' ]tOTAL REC'T'ANGI_ILAR Ct-JOF(D I NATES VEF:T ]1:CA1 .... 5257, t 1 35 4':.:' S 27, :39 W (), :3t '2222 41 S 14.::2:2..':. 4:B W '2L'-70, .... - :.3:!ii:. 1 I S f::: ti'.:; 2'7. :':: (') W 0:7 9 2 2 7 4:3 8 'S 1 F; 0':¢ ff]'::/ W "::' 7 '2 9 54 1 ':.-;, () 1. 36 1 S 26.80 N (), :3 () 2:3:7: 6. '7:3 S 15 :.,:.: 6, :B :.3 N '7:'7 F..:'7 ,, ':" 5 '""":' 2:2:79. 17 S 15 & 2, :iii: 1 N ::ii:',iii: ::l-,:'i:, ~ · : ........ ti.-".; 2,'.!:,. :30 N 0, i 0 :'::: !::; '2'? ~::;'.'::',":., ."=;,:") W () ,, Zl 7 24 :..=:: 1.34 S .1. 589'. () () l,.,J :2904 ..... :" = :": f ...... =: "L ::* .. %,. ~: 0.(.)2 2 '744,()2 S 1744.83 W 71 =;-~ /-, t :::',-} '='::' /-, 11:3 =;=; .... '": 46 '" 26 19 0 04 17F, 9 0:3 W ...... · ...... , _ , .~ ..... :,..., :5 W 2772 8'7 c. · .~'- , # . · - ~ .--~ ,.,+ , ,is 76 15;;' '7.'-..!: :1. 9 2 c:':, 05 :3-5 :B 2 5 .1.. 7 ::'i: 3 2 '2. :.3. '~/._, =' HOR_I_Z!Z!b!TAt:.... I]]:SF'[.ACE='MENf~____~ :'-'i:2::'=:!:=].._.75 FEE]" AT L=;OUTH .'.:.:2 D_~EG, _~.~. MI N .... WEST Al' MD = 7!.~_ ............................ ) "I'HE CALCLIL. ATION F:'R(]E:E'DLIF:E::3 ARE BASEO ON THE" U:F.;E OF THREE D IMENSI JN~-,L R~DIU'.:_'-.'; OF F:URVATUF;:EC METHE~.O ARL:L ALASI':::A I NC:. :oH-,.,(.:,Et... 1 :Z 'T t 2N RE)SE ) ; ?: :::.! :.!!i!i:. ' KLIF'AL.IRK ALASKA MEASUI:;:ED VERT I CAL D E P T H D E P T H :.--'.;LIB-F;E A "F C.I 1-gl... · : : DATE OF ;=:! tRVEY NOVEMBE:R 2.~.";., t'i;",~:7 ,]:OMP U,['~.%!ON DATE. .......... ...... ' NOVEMBER 30., .i.'P87 JOB NI_iMBER AI.:::-E~O-701():3 I<ELLY BUSHING E:LEV, = '76,00 FT. ! · V E R T I C A I.._ R E C T A N G I..I L~ A IR C: i]1171R !El I N A "F E S M D- T V D V E IR "F I C A L DE F' T'.H ............ I}J.O_R T H_.../ S C..'!!:,l.]'?J_ .......... ~;. A_$_;]'~.~; S:; T ...... ~)_];_E.F_:j~E.'.ENj.'.: E_.L ............ I: '~ J: I4F~~ E--'F=: 'JLLr-,.ZC..N ? ........ (-) O. O() 10 ('J:, () '.:.:' 9 8.70 :;2:(30 (") 1 9 C:, 1 '::: ]. :300 0 2'7 4 :;.:.:..1. 7 4 ()':.'.:' 0 :'::~ ::::; ::'3 'i;:' ,, 2 ':'J." 5C.:'00 .q- 4. :3 (),, 5'7 60 (_'3,.'::3 5 :;2:5:1.. :? 7 70 0 0 6 0 6 :.3.8 0 7. 1 ....,':: ..... ....,' 6 i :i!i: 'i?. ...... r:'~; .~ 'P7. 1!? 1. 5 8. :..:.:4 :L '=''''' 9'7 ...I ..D. 'T'HE:. CAI.._C:LII....AT ]; (iN I:::'I::;:C~(:':t~i];!3LtF;:ii}i'S ARE BA:ii:;t-Z);') Otq "r'HE I..k~;E OFi "r'FIRE:E ii I MENS.'; I ONAL. RAD I i..IS OF f.":l.. RVA-r'LIF;:E M[:E-I"HOI]~ St:::'EF;;RY--'.?:;I...Ii",.I WEI_I_ SURVE:.Y]:N(Z4 COMF:'ANY :ARC:O AI_ASKA.., INC, · :, n.... ( S E !": :[ :2: T 12 N R t ,::, E ) K I...IF'A I...IR K A I.... A S K ¢3, ANCHORAGE ALASKA C 0 M P U T A 'f_~ I C._!k_L~.~" E NO V E M B ER :3 (), 19'87 M Ii.-.-. A S U R F:!: D D E P T FI J () B N Ij M B E R A [:; - B 0- 7 () 10 :L:: KEI.~L.Y BLr.~HING ELEV. = 0 F:' IE R A T 0 R - H A R G E Fi I N'TERiPOE::~:~E.F.~ VALUES FOR EVEN 100 FEET OF SUB.--SEA DEPTH ' "r'F~t?'E' SUB-SE,C.~ TOTAl_ V i.E R T I C Al... 19' :3 '7 76.0() F' T ,, V E R ]" I C A L... R E il.'.: "f' A N ('.:i U l.... A R (Z: (] 0 R D I N A "r' E S M D-- '1' V Ii V E F;,' "F I C A I_ T'ff:"F"t"FI KtFE:~'T'H / F;F I ITH EA'.?I" / WE:S'T' l"i :1' I::: I::' E:. F;: E N (::: I:?' COF;.'F;:ECT I C.)l'q ) ~ 76 ;t. 27,:'i:, :3 '7 ,:':':, 47/_-:, 576 /::,76 7'76 F~ '7,,':, 0 ,, ()0 76 ,, ()C:, :1. 76 ,, 0 () 276, ()0 :2, 7,'3. ()0 4.76~ ,:::, 0 5'76 ,, 00 6'76. () 0 7'7 ;3 ,. 0 () ',!~:'7 6 ,, ()C) 0.0() N 0 ,, :3,'3 W O. 0 () ,:'). 00 C), 02 S (7.) ,, '70 I,..; ,.'Z), () () O. 0 () C: ,, '2 f:::; ltl (":. ',::',,:") 0. 18 N 0.77 W 0.()0 0.00 (). 0'7 1'4 0. '7.1. W O, 0() C), ()() ("~, .1. 2S (),50 W 0,00 0.00 t ,, 4 :t.'-E; 0. ','_4() W 0. ('-.~2 0 ,, 6, -z::: ,::' :3:3.1. W 0 '"-:'";' , .. ~.,...~ , . , a... a .... ,, .- ,:.} "7 "..:,' ,. ! t 0 7 8 1 t 81 12 8 6 1849 1776.00 1700.00 8. :31 W 1.01 16.24 W 'ii:. 73 28.71 W 5. :30 · .';:~6,2:;B W 10.45 68,,49 W 17.:29 98.02 W 27.2:::}.': (). '7;:2 1.7:_:: 3.07 6.84 ':) '?F-; KUF'AURK AL.A'.L:;KA M E A :!.:.; U F;..' E lj'_'l V li!E F.;,' ']" .[ (]: A I.._ L]E F:' 'r H ]0 E F::'-1" H I',IOVEMBER :30., 1 '.;,'87 i N'TERRE!i~Ai~ED VAL. UES FOR EVEN 100 FEET OF,:,'" U B .-, .:,'=' "I: A DEPTH S LIB- S ~;A "1" 0 TAI .... VERT I CAL REC"t"ANE4..tI_.AR CCtORD I NATES MD--]'VD .lOB NUMBER AK-B(]-7C:,103 KEI...I_Y BUSHTN(].i ELFV, = 76. (")0 F"t"., ~F' g.R A T C, RTH ~i.~. I:~ GE R ============================================================== V E IR T I C A L C 0 R R F C: T I 0 N i :3C'0.00 :340.4:3 S 2:3'7.05 L.4 'F':3.6() 19.71 1 '-}()0. 0(-) :--:94 07 '.:; 27::: 0::: W ] 19 /-,y; Z ~ T. .... ~. ~ .................... %-: ........ ~. _] .... ~ ................. 2~__ .:~..~_,~ .......................... ~ ~. 4~:: ~_~ 2 ()()0 ,, 0() 44 d, :37 S :309 ,, 04 W 1:31.. 1 () 18,46 210(). ()0 497 ,, 74. S :344,94 W 14'?, :1. 2 18, 02 2 2 (';:, 0 ,. ()0 549 ,, 19 '.B :380 E: !) W 16'7. 19 18.0'7 23()().,00 601.'22 S 4.17.19 W 185.61 t8.4:3 94(w'). c:,(') /-,% 4 o9 S 454 '-' = W 2(") 4 .o.:,' ~= 19 0::: 7'/.-, (":,,:") r'~ n 76 ]. :2, 6 '-S Ffi 7"::2 ~';::' W 24:3. ............ .-... , ........ . . ...... "~ .... . 27,:}() ~ 0() :F: :! 4 ,, :::',7 S 566.92 W 26:3. ]. '7 ! 9.4 2 4) 0:2, ,. 64 W ......... 28.1~, 8 640 '-'~ , ~ / W :300. :z:o 18 676.67 W :3~8.2:3 17.87 :351 1 -Z, / ; :38 66 :2';/R4 :::.=,7/-, 0() :::5C)() 0() lz..,:,7.74 ,3 41 C) :,7: :3/_-, 7/:,. 00 :360 O, 00 t 7' 7'.~. ,_1 S · ]..<~. Ob ............... :,.:,..,. 85 '7 4:F:. 10 1,4 :7:5 :'_::. ~:'-5.' '78:3.88 W :371.64 :31 ?, 1.-,:3 W :'~90. 1 ..:., :: ...,., '~,,". :": o._,~,. ,,, ~ :W 408 , .;'3':;,.. 890. '~"- · _~ Y W 426.60 17.62 . 17.7,,'-I. 1L::. C:,5 !8, 47 18.2() ~ARCO AL. ASKA ~, I N C. K U PA I...IR I-:.'.' A I... A S K A NOVEFIBER 30, 19 87 ,..IEIB NUMBER AK-Bf3-7(:)IO::: K E L.[. Y BIJL:;H T NG E I_ E V. = 76.00 F:'T ,, 0 F' E R A T 0 R - H A R G E R I NIERFOb;~:EL VALLtlES F:OR EVEN 100 FEIET OF '"" I' ' TRt...IE '-' ~ '-' " . .:, I_i E -.:, E ~.-; T I':1T a L ~--. ~ MEA:E;UI:~ F:'I] ......... VERT' I CAt_.. VERT I _.RI .... RECTANGI..ILAR COORD I N ¢-~" ....... 1 E ...... ':::' M D- T V D D E P'I" H D E;F:'"I" H D E F::' T H N CIR T H / :E;OI...IT H E A S ]" / W E'.B"t" D I F F'E RE N E:E VERT :[ CAL C 0 R R E E: T I 0 N ::::::::::::::::::::::::::::::::::::::::::::::::::::::: 4220 :3776 ,, C:, () 4 :Z.:.: :.":.::8 ::ii: 076.~ () 0 445 '7 :>7: 'i;;' 7 ,:':, ,, C:, ,:.'.) zt 5 '75 ;~ ;":' ":;'/-., ;'"' ;'"' ,-].,.,, ..., .,,. ,,,, 4 6 !;;' 4 .,'t. ;i. '76 ,, 0 4 81 :;.:.: 4 '"27 '. ,") .~' ! ,'-~....... 49:34 42, 7/:,. 0 () 5054. 4476. 5 ]. '75 457 (!:, ,, 0 5296 46'76 ,, 00 5417 4 '7 '7 ;:?:,., 00 4 2 0 0 ,, C, C.', 4:3 ()0 ,, ()0 4. 4 (),:), 00 4 !!50 C.:, ,, 00 46 C,(), C:, 0 ,:I-'70 ()., :} 0 5661 !:-178zl. 5 '.::"/0/-:, 6, 02:..: 9 615 2 6276 6400 1326.46 W 66:3.71 21.74 1:3 ..../-, (") ./-,.. 2. W 685 . :::_ 9. ~':' ~.'-". 18 '-, C'.' I:::: 1429, 41 W 7:3 C) . ,:,'-' .._, = .,:."'-' ~..":'. 46 146:3. 1/_-, W 753.64- 2:2.7'F/ 147.6, 89 W 776 · 91 2:-::. 2/-, ....... ;:' , ...... ""I 1._(::.. 84 14 _.,..-,, 08 ANCHORAGE ALASKA ARCO At..ASKA.~ :INC. .::,H-.. ( SEC 12 T 12N RO::::~ ) I< LIF'A U RI< A L A S K A MEA'.~3URED I]E:F'TFI ............................... ~'/F, IJ T A T_ I 0 hJ_~ N(]VEMBER :.30:, 1'.:./:.:.:7 DA'T'E OF SLIRVEY N.~VEMBER~.'-'=._,, 1 ;~c, / IN TER~:..i~L:A~:ED VAL. UES FOR EVEN 1C)O FEET OF · . :....: j:~:: ~::: ': .~ T R L.I E S U B- S E A ']" ()T A L. V E R T ]: C A t..~ V E R T I C A L R E C T A N G I...I [.. A RC ()0 R D I N A T IE'S M D- T V D D E F:"T'H DE F::"t' FI N 0 R ]"H / S 01..1"[' H E A S T / W E: S"[' D ]' F F E R E N C E .j,Et B N U M B E R A K - B 0- '701 0 ::: K E L L. Y B LI'.~;H I N G E L. E V. = 7 6.0 0 F:' T. , . :::~i!:?:'.'::':. 5 VERI' I CAL r'.:: 0 R R E C T I 0 N :2:3 5 6 7 6. (.) ('::, 4 6. 5 7'7 6.0 ('-~ ,":-., :--'::: f::' ''"' "7 ..... .......... :,'::,; /-, 5;' 1 5 9 7 6,. ()0 ]. '::"' 6, 0 7 ;:., ("-', -,..! ~ ~ .....- :.3 8 6:1. '76, ,, 0 () '=5 ,'.!:, 1 :!3'::~ % 5; %.1, '1 ,. ~ .,,...., 5-; &,C:,(') C) O 24 4:3 '-' '~' ....... :,o :iF.; 159 5.0(') W 8 4 7.1 7 .=;'7()0 00 ""'"'" .. . ~...:, 07 '-'"' . , .:,o S 1/:,.,.~ :,. 7 ]. W :.:.:70 (:)6 23.09 :.';--:: :;..':". :::7 ":'":' (~)0 a:- ...J, u - 2:3. 10 9 6'2. :30 96,5.4 5 THI:'< Nt!![AF;tli:~(3"F :;ii:('.::, F:O(]"I" MI) (l::'F:;.:Oht l::;.:AD]:Utiii; C)F: CIJIRVATt_IRE) POINTS :::::;...:.:::: . .::: ::-:::d:: ARL:O ALASKA,, INC:. · _'~ H- ~., ( :B E C 1T 1:2 N R 0 :": [:' ) KLIF'AUIRK AL. ASKA ~,F:'~y-.::;I IN NELI .'.:i;UFkVEY I NG · ,~ ....... ? ~ _ ~ ............ . -. ~ . AN.~;.HO[,,AUE ALA.~KA ~:OMPU'TAT ! ON .~FE ..... NOVEMBER :}.':0~ 19,'-2:7 -' · I '. ' ' ': · . , "~ i~'"o. i INTERROE~TE, I. VAI.,.UES FOR .:,PECIAL '.gl IRVEY PO_'[NTS DATE .[;!F ;:-.,URMEY NOVEMBER ":'=; ,JOB NUMBER AK-BO-70103 K E L..t... Y B IJ,..~; H I N G E L. E V. = 76.0 () F:'T'. 0 P E R A T 0 R - FI A R G E Iq: 'T'RUE SUB-SEA MEASIJRED VERT I CAL.. VEIRT I C:AL I]E F'I"H D E F:' ]"H D .F.':P T H TOTAL "l .... · ~ "~. '-. ~' "~ R E L. ] ia N b IJ L A 1:", L.- t]10 IT(D ]: N a T E :iii; hi 0 R ~r' H / S (] Ij -[' H E A S T / W E :~; T MARKER ,:,H-.~ ( :BEC 1 '"'' Ti 2N ROSE ) ....... -- , . · ~Cl2~:L:!L~__SF~~MM~ .... D E' ........... R t V E D I. k::; :t: N G 1] I L. D E F' ]" H S A N D S P E R R Y ::;I IN .:::,'""t..t r'~'"'v'~:"~. ',' D.. A T A ~_____~i-'Q ] '-'..~l' ' ']"E'c'. ..:_, ..... ......... ..................... ....... ............ ......... :TV[ ............. TH ....... : ~: BKB BKB '.SUB-SEA VERT I CAL. ( rtR I G I N- 1 ~ENL::: '"'""' ~;:,::, ~ F W L ) -- , :~:: :::::::::::::::::::::::: ~: ]:~:: Tf]F' t.:::I...tF'ARt...IK (.] 6'75':~ !:.!i; :E: (S '7 , '7 2 5'7'P:L,':T~2 B a L:i; Ei: K I...I I:::' A I:'~ 1...I K C(?, L:]: :..--.I,.'.':, ]i!!i'.:.':' :}.",,:".) ,, 5 J. 5 Ii-.':: 54,5 J. 'l"l}F' KIJ Pi:"~RI...iK A ,..z-,°"::' ,,.,..,....,,~, ~;'i~;':_.::O., :..~1'"'- ._'=iFf'::']4_ ._ . ._=il BASE KIJi::'ARtJI< A 6'.::;'61 6C):32. 16 5'.956, 16 TOTAl .... DEF:'TH I]R ILL. ER 7155 6.1. 8'::). 55 6:1. ~. :3.55 2606, 00 S 16 76 ,, 4 S':' kl 2,S 7 t, 10 S 1 700, 'il) 5 W 2: 7. 7 .,..'::', ::::_ '7. ~.-".i; .t. 7 ...,':::' '"".:, ,, ()3 W i) FROM LINE:AR EXTRAPOL..ATICfN BEL..OW DEEF'EST STATION. 2) COMF'UTER F'RC,SRAM -SF'ERRY SUN THREE DIMENF-;IONAL RADIU:-'; OF CURVATURE. DATA C:ALCLILATION AND INTE:RF'FIL. ATI'ON BY RADIL1S; OF CURVATURE COMF'UI'ATION DATE NAVEMBER_ 30 :, 1 '--'P7... _, DA]rE OF SLIRVE'¥' NOVEMBER 25, 17',,-]:7 .J A B NU .~.~.~K- B 0- '7010:3 .. :~i::~!~i~'!~i~,...';:!: _ f:..EL.L¥'~:~t$~::NU ELEV. - '7/-~.00 F~ ................................. :SPERRY -:SUN -70103 5CRLE :- 1 INCH TO 500.00 / 500.0 RRCO qLRSKRo INC. NOVEMBER 25, [987 -~oloo. oo -~sl~o. oo -,oloo.' oo -~o1~. oo TRUE NORTH O. O0 · , 500.00 O0 00. O0 155 HOB ~[ ZONTRL PROJECT T_ ON -3000.00 0.00 1500.00 :' ..<: KUPRURK 5CRLE ; i INCH TO 1500.00 / 1500.0 RRCO RLASKR, 5H-5(SEC12 T12N RO8E) RK-80-70103 3000.00 INC. 1987 4500,00 6[89.55 RTICRL SECTION 7155 7500.00 15~0.00 30~0.00 I 4500. O0 VERTTCFIL PROJECTION ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 11, 1988 Transmittal # 7056 RETUP, N TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. '"'~'-o2V-4 Cement Evaluation Log 12-29-87 5987-7253 ~ '"~3H-6 Cement Bond Log 11-27-87 5300-7866 '-~3H-7 Cement Bond Log 11-28-87 6000-8516 -.o "~3H-5 cement Bond Log 11-25-87 4900-7020 '~3H-8 Cement Bond Log 12-3-87 4600-6756 "~"~3H-lO Cement Bond Log 12-9-87 5128-6633 ~'~ ~'~3H-1 Cement Bond Log 12-3-87 5700-7978 ~'~ x"~3H-2 Cement Bond Log 11-23-87 6100-8184 "~ x'~3H-4 Pulse Echo Log 11-25-87 5600-7986 "~ "~3H-9 Cement Bond Log 12-8-87 5550-7162 -"'~'"'~3H-3 PulSe Echo Log 11-26-87 4400-9354 Receipt Acknowledged: DISTRIBUTION: ~,laska Oil & Gas Cons. Anchorage NSK Drilling State of Alaska(+sepia) ARCO Alaska, Inc. , Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: January 11, 1988 Transmittal # 7061 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3H-4 3H-5 3H-5 3H-6 3H-7 3H-8 3H-8 3H-9 3H-10 BHP Data Worksheet 12-17-87 Kuparuk Well Pressure Report Kupaurk Well Pressure Report Kuparuk Well Pressure Report Kuoaruk Well Pressure Report Kuparuk Well Pressure Report Kuparuk Well Pressure Report Kuparuk Well Pressure Report Kuparuk Well Pressure Report C~co 12-18-87 Static Otis 12-18-87 Static Otis 12-19-87 Static 12-23-87 Static Otis 12-21-87 Static Camco ' 12-22-87 Static 'C' Sand Otis 12-22-87 Otis Receipt Acknowledged: DISTRIBUTION: D &M ~State ~f Alaska ~ BPAE Chevron Mobil SAPC Unocal STATE OF ALASKA ~"~. ALASF,. OIL AND GAS CONSERVATION COMN, 51ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate,~ Pull tubing [] Alter Casing [] Other ~ COHPLETE 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. RKB 76' Feet 3. Address 6. Unit or Prg~erty name P.O. Box 100360, Anchorage, AK 99510-0360 Kuparuk R~ver Unit 4. Location of well at surface 1446' FNL, 281' FWL, Sec.12, T12N, R8E, UM At top of productive interval 1268' FSL, 1375' FEL, Sec.11, T12N, R8E, UM 7. Well number 3H-5 8. Approval number 7-646 9. APl number 50-- 103-20077 10. Pool Kuparuk River 0i] Pool At effective depth 1111' FSL, 1454' At total depth 1061' FSL~ 1478' 11. Present well condit Total depth: FEL, Sec.11, T12N, R8E, UM FEL~ Sec.11~ T12N~ R8E~ UM ion summary measured 7155 'MD true vertical 6190'TVD feet feet Plugs (measured) None Effective depth: measured 7060 'MD true vertical 6112'TVD feet feet Junk (measured) None Casing Length Size Conductor 80' 16" Surface 3420' 9-5/8" Production 7115' 7" Cemented Measured depth 255 sx AS I 115'MD t250 sx AS III & 3454'MD 425 sx Class G Top job w/lO0 sx AS I 300 sx Class G & 7150'MD 400 sx AS I True Vertical depth 115 'TVD 3127 'TVD 6186 ' TVD Perforation depth: measured 6894'-6914'MD 5978 ' -5994 'TVD true vertical 12. Tubing (size, grade and measured depth) :~-1/2", J-55, tbg w/tail ~ 6680' Packers and SSSV (type and measured depth) FHL pkr ~ 6606' & Otis SSSV @ 1781' Stimulation or cement squeeze summary N/A Intervals treated (measured) 'Alas~ 0i~ & Gas 6or~s. 6ommissior~ A~chorage Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Completion Well His~ry) Daily Report of Well Operations Copies of Logs and Surveys Run ~ Gyro 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~.~.~/,~ Title Associate Engineer Form 10-404 Rev. 12-1-85 Date (Dani) SW03/26 Submit in Duplicate ARCO Olland Gas Company Well History - Initial Report - Daily Itmtmotion~: Prepare and submit the "Initial Rel~t" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to sPudding should be summarized on the form giving inclusive dates only. Diatriot ARCO Alaska, Inc. Field KUPARUK RIVER UNIT lCounty, parish or borough NORTH SLOPE Lease or Unit ' ADL: 25531 COMPLETION ] Stat~%K 3H-5 IWell no. Auth. or W.O. no. AK2483 Operator ARCO Spudded or W.O. begun ACCEPT Date and depth aa o! 8:00 a.m. 12/09/87 ( TD: 7155 PB: 7026 (WI; SUPV:HE/JE API: 50-103-20077 I ARCO W.I. IDate 12/08/87 IH°ur 0915 I 56'0000 I Prior status If a W.O. Complete record for each day reported NOBJ)IC 1 DISPLACING W/ DIESEL MW: 6.9 DIESEL MOVE. RIG F/ 3H-4 TO 3H-5. ACCEPTED RIG @ 0915 HRS 12/08/87. ND TREE. NU BOPE. TEST TO 3000 PSI. PU WL. PERF "A" SAND F/6894'-6914' W/1 SPF (120 PHASE). RUN 3-1/2" SINGLE COMPL. RUN TOTAL OF 203 JTS 3-1/2" 9.3, J-55 EUE AB MOD IP¢ TBG. MU SSSV. TEST CONTROL LINE TO 5000 PSI. OK. FIN RUN TBG. PU HANGER AND LAND. SET RET PKR W/ 1100 PSI. TEST TBG TO 2500 PSI. SHEAR PKR. TEST ANNULUS TO 2500 PSI. TEST SSSV. SHEAR BALL SET BPV. ND BOPE. MU FMC 5000 PSI 3-1/8" THEE AND TEST. DISPLACE TO DIESEL. (SSSV @ 1781', PKR @ 6606', TAIL @ 6680') DAILY:S141,200 CUM:$141,200 ETD:S141,200 EFC:$740,000 The above Is correct For form preparation an~l~'dlatrtbutlon, see Procedures Manual~'~6ection 10, Drilling, Pages 8~ and 8~'. ITitle Associate Engineer ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting cost center code District County or Parish State ARCO Alaska, Inc. NORTH SLOPE I AK Field ILease or Unit IWell no. KUPARUK RIVER UNIT I ADL: 25531 3H-5 Auth. or W.O. no. I Title Operator IA.R.Co. W.I. ARCO ~ 56.0000 Spudded or W.O. begun Date ACCEPT 12/08/87 Date and depth as of 8:00 a.m. 12/10/87 ( TD: 7155 PB 7026 (WL~ SUPV:HE/JE Complete record for each day reposed NORDIC 1 I otal number of wells (active or inactive) on this Dst center prior to plugging and bandonment of this well J our I Prlor status if a W.O, I 0915 RIG RELEASED MW: 6.9 DIESEL FINISHED DISPLACING WELL WITH DIESEL. SERVICED RIG. SET BPV. SECURED WELL AND RELEASED RIG @ 0700 HRS, 12/09/87. DAILY:S11,398 CUM:$152,598 ETD:S152,598 EFC:$740,000 Old TD Released rig New TD Date PB Depth I ::t!as~a Oi~ & Gas Cons. Commissio~ i~,~; o, ,,g Anchorage Classifications (oil, gas, etc.) I Type completion (single, dual, etc.) I Producing method IOfficial reservoir name(s) I Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production , ., Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form prepar,~on and distribution, see Procedures~lanual, Section 10, Drilling, Pages 86 and 87. Associate Engineer STATE OF ALASKA .... ALA~ ,A OIL AND GAS CONSERVATION COl, .ISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown~ Re-enter suspended well ~ Alter casing [2 Time extension [] Change approved program [] Plugging [] Stimulate ~ Pull tubing ~ Amend order ~ Perforate ~ Other 2. Name of Operator ARCO Alaska~ Inc 3. Address P. 0. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1446' FNL, 281' FWL, Sec.12, T12N, ESE, UN At top of productive interval 1368' FSL, 1290' FEL, Sec.11, T12N, RSE, UM (approx) At effective depth 1118' FSL, 1424' FEL, Sec.11, T12N, RSE, UM (approx) At total depth 1069' FSL, 1449' FEL~ Sec.11~ T12N~ RSE~ UN (approx) 11. Present well condition summary Total depth: measured 715.5 ' M D feet Plugs (measured) true vertical 6199 ' TVD feet Effective depth: measured 7060 ' MD feet true vertical feet 61 22 ' TVD Casing Length Size Conductor 80 ' 1 6" Surface 3420 ' 9-5/8" 5. Datum elevation (DF or KB) EKD 76, 6. Unit or Property name Kuparuk River Unit 7. Well number 3H-5 8. Permit number R7 -77 9. APl number 50-- I n~-20n77 10. Pool Kuparuk River Oil Pool None Producti on 711 5 ' 7" Perforation depth: measured Junk (measured) None Cemented Measured depth 255 sx AS I 12.50 sx AS II I & 425 sx Class G Top job w/lO0 sx AS 300 sx Class G feet True Vertical depth 115'MD 115'TVD 3454 'MD 3134 'TVD 7150'MD 619'5'TVD None true vertical None Tubing (size, grade and measured depth) None RECEIVED Packers and SSSV (type and measured depth) None OCT 0 I 1987 12.Attachments WELL HISTORY Description summary of proposal [] Alask~ 0ii & Gas Cons. C0mmissl0~i Detailed operations program ~'"""BO~ sketch 13. Estimated date for commencing operation December, 1987 14. If proposal was verbally approved Name of approver Approved by . '8~ [~N~i[[ Form 10-403 Rev 12-1-85 Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~ ~ll_/],,¢J~ ,.,, Title Assoc~qte gnoin~.er'_ Date Commission Use Only (Dani) SA2/96 Conditions of approval Notify commission so representative may witness ~ Approval No. ~ Plug integrity ~ BOP Test D Location clearance by order of the commission Date Commissioner ""~ ,,'"/ Submit in triplicate ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Rel~rt" on the first Wednesday after e well is spudded or workover operations are started. Daily work prior to Sl~udding should be summarized on the form giving inclusive dates only. District I County. parish or borough Alaska I North Slope Borough Field Lease or Unit Kuparuk River ADL 25531 Auth. or W.O. no. ITitle AFE AK2483 I Drill Doyon 14 API 50-103-20077 IState Alaska Iwsll no. 3H-5 Operator ARCO Alaska, Inc. 9/08/87 9/09/87 9/10/87 9/11/87 Complete record for each day reported 16" @ 115' NU diverter. Date and depth as of 8:00 a.m. 9/12/87 thru 9/14/87 The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. 2400 hrs. mARCO w.I. Prior status if s W.O. 16" @ 115' 915', (835'), Drlg Wt. 8.9, PV 15, YP 19, PH 9.0, WL 18.6, $ol 4 Acce~ ri{ @ 0630 hfs, 9/8/87. Spud wall @ 2400 hrs~ 9/9/87. Drl to 915'. 16" @ 115' 2781', (1866'), Drlg surf hole Wt. 9.1, PV 17, YP 34, PH 9, WL 8.2, Sol 5 Drl surf hole to 2781'. 455', .3°, S49.5E, 455.00 TVD, -0.17 VS, .77S, .91E 1062', 11.3°, S21.6W, 1059.89 TVD, 25.84 VS, 31.52S, 1.37E 1634', 28.1°, S39.1W, 1594.81,TVD, 223.72 VS, 193.42S, 112.72W 2295', 32.0°, S34.2W, 2155.25 TVD, 572.61VS, 484.80S, 304.74W 9-5/8" @ 3454' 3472', (691'), ND diverter Cln'g pits Drl to 3472', C&C, POH. RU & rn 87 its, 9-5/8" BTC, 36# csg w/FS @ 3454'. Cmt w/1250 sx AS III & 425 sx C1 "G" w/2% S-1 & .2% D-46. Displ w/wtr & bump plug. ND diverter. 2613', 32.7°, S32.8W, 2423.84 TVD, 742.76 VS, 626.69S, 398.66W 3400', 31.9°, S35.6W, 3086.51TVD, 1166.97 VS, 976.24S, 639.50W 9-5/8" @ 3454' 7155', (3683'), RU to rn OHL Wt. 10.0+, PV 13, YP 4, PH 9.0, WL 4.6, Sol 12 Perform top job w/lO0 sx AS I cmt. NU & tst BOPE. Drl & surv to 7155', cond hole, POOH, RU to rn OHL. 3714', 31.9°, S34.9W, 3353.15 TVD, 1332.71VS, 1111.75S, 735.27W 4443', 32.2c, S36.3W, 3970.55 TVD, 1719.98 VS, 1429.71S, 956.96W 5296', 34.2°, S31.4W, 4682.21TVD, 2189.96 VS, 1820.02S, 1219.00W 5773', 35.2°, S29.3W, 5074.37 TVD, 2461.32 VS, 2054.36S, 1356.21E 7155', 35.4c, S26.5W, 6199.35 TVD, 3261.23 VS, 2764.68S, 1730.02E RECEIVED OCT o i Alaska 0ii & Gas Cons. C0mmissi0t~ Anch?-g~ Drilling Superintendent JDate Title 56.24% AR3B-459-1-D Number ell dally well history forms consecutively eagle no. ss they are prepared for each well. J ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time, On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available, Accounting COSt center code I County or Parish State Alaska North Slope Borough Kuparuk River ADL 25531 3H-5 Auth, or W.O. no. ~Title AFE AK2483 J Drill Doyon #14 Operator ARCO Alaska, Inc. District Alaska Spudded or W.O. begun Spudded 9/15/87 Date and depth as of 8:00 a.m. 9/16/87 API 50-103-20077 A.R.Co. W.I. 56.24% D;ita 9/9/87 Complete record for each day reported Iotal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well I our ~Prior sfatua If a W,O. 2400 hrs. I 9-5/8" @ 3454' 7155', (0'), RU to rn 7" Wt. 10.0+, PV 13, YP 8, PH 8.5, WL 4.8, Sol 11 RUrn DIL/SP/SFL f/7166'-3150', GR f/7166'-1000', FDC/CNL f/7166'-6550', 6230'-6090', 5850'-5700', 5000'-4900', CAL f/7166'-3150', FMS f/7166'-6550'. Cond for csg. POH LD DP. 7" @ 7150' 7155' TD, 7060' ?BTD, RR 10.0 ppg brine Rn 169 its + mkr jr, 7", 26#, BTC J-55 csg w/FS @ 7150', FC @ 7063'. Cmt w/100 sx 50/50 Healey Flyash C1 "G" w/4% D-20, .2% D-46, .5% D-65 & 200 sx C1 "G" w/3% KC1, .3% D-13 & .2% D-46. Displ w/10.0 ppg brine using rig pmp, bump plug. RR @ 0530 hfs, 9/16/87. 0 C"i 0 / Alaska 0il & Gas Cons. Commission Anchorage Old TD Released rig 0530 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing New TD 7155' TD IPs Depth Kind of rig 9/16/87 Type completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands 7060' PBTD Rotary Potential test data , 'Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effe'ctlve date corrected The above is correct ~ Drilling Superintendent For form preparation and distribution, see Procedures Manuat, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C INumber all daily well history forms consecutively ;is they are prepared for each well. iPag; no. Dlvlllon of AtlentlcRIchflel¢lCompeny . ARCO Alaska, lc' Post Offi~. .ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: September 24, 1987 Transmittal #:6066 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3H-5 5" Dual Induction 9-14-87 3457-7160 3H-5 2" Dual Induction 9-14-87 3457-7160 3H-5 5" Porosity FDC 9-14-87 4875-7134 3H-5 2" Porosity FDC 9-14-87 4875-7134 3H-5 5" Raw (+1.2") FDC 9-14-87 4875-7134 3H-5 2" Raw Data FDC 9-14-87 4875-~7134 3H-5 Cyberlook 9-14-87 6550-7050 3H-5 Formation Mirco-Scanner 9-14-87 6550-7163 /' ./ Alaska Oil & Gas Cons. Commission Receipt Acknowledged: DISTRIBUTION: Date: NSK Drilling Franzen D & M State of Alaska (+sepia] L. Johnston(vendor Package) Vault(film) ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Post Otfic~ ~ Dx 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: September 22, 1987 Transmittal #:6064 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3H-5 NOTE: OH Lis Tape 9-14-87 #72445 Oh Lis Tape 9-5-87 #72439 Colville OH LisTape 9-5-87 #7244~: ............. I will be sending the Colville OH Lis Tape at a later date. Receipt Acknowledged: DISTRIBUTION: Date: State of Alaska M. Stanford ARCO Alaska, Inc. is a Subsidiary ot AttanticRichlieidCompany ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 August 5, 1987 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - 3H Pad (Wells 1-22) Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/pk GRU1/31 Enclosure RECEIVED Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany II 112 I \ ell VICINITY MAP $~.ALE I'B ~P MILES ALL WELLS LOCATED IN SEC. 12, T. 12 N., R.8 E., UMIAT MERIDIAN. NOTES I. ALL COORDINATES ARE A.S.P., ZONE 4. 2:. ALL DISTANCES SHOWN ARE TRUE. 3. ELEVATIONS ARE B.P.M.S.L. 4. REFER. FIELD BOOK L-17-1~,35-44 ~ L-07-11, 29-32. E. O.g. ELEVATIONS FROM CED-RIXX- 3471,~ 6. HORIZONTAL POSITION BASEDON 3H CONTROL ASPs 'X' 6,000,110.73 6,000,135.51 6,000,160. 57 6,000, 185.28 6,000,2:10.66 6,000,2:35.50 6,000,260.34 6,000,E85.82: 6,000,310.30 6,000, 3 35.43 6,000,425.37 6, 000,450.51 6,000,475.46 6,000, 5.00.41 6,000, 525.44 6,000,550.46 6,000,575.45 6,000,650A5 6,000,675.40 6,000,700A2. 498,655.44 498,655.43 498,655.39 49 8,655.43 498,655.47 498,655.40 498,655.41 498,655.44 498,655.45 498,655.44 498,655.44 498,655.38 498,655.42 4 98,655.4S 498,655.41 498,655.47 498,655. 55 498,655.59 498,655.49 498,655.63 49 8,655.73 LATITUDE 70o24'41.531" 70°24'41. 775" 70024 42 264, 70° Z4' 42.514 700 24'45.003 70 24,43.494, 70°24 43.741' 7ooz4'44.6~' 70o24'44.875'' 70 2:4 45.610 70o24'45.856"i 1'002:4'46.102" zoo:' 4' 463 4a' 7oo24'4 .04o-1 70° 2:4 '47.08 5" I 70°2.4'47. 351 "1 150000' 39.41_7,~ 150° 00~ ~9.418,, 150° 00, 39.417 o 00'. 39.4,8',', 150° O0 39.418 15o0oo', 39.41Y' 150° 00, 39.417" 150° 00 39.417" 150°00' ~9.418" 150o 00'39.4~' 150° 00'39.419" 150° 00' 39.411~ 150° 00' 39.419 150°00' 39.417' 150o00' 39.415" 150o00' ~9.414P LONGITUDE IDist £N.L. I50°00'39.4~6''1 ~a~kaOil 522', 49 7, 472, 446 422' 397' 371' 347', 322. 1232' 1207' 1182' 1107' 1082' 1057' 150o00'39.418'' 150o00'39.413' 150o00'39.410" I AM PROPERLY tHEREBY CERTIFY THAT REGISTERED AND LICENCED TO PRAC- TICE LAND SURVEYING INTHE STATE OF ALASKA AND THAT THIS PLAT REPRESENTSA LOCATION SURVEY MADE BY ME OR UNDER NY SUPERVISION AND THAT ALL t DIMENSIONS AND OTHE" DETAILS ARE CORRECT AS OF 6/9/87. 1007' 982' 957' Dist EW.L:! O.D. Elev. Ga~ C'ons. c0 ma '. Arzadrage / 34.~_' 20': 35.9: 2:81, $$.8, 281 337 33.6 Pod Elev._ 38.8' 38.8' 38.7~ 38.7 $86' 3,8.9 281 26 I' 281' 281' 281' 282' 282' 282' 282' 282' 33.6: 33.6, 33.6 33.7' 33.8' 33.8' 33.8', 33.~ 33.8' 33.8' 33.8' 33.9' $3.9' 33.9' 38.7', 38.6, 38.6 38.7' 38.8' $8.8' 38.7: 38.7 38.7' 38.8' 38.9' $8.7' 38.6' 38.6' KUPAIIUK P~oJEC! D.S. SH WELL CONDUCTOR AS-BUILT PREPARED BY - LOUNSBURY Associates ANCHORAGE ALASKA OWN BY: PJW ! CHKBY: dWT ~ July 31, 1987 J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 3H-5 ARCO Alaska, Inc. Permit No. 87-77 Sur. Loc. Btmhole Loc. Telecopy No. (907) 276-7542 144.6'FNL, 281'FWL, Sec. 12, T12N, R8E, UM. l182'FSL, 1408'FEL, Sec. 11, T12N, RSE, UM. Dear Mr. KeWin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other govern- mental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representatiVe of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. C ~ Chairman Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION jo Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Douglas L. Lowery -, STATE OF ALASKA ~ ALASKA AND GAS CONSERVATION CL. ,/IISSION PERMIT TO DRILL 20 AAC 25.005 i la. Type of work Drill ~ Redrill r-qI lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] Deepen[]1 Service [] Developement Gas [] Single Zone ~ Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska~ Inc RKB 76' PAD 39' feet Kuparuk River Field Kuparuk River Oil Pool 3. Address 6. Property Designation P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25531 ALK 2657 4. Location of well at surface 7. Unit or property Name 11. Type Bond(se, 20 AAC 25.025) 1446'FNL, 281'FWL, Sec.12, T12N, R8E, UM Kuparuk River Unit Statewide At top of productive interval 81 Well nurpber Number 1368'FSL, 1290'FEL, Sec.ll, T12N, RSE, UM 3H-5 t/8088-26-27 At total depth 9. Approximate spud date Amount l182'FSL, 1408'FEL, Sec.ll, T12N, RSE, UM 08/17/87 $500,000 12. Distance to nearest 13.3D~s_t~nce to nearest well 14. Number oi acres in property 15. Proposed depth/MD and TVD) 7097'MD property line 1182'~ TD feet 25' ~ ,Surface feet 2560 (6204'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure ise~ 2o AAC 25.o35 lei1211 Kickoff depth750 feet Maximum hole angle33 0 Maximum surface 1865 psig At total depth (TVD) 3018 psig ., 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 80' 35' 35' 115 115' +200 cf 12-1/4" 9-5/8" 36.0# J-55 BTC 3433' 35' 35' 3468 3151 ' 1100 sx AS III & HF-ERW 425 sx Class G blend 8-1/2" 7" 26.0# J-55 BTC 7063' 34' 34' 7097 6204' 200 sx i~lass G(minimum HF-ER~ TOC 5(0' above top of Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 20. Attachments Filing fee ~' Property plat ~J BOP Sketch,~ Diverter Sketch ~ Drilling program Drilling fluid program ;~ Time vs depth plot [] Refraction analysis ~_ Seabed report ~ 20 AAC 25.050 requirements 21. I hereby cer~hat the foreg.o, ing¢!.~ true and ~orrect to the best of my knOwledge /! i ' ' -, ' Da Signed z_¢,, ¢'"¢"~c¢~/"( .,- TitleRegional Drilling Engineer ~/"~~?t ~'~"~i~ ~ Commission UsiOnly (JLQ)jPD2/37 . .. Permit Nu,~er _. - APl number Approval date See cover letter 5o- i ¢ ~ ~ % ') <~ ? 7 0 7/-3 :;l / 8 7 for other requirements Conditions of approval Samples required [] Yes ~No Mud Icg required - Yes ~ No Hydrogen sulfide measures L3 Yes ~ No DirectiOnal survey required ~'¢~ Yes ~ No Requiredwo~~~~5M; ~ 10M;~-~, i5M Other: by order of Approved byk ~' "-/' k !''~~~ Commissioner the commission Date . Form 10-401R~v.~-T¢~¢~-1-85 ¢ SL '~ triplicate I ARCO ALASKA. INC. PAD 3H, WELL NO, 5 P~OPOSED KUPARUK FIELD, NORTH SLOPE, ALASKA 0 _ 1000 _ 2000 _ 3000_ = 4000 _ 5000 _ 6000 _ 7000. KOP TVD=?50 TMD=?50 DEP=O 3 BU[LD 3 DEO 9 PER I O0 FT 15 21 B/ PERMAFROST TVD=1591 TMD=1621 DEPm195 EOC TVD'l?82 TMD'! 841 DEP'303 T/ UGNU SNDS TVD'1836 TMD'I 904 DEP'338 T/ W SAK SNDS TVD=2561 TMD=2766 DEpm803 K-12 TVD=2951 TlflD=3230 DEpmI054 9 5/8' CSO PT TVD=:31 51 TI'ID=:3468 DEP=118:3 K-S TVD=4376 TMD=4924 DEP=I 970 AVERAGE ANGLE 32. DEG 43 HI N T/ ZONE D TVD-5856 TMD=6683 DEP=2921 ~T/ ZONE C TVD=5861 TMD=6689 DEP-2924 ZONE A TVD=5922 TMD-6761 DEP-2963 TARGET CNTR TVD-5949 TMD-679:3 DEP-2981 B/ KUP SNDS TVD=6036 T~D=6897 DEP=3036 TD (LOG PT) TVD=6204 T~D-7097 DEP=3145 I I I 1 000 2000 3000 VERTICAL SECT[ON I 4000 I HOP I ZO~:AL PROJECTION SCAL. 1 IN. = 1000 FEET ARCO ALASKA, ! NC. PAD 3H, WELL NO, 5 PROPOSED KUPARUK FIELD. NORTH SLOPE, ALASKA 3000 1000 'sm,, m 1000 . 2000 _ 3000 . TD LOCAT[O#~ 1182' FSL. 1408' FEL ~'~EC- I1. TI2#. R8E WEST-EAST 2000 1 000 0 I I I 1 000 I SURFACE LOCAT [ ON ~ 1446' FNL. 281' F'dt. SEC:- 12. TI21i. RIlE SURFACE TARGET CENTER TVD-$949 TMD-6793 DEP-2981 SOUTH 2514 WEST 1601 TARGET LOCAT[O# ~ ! 320' FSL. 1320' FEL SEC. 11. TI2#. R8E S 32 DEG 29 MI N W 2981' (TO TARGET) I 1250 1 300 1350 1400 1 450 1500 1550 1 O0 1 50 200 250 300 I I I I I 350 I 400 I 700 'q6oo 4oo 800 1300 ! 100 %~200 I 300 ! 150 200 250 300 350 400 450 I I 450 5OO I , I 5OO 1250 1300 1350 1 400 1 450 1500 1550 KUPARUK RIVER UNIT 20' DIVERTER SCHEMATIC _1 L DESCRIPTION 1. 16" CONDUCT~ 2. FMC SLIP-ON WELD STARTIN6 HEAD ,3. FMC DIVERT'ER ASSEMBLY WITH ~WO 2-1/16' 2000 PSI BALL VALVES 4. 20' 2000 PSI DRILLII~ SPOOL W/lO" OUTLETS S. 10" HCR BALL VALVES W/10' DIVERTER LINES, A SINC,-I.E VALVE OPENS AUTOtlATICALLY UPON CLOSUI:D,E OF ANNULAR, PreVENTER. VALVES CAN BE REMOTELY CONTI~(3t, LED TO ACHIEVE DOWNWIND DIVERSION. 6. 20" 2000 PSI ANNULAR PREVENTER ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERT'ER SYSTEH AS A VARIANCE FROH 20AAC2'5.0:35(b) mAINTENANCE & OPERATION i 2 UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. 2, CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. 3. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBOf~ FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. DO NOT SHUT IN WELL UNDER ANY CII,~CUFISTANCE$ JG 11-3-86 7 6 DIAGFU~ #1 13-5/o' 5000 PSI ~ BCP STAQ( I. 16" - 2000 PSI TAN(CO STN~I'II~3 ~ 2. II · - _3000___ P~X C.a~IN~ ~ 3. I1' - ~3000__~ P~X X 13-5/8' - ~ P~! 8PACE~ ~ 4, 13--5/8" - 51300 I:~Z PZi::~ RAk~ 5. 13--5/8" - ~ I:~I [~llt INO ~ W/~ ~ Kill LII~.S ?. 13-5/a' - 5~30 P~! AN~LI. AR AOD.MIATCR CAPACITY TEST 5 . 13-5/8" B(::P STAO( TEST I. FILL ~ STA(3( ,q43 0413~ MI~IF(3.0 W131.1 AI:~CrIC 2. (:~EO( THaT AL/. LOC~ DI3M~ SCRER8 IN ~]J~:~IO FULLY RL:'rRACTED. $F. AT TEST PLUG IN WITH RLI~4IN~ JT ~ ~ IN L~ SCREY~. LIllE VALVES ADJACENT TO 8(P 8TA(](. ALL OT~ER 4. PRESS.I~ UP TO 250 P~I At43 HCI.D FOR I0 MIN. IN- (]iF_ASE PRF. SSJRE TO 3000 F~3I AN3 HOLD FOR I0 ~IN. Bl~:n PRESSL;~ TO 0 P~I. LI~E VALVES. CLOSE TCP PIPE P. AMB ~ HCR VALVES ON KILL AN3 04CI(E LI~ES. 6. TEST TO 250 PSI AM) 3OOOPSI AS INSTE3:4. ?. 03~rINLE TESTIN~ ALL VALVES. LI~So ~ 04CKES WITH A 250 PSI L(3~ ~ ~ PSI HIGH. TEST AS IN NOT A FLt. L CL(3~IM3 POSITIVE SEAL (]43(E. CN.Y ~,JI%~-TI(SI~i 1T~ST ~ THAT DO ~ FiA..J.Y (3,.(~. 6. ~ TC~ PZF~ RNa6 ~ (:L(:X~ 90TI'CM PZI:~ TEST 90TTCki PI~ F~N~6 TO ~ PSI ~N~ ~ PSI. I0. CI.C~E 9LZf~O P.~V8 ~ TEST TO ~50 PSI P~I. R_~ID. ~ ~ YALVES IN CRILLIN~ POGITICN. 12. TEST 5"TAN~IPE VALVES, KI=I_LYo KELLY 030(S, DRILL PIPE SAFETY VALVE, AI~ INtSIDE B(3:~ TO 250 PSI AhD 13. PECOI~ TEb"'r II~F~TICN CN BLCVKXJT PREVENTE~ TEST FCI~o SIG% AN3 SIDED TO DRILLING ~ISCR. 14. PF_RF(]~ ~ B(]=[ TEST AFTER N[PPL[NG UP WEEXLY ~ FI..~'TICI%aI.LY CPERATE BCPE DALLY. 510084001 ~EV.; MAY 15o t98! GENERAL DRILLING PROCEDUR~ KUPAKUK ~IVEI~ FIELD DEVELOPMENT ~ELLS 1. Move in rig. 2. In~tall Tankco diverter system. 3. Drill 12¥' hole to 9-5/8" surface casing point according to directional plan. 4. Run and cement 9-5/8" casing. 5. Install and test blow out preventer. Test casing to 2000 psig. 6. Drill out cement and 10' new hole. Perform leakers test. 7. Drill 8¥' hole to loggin$ point according to directional plan. 8. Run open hole logs. 9. Continua drillin~ 8½" hole to provide 100' between plug back total depth and bottom of Kuparuk sands. 10. Run end cement 7" casing. Pressure test to 3500 psig. 11. Dovusqueeze Arctic Pack and cement in 7" x 9-5/8" annulus. 12. Nipple down blow out preventer and install teuporar7 X~s tree. 13. Secure well and release rig. 14. ~mn c~sad hole logs. 15. Hove in workover rig. Nipple up blowout preventer. 16. Pick up 7** casing scraper and tubing, trip in hole to plug back total depth. Circulate hole with clean brine and trip out of hole etendin8 tubing back. 17. Perforate end run coupletiou asseubly, set and test packer. 18. Nipple down blow out preventer and install Xmas tree. 19. Chnga over to diesel. 20. Flow well to tanks. Shut in. 21. Secure well and release rig. 22. Fracture stimulate. STIR ,,~.w, STIR __ STIR S * , 1,,, CL~NER,, TYPICAL MUD SYSTEM SCHEMATIC T.,,~4 / ih Density DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Casing to Weight Up 9.6-9.8 8.7-9.2 Weight Up to TD 10.3 PV 15-30 5-15 9-13 YP 20-40 8-12 8-12 Viscosity 50-100 35-40 35-45 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 5-12 Filtrate API 20 10-20 pH 9-10 9.5-10.5 9.5-10.5 % Solids 10± 4-7 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW (Kuparuk average) and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. In accordance with Area' Injection Order No. 2, excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shutdown in disposal operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of the fluid disposal. LWK5 / ih 'reserve Pit wing valve swab valve master valve pad flQl~ line center Plan- View actuator valve I. valve line psi gauge I. adaptor swab valve wing valve---.~, flew'cross actuator valve Kuparuk Well-head Orientation .41RCO ALASKA, INC. master valve well line VR plug-. -- View froml Pad Center 1, , ARCO Alaska, Inc. I Post Office Box 100360 Anchorage, Alaska 99510~0360 Telephone 907 276 1215 June 16, 1987 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built (Wells 1-18) Dear Mr. Chatterton. Location Enclosed is an as-built you have any questions, Sincerely, Gruber Associate Engineer location plat for please call me at JG/pk GRU1/31 Encl osure Plat - 3H Pad the subject wells. 263-4944. If ARCO Alaska, Inc, is a Subsidiary of AllanlicRichtieldCompany 21, II 112 I II. III ~0o ALL WELLS LOCATED IN SEC. 12,. T. 12 N., R.8 E., UMIAT MERIDIAN. , ',~- i'~\~ 7,,. ~::'"'~ ~:'' '::' VICINITY MAI~ SCALE I"i 2MILES NOTES I. ALL COORDINATES ARE A.S.P., ZONE 4. 2. ALL DISTANCES SHOWN ARE TRUE. 3. ELEVATIONS ARE B.P.M.S.L. 4. REFER. FIELD BOOK L-87-19,35-441L.87-11, 6.0.6. ELEVATIONS FROM CED-RlXX-$471~ 6. HORIZONTAL POSITION BASEDON SH CONTROL MONUMENTS PER LOUNSBURYS~ Assoc. ASPs 'X' LATITUDE 6,000,110.73 6,000,135.5 I 6,000,160.57 6,000,185.28 6,000,210.66 6,000,235.50 6,000,260.34 6,000,285.82 6,000,310.30 6,000, 335.43 6,000,425.37 6, 000,450.51 6,000,475.46 6,000,500.41 6',000, 525.44 6,000,550.46 6,000,575.45 6,000,600.44 498,655.44 498,655.43 498,655.39 498,655.43 498,655.47 498,655.40 498,655.41 498,655.44 498,655.45 498,655.44 4 98,655.44 498,655.38 498~655.4~ 498,655.43 498,655.41 498,655.47 498,655. 55 498,655.59 70o24'41.531" 70° 24'41. 775" 70o24'42.0;>2" 700 70° 24 42.514 700 24:42.. 758:', TO° 24 45.003 700 Z4:45.253,", 70° 24,43.494 70°Z4 43.741" ?oo24'44.6z6" 70o~4'44.873'' 70°2 4' 4 5.119" 70024:45.3._6~," 70°24 45.610 70o24'45.856'' 70°24'46. !02" 70024'46548" LONGITUDE joist FN.L. 150o00. 39.4~6"l 150000' 39.417" 150° 00: 39.418" 150° 00, 39.417" 15o° 09: 50° O0 39.418 150° 00' 59.417" 150° 00', 39.417" 150°00 150o00'39.418, 150o 00'39.43C~' 150° 00'39.419" 50° O0 $9.41~ 150000' 39.417" 150000" 39.415" 150000'~.414" 154 6' 1522', 149 7, 1472, 1446 1422', 1397 1371' I $47'. 1 322 1232' 1207' 1182' II07' 1082' 1057' Dist F.W.L. ! 281 281', 281 281' 281' 281~ 281 281' 281', 281 281' 281' 2 61' 261', 281 281' 28 2' 262' O.G. Ele¥. 34.0' 34.0' 33.9: 33.8, 33.? 33,71 33.6 33.6~ 33.6, 33.6 33.7' 33.8' 33.8' 33.8', 33.6 33.8' 33.8' 33.6' Pod Elev. 38.8' 38.8' 38.7° 38.7' 38.8' 3e.e', 36.9 $8.7', 36.6, 36.6 38.7' 38.8' 38.8' 38.7: 38.7 36.7' 38.8' 38.9' I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENCED TO PRAC- TICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTSA LOCATION SURVEY MADE BY ME OR UNDER MY SUPERVISION,AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF 6/9/87. ARCO Alaska Inc. ECT D.S. 3H WELL CONDUCTOR AS-BUILT LOUNSBURY Associates ANCHORAGE ALASKA DWN BY: PJW CHK BY: JWT DATE: 6/9/87 NSK 6.308-d5 i , i (3) (9 (lO ana "13) . (4) (14 rJ~ru 2.2) (2,~ ~ 128)11 (29 ) (6) Add: rev: 01/28/87 6.011 YES ~0 1 Is the permit fee a~cached ~- --- 2. Is well to be located in a defined pool ............................. ~ ~. Is well located proper distance ~ prophecy line .................. 4 Is well located p ~roper d~ ~rance f~cm orhe~ wells · ~ Is sufficient nndadica~ed acreage cycle in ~ pool ......... Is operator ~ only affected par~y ................................. 8 Can p~r~_'_t be app~d before fif:een-day wai~ 9. Does opera:or ~ve a bond in force .................................. ~ 10. Is a cm'~emmt::Lm~, order needed. ...................................... 11 Is a~m*n~ ~ra:ive ~~-nee~d 12. ~ ~ l~e m~ ~r~~a ............ ~ 14. Is conductor s~-ing provided ........................................ ~ Will surface casing protect fresh water zones ,,/Z~' ' , 16. Is enough cement used to circulate on condudtor and surface ......... ~f ,,, 17. Will c~t ~ie in surface and intermediate or production strings ... ,~ 18 Will cmm~n~ t omm_r all known produc=ive horizons ,,~¥ ----- ,, 19. Will all casing give adequate safe~y in collapse, tension and burst.. ~ 20. IS rtzis well to be kicked off frcm an existing we!lbore ............ ~, ,,,,, ~, 21. Is old wellbore abandommen= proce~e included on 10-403 ............ 22. Is adequate we!lbore separation proposed ............................ ~ ,,,,, 23 Is a diver~er system required - ~ 24. ~ ~ ~ ~d p~~ s~~c ~d ~: of ~~: a~~:a ~ 26. ~ ~ ~ ~~~= pr~~ ra~ - Tes: :o ~ ps~ .. 27. ~ ~ ~ ~*old ~ly w/~I ~-53 ~ 84) .................. ~. ~ ~ ~~ of ~S g~ p~b~ ................................. , For exploratory and St~a~hi¢ 29. Are dare presented on potential overpr~sure zones? ................. 30. Are seismic ~.ysis d~ presented on shallo~ gas zones ............ ~. ~" 31. If an offshore loc., are survey results of seabed conditions pm~ented__ POOL CLASS STATUS ARFA NO. SHORE ,, , Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ~aska OiJ & Gas Cons, Commissio~ Anchorage LIS TAPE VERI FICATI [~tN bISTING P~GE .E'.~ v ! CE N A !,,". E : E:L)iT ATE :87/09/!.7 RIO;TN : EEl., ~ ~ ,~,~ E :72445 ONTI~UATIGN # :01 RE¥IOUS R F,B[ L O'~P:~ThTS :LIS ',rAPE, ARCO KUPARUK 3~1-5, AFl ~ 50-103-20077 * ThPF HEADER ** ERVICF NA;~E :EDIT ~TE :87/09/17 'RIGIN :7244 APE NA~.E : 'ONTINUATIOt,~ ~ :01 ~RB;VIOUS TAPE : Om:JPENTS IL, IS TAPE, ARCO hUP,ARUK 3H-5, APl ~ 5(;-1()3-20077 ********** EL)F IbK ~,~ A :M E :EDIT .001 ~AXI~U~ LE~'~GTH : 1024 'ILE TYPE : ~EV!OUS FILE : UNIT TYPE CATE SIZE CCDE JN : A~CO ALASKA, INC, 000 000 018 065 ~N : 3H-5 000 000 004 065 rN J ~tJP~RUK 000 000 008 065 ~AN~: 8E 000 000 002 065 ~OW~: 12~ 000 000 004 065 !ECT: 12 000 000 002 065 ()UN: NDRTH S[~OPE 000 000 012 065 ~TAT: ALASKA 000 000 006 065 ~T~:¥: I.,;S~ OOO 000 004 065 q NE~ CO~ TENTS UNiT TYPE CA~:E SIZE ?RES: E 000 000 001 065 ************************************************************************************ qP 010,}.~02 VEi:~I:["ICATIt!~,~ LISTIt,~G P/~GE 2 AI.,ASKA CO~.*POTING CEi~I~iER , ELL PI ~ = 50-103-20077 IEI,D = KUP~RU~. OL.INT'Y = ~'~OR'fa SLOPE ~OROUGH OB NU~E[{ ~T ~KCCI 72445 U~ ~1 D~TE bOGGED: 14-SEPT-~7 DP: R~CK KR{.IL~ELL YPE FLUID Ea~S] TY ISCOSI~'Y LUID LOS,q, ATI~I X S A ~,{.I:)S T(3i4 E = 9,625" fa :]454' ' ~IT SIZE = 8.5" TO 7166' = bSi'~ D : 10 LB,tG RFt = 5 16 ~ 63 DF = 37 S R~F = 4~96 ~ 69 DF = 9,O R/4C = ~,29 ~ 63 DF = ~,~ C3 RM AT BMT = 2,491 8 ~38 DF OTE'.. , Fi!:~E ED!T.O01 CO!'VTAIN,S.. DATA 5AtiPLED.. i,.a ,5' FILE EDIT,O02 COaTAI~,}S HIGH RF, SClt~UTIUN {)ATA ,AaPLED Ca 1,2" VP OlO,h02 ~'k~RIFICAT.[Oi'~ LISTIr/G PAGE 3 , , , , , , * , , , , , , , , , , , , , , , * * , [)~hi., i,,~ouc'rlOt2 SPHERiCAl,BY F()CL}SED LOG · DA"rA aVAIbABLE: 7160' TO 3457' · FO~,,~ATIO~ i)K~SI.'RY CO~p~3,~iSATEp bOG (FDN) · DAI'A AVAILABLE: · 7134' 6542'/ 6246' 5636'/ 4946' · DATA Ali A ! bAi,~LE: · 7119' 6548'/ 6234' 5695'/ 496~' 4B~6' · (.,A~,~i:~'.~' RAY ].~, CASING (C$~.)" * · FC]R~A"r!I)N DEh$ITY CO.~iPE~SATE[) bOG ~iI REO · DATA AVAILA~[,,E: 7135' TO 6548' · CO~PE.NSg.'I'EO i'~ELITRON LOG ~.41 RES (FDa) · DATA AVAILABbE: 7119' TO 6548' · , * , * , , * , · , , * , * * * , , , · PAGE 4 * Ot~TA FOR<AT RECGRD NTF¥ PLUCKS TYPE SIZE RF'.PR CODE ENTRY 2 .1 66 0 4 1 66 1 8 4 7 3 6n 9 4 65 ]6 1 66 1 0 1 66 0 ATUt~; SPEC!FiC,ATIOh~ BI~OCKS NE~ SFRVICE SERVICE U~II API AP1 API APl FILE SIZE SPL REPR ID ORDER .~ LOG TYPE CI,ASS EPT FT O0 000 O0 0 0 4 F L U ~ I L C' H ~. ~ 00 22 (') 01 O 0 4 hD DIL OHit,~ O0 120 46 0 0 4 L~ DIG ()H.~ O0 120 44 0 0 4 ,P C'IL ~v O0 010 O1 0 0 4 ;R DIL GAPI O0 ]10 ~ENS DII., LB O0 635 21 0 0 4 'R FDN GAFI O0 310 O1 0 0 4 :ALI FDN Ib;~ O0 280 O1 0 0 4 :HOD FDN G/C3 ()0 350 02 0 0 4 ~RHO FDN G/C3 O0 356 O1 0 0 4 ~RAT FDN O0 420 O1 0 0 4 '~NRA FDb 00 000 O0 0 0 4 ~PH I Ft)N PU OO 890 O0 0 0 4 ~P~I FD~ PU O0 890 O0 0 0 4 ~C~b FO~ CPS O0 ]30 3! 0 0 4 ~E N $ F O ~'~ L ~ O 0 635 21 0 0 4 ;R CSG G~PI O0 ]10 ol o 0 4 ~ENS CSG LB oo 635 21 0 o 4 PROCESS CODE (OCTAL) i 68 00000000000000 1 68 00000000000000 1 68 00000000000000 I 68 00000000000000 ! 68 00000000000000 1 68 00000000000000 I 68 00000000000000 I 68 00000000000000 I 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 I 68 00000000000000 1 68 O00OO000000000 I 68 00000000000000 1 6~ 00000000000000 t 68 00000000000000 1 68 00000000000000 I 68 00000000000000 1 68 00000000000000 )EPT ~Li 7174 5000 SFLU -3B 46.88 (;R 5 1719 RHOg 3 4570 ~PhI 624 5000 TEaS )EPT ~P ]ALI tNRA ;'CNL 7100 0000 SFLU -30 0000 (;R 8 7969 RH{3~ 3 5508 NP~i.I 561 000o TE~$ 3 1815 101 0625 TENS 2 4180 36 3281 DP~I 3864 0000 GR 3,09~9 ILg 2674,0()00 GR 0,1118 NRAT 52,4"787 NCNL '999'2500 fENS 3864:0000 OR 0.0190 ~RAT 14'0711 NCNL '999,2500 TENS 2 .]649 100 4375 3 2637 2160 0000 -999 2500 9180 0625 1484 oooo 25OO VP O1C,HC'2 Vk',P,I,FICATiO!i LISi?Ii,iG PAGE 5 EDT 6~900.0000 SFLU P -21 25OO Ga AL1 8;8672 NRA 2,8867 ~) 000 663,, EPT 6800. 0000 SFLb P -65.2500 GR ALI 8 5469 Rri[!a NRA 3:627(, NP~I CNL 579.5000 TENS 'L. I 6600,0000 SFbU -2~,5156 GR :~bl 9.3516 RHO~ NRA ,t.2578 NP)~I 'CNb 380,5000 TE~$ ~EPT 6500 ;P ',ALI -999 [~RA -999 NL -999 ~EPT 6400 ;P -37 ;ALI -999 tNRA -999 "'C~iL -999 ~EPT 6300 ;P -41 ~AbI -999 tNRA -999 'CNL -999 0000 SFhU bO00 250O 25(i0 NPH1 2500 0000 SFbO 2500 Ge 2500 R~.~O~ 25OO t~PHi 250O TE~$ 0000 SFLU 5000 GR 2500 RHOB 2500 NPHI 2500 TENS )EPT 6200.0000 SFbU ' -51':' .... ~' bi 9,8359 ~N~A 3,5762 ~P~iI 0000 TE~$ ~CNL 549,. 4.2296 ILL~ qB,0000 TENS 2.4180 39,0484 3904.0000 0000 TENS ~:4141 3984 DPHI 3594,0000 133 249! 68 8750 2 5332 41 3574 ]684 0000 1.4162 1.21,3750 2.3184 46,2402 3570,0000 2.6116 1.13,4375 2,3770 46.2402 35!0,0000 3 7193 193 7500 -999 2500 -999 2500 -999 2500 3 9686 140 0000 -999 2500 -999 2500 -999 2500 4 5762 98 3!25 -999 2500 -999 2500 -999 2500 iLD TENS D P {~ I GR DR bl[.'] DPHI GR ! b D TENS GR ILD ~EN$ DPHI GR I. L9 T E ~: S DPHI ibD TENS DR.MO 0063 IbD 3750 TENS 2305 D P h I ."~254. 0000 3.2187 3904.0000 GR O.O293 NRAT 14 0711 -999~2500 TE~S 5.6526 Ib~ 3584,0000 GR 0.0225 NRAT 14.3078 NCNb -999,2500 TENS 1!9.7469 lb~ 3684,0000 GR -0.0161 NRAT 7.0879 NCN[, -999.2500 ~ENS 1.6477 IbM 3570,0000 GR 0,0098 NRAT 20,1074 NCNb -999.2500 TE~S 2.2609 IbM 3510.0000 GR 0,0205 NRAT !6,5566 NCNb -999.2500 ~ENS 2,5450 I.b~t 3704,0000 GR '999,2500 NRAT '999,2500 NCNb '999,250() TENS 3,4064 Ib~ 3474,0000 GR '999,2500 NRAT -999 25 0 i~CNb -999,2500 TENS 4.2009 3284,0000 GR T -999,2500 NRA ~ N -999,2500 NC.'L -999,2500 TENS 3,7345 IhM 3254,000() GR 0,0171 NRAT 11,5855 NCNb -999,2500 TENS 3 3620 98 0000 3 3066 1924 0000 -999 2500 6,0534 89.0000 2,9961 1915,0000 -999,2500 110,1502 68,8750 3,4023 2102.0000 -999,2500 1,5981 121,3750 3,7070 1692,0000 -999,2500 2 3338 4375 1621 0000 -999 2500 2 6504 -999 2500 -999 2500 -999 2500 -999 250O 3,4548 -999,2500 -999,2500 -999.2500 -999,2500 4 2844 -999 2500 -999 2500 -999 2500 -999 2500 3 8O21 1113 3750 2285 1964 0000 -999 2500 EF:'T e,!O0,OOO0 S.Ft:iJ P -39 5000 GR AI, I 9:53!3 RHO~ NRA 3,74,31 N~HI C~b 512,o00o TEi~,$ EPT 6000 O00O SFLU P -51 '.7500 GR AL1 gi6328 EH08 NRA 3 0938 NP~[ CNL 619,0000 TENS EPT P AL1 .p 'CNL ~EPT ~p ;P ?ALI tNRA ' C N L ~P )EPT ;P ]AL I 5800 0000 -69 7500 8 8906 3 5879 588 5000 5700,0000 -51,7500 9,101.6 3.33'19 568.0000 5600.0000 ~50,5000 ' 99,2500 -999,2500 '999.2500 5500 0000 -43~7500 -999'2500 -999'2500 -999,2500 5400 0000 -53 5000 -999 2500 -999 25O0 -999 250O 300,0000 ~46.5000 99,250() -999.2500 ,999,2500 5FLU NPHI SFLL! RHOB NPHI TENS G~ NPHI TENS SFLU GR SFLU GR NPHI S P [, U GR R~,tUB T~;NS 3.637 o 103,3125 2,4707 40,9668 4, C, g 60 1 L D 100.4375 TENS 2 4121 34!7656 DP}ii 3190 0000 G~ q8i1875 TENS 2 3945 D~hO ..]8 6719 UPH1 3210. 0000 GR 5,1947 IbD 74,6875 TE~$ 2. 3223 [)RHO 442oooo 4.229~ ~9 7500 TENS 2i3750 DRHO 361328 DPHI 3i. 20 0000 GR 4 1466 92 3125 -999 2500 -999 250o -999 2500 3 8005 I02 6875 -999 2500 =9gE 2500 -999 2500 TENS DRHO DPHI GR ILD TENS DPHI GR 3,5712 ILD 96,1875 TENS -999,2500 "999.2500 'g99,250() GR 3,6708 ILD !04.6250 TENS '999'2500 DRflO '999'25()0 DPHI '999,2500 GR 2.9 408 I L M 20. U 000 G R. 0,028.t NWAT 10,8'154 NCNb '999,2500 TENS 4,2167 3190.0000 GR 0,0044 NRAT 14,4262 NCNb -999,2500 TENS 5,3221 Ib~ 3210,0000 GR -0,0020 NRAT 15,4914 NCNb -999,2500 TENS 3.5526 lbs 3044,0000 GR =0,0088 NRAT 19,870'1 NCNb -999,2500 TENS 3,9060 3!20,0000 GR 0,0142 NEAT !6.6750 NEVI.. '999,2500 TENS ~,0"124 3220 0000 -999 2500 -999 2500 -999 2500 3,6004 3100.0000 -999,2500 2500 -999, -999,250.) 3,5429 3000.0000 999,2500 999,2500 999,2500 3,6668 31!4.0000 '999,2500 '999,2500 =999,2500 IL~ GR NEAT NCNb TENS NEAT NCNL TENS NRAT .Ib~i GR NEAT NCNb TENS 3,0544 103,3125 3.4629 !917,0000 -999,2500 4 2673 100 4375 3 1328 1916 0000 -999 2500 5.1699 98 1175 3~3 98 1933,0000 -999,2500 3 7725 74 6875 3 2402 2112 0000 -999 2500 4 0435 89 7500 3 1621 1897 0000 -999 2500 4,1533 -999,2500 -999,2500 -999,2500 -999.2500 3 6425 -999 2500 -999 2500 -999 2500 -999 2500 3 6OO 7 -999 2500 -999 2500 -999 2500 ,999 2500 3 6878 · .999 2500 -999 2500 -999 2500 -999 25o0 VI:' 010,HO~ ~KRIFICA'rlO!'.~ blS'rll:G PAGE ? 51_00 0000 S -999.2500 RHO~ -999.2500 -999.2500 EPI 5000. 0000 SFLb P -40.9687 GR AL1 -999.2500 RHOP, NPA -999 2500 t~PHI CNL -999;2500 T~NS EPT 4900,0000 SFLU P -33.2500 GR ALI 9.1953 RHOB NPA 3,976b NPHI CNL 440,0000 TENS EPT 4800,0000 SFbU ,P -49,5000 :ALI -999,2500 NRA -999,2500 NPHi 'CNb -999,2500 ~EPT 4700,0000 $~ ~. ;P -57.7500 GR iR[:l -999.25(.)0 Ri-lOB I:tqR A -999,2500 NPHI 'CNL -999,2500 TE', N,S >EPT 4600 0000 SFLU ;P -57 5000 GR ~EPT 4500 0000 SFbU ;P -.39~2187 GR JiLl -999 2500 ~N~A. -999 2500 :'C~b -999 2500 TEf~S )EPT 4400,0000 SFLJ ;p -40.0000 GR ~NRA -999 2500 NPHI ;'C~L, -999 2500 TENS 3. 317{:) ql 6250 -969~2500 -999. 250C DPHI -999.2500 3.2178 I!,,D 97,6250 TENS -999.25()0 DR}'iO -999 2500 DPHI -999:2500 GR 2.2025 ILD 99 9375 TEmS -999i2500 [?RHO -999 2500 DPHI -999 2500 GR 1 3525 lbo 96:4375 TENS 2.2969 DRHO 49 0094 DPHI 271.4~(,000) '' GR 3 2496 !30 5000 -999 2500 -999 2500 -999 2500 4,2417 107,0000 -999. 2500 :999 2500 999]~500 2 6127 155 2500 -999 2500 -999 2500 -999 2500 2 1196 121 1875 -999 2500 -999 2500 -999 2500 2,I854 94.1250 '999 2500 '~99 2500 '999 2500 I b D TENS DRHO OPHI I TENS D R H [.) 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