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Home My WebLink About197-221STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION AUG 0 5 2019 WELL COMPLETION OR RECOMPLETION REPORT AN 1a. Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned 2] • Suspended ❑ 20MC 25.105 20AAC 25.110 GINJ ❑ WINJ❑ WAG[:] WDSPL❑ No. of Completions: 1b. Well Class: Development ❑ Exploratory P ry ❑ Service Q ' Stratigraphic Test ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Date Comp., Susp., or Aband.: 7/7/2019 7. Date Spudded: 12/7/1997 14. Permit to Drill Number / Sun ' 197-221 3 Z 15. API Number: 50-029.22835-00-00 4a. Location of Well (Governmental Section): Surface: 166' FNL, 598' FEL, Sec 23, TIIN, R10E, UM Top of Productive Interval: 60' FNL, 364' FWL, Sec 24, T11N, R10E, UM Total Depth: 29' FNL, 576' FWL, Sec 24, T11N, R10E, UM 8. Date TO Reached: 12/811997 16. Well Name and Number: KRU 1D-120 9. Ref Elevations: KB:. / Jt GL: 71 BF: 'P 17. Field / Pool(s): Kuparuk River FieldMest Sak Oil Pool ' 10. Plug Back Depth MD/1 VP: y;i 4446/4235 Ila 18. Property Designation: ADL 25650 , 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 560490 y- 5959499 ' Zone- 4 TPI: x- 561451 y- 5959612 Zone- 4 Total Depth: x- 561663 y- 5959645 Zone- 4 11. Total Depth MD/TVD: • 4530/4315 • 19. DNR Approval Number: ALK 468 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MD/TVD: 1520/1510 5. Directional or Inclination Survey: Yes ❑ (attached) No Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: NIA (ft MSL) 21. Re-drill/Lateral Top Window MDfFVD: 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 IN AMOUNT WT. PER SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD GRADE TOP BOTTOM TOP BOTTOM PULLED 16 62.58 H-40 53 121 53 121 24 9 cu yds High Early 5.5x3.5 15.5/9.3 L-80 53 4510 53 4296 8.5 305sx AS III LW, 485sx Class G 24. Open to production or injection? Yes ❑ No (] If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Pertd): PERFORATIONS CEMENT SQUEEZED;below cement plug 3866-3898 MD and 3686-3716 TVD 3934-3970 MD and 3750-3785 TVD � �;� ISOLATED BY FILL; BELOW CEMENT PLUG 3981-4001 MD and 3795.3814 TVD I - A E 2 4068.4081 MD and 3877-3890 TVD 7 ... r 4100-4109 MD and 3908.3916 TVDVE 1 4118-4148 MD and 3925-3953 TVD 4180-4195 MD and 3983-3997 TVD 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 3112 3765 NIA 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No ❑ Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 53-3954 34 bbls 15.8 Class G in Tubing 53-3745 44 bbls 15.8 Class G in IA 3866-3898, 3934-3954 4.1 bbls 15.8 Class G into C&Upper B Paris 27. PRODUCTION TEST Date First Production: NIA Method of Operation (Flowing, gas lift, etc.): PLUGGED BACK Date of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press. Casing Press: Calculated 24Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravitv -API (corr): Form 10-407 Revised 5/2017 V7-7-, CONTINUEP ON PAGE 2 Submit ORIGINIAL only 0, r�/y RBDMSAUG 0 5 2019 � ,,,y„4 ,%y 28. CORE DATA Conventional Core(s): Yes ❑ No Evl Sidewall Cores: Yes ❑ No 21 If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presenceof oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No 2 If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval N/A N/A information, including reports, per 20 AAC 25.071. Formation @ TPI - 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, paleontoloaicalr r n or well results -per 2 7. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: G.L. Alvord Contact Name: John Peirce " " - Authorized Title: A ska Drilling Manager Contact Email: John.W.Peirce co .com Authorized Contact Phone: 265-6471 Signature: t%t•\ — Date: u 1 ( 20 1 INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate 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 10407 Revised 5/2017 Submit ORIGINAL Only Cono4hillips Alagra, Inc. KUP [NJ WELLNAME 1D-120 WELLBORE 1D-120 +D-D"hion"',zsx Aad I�nnaBr Last Tag Veruml xnemaec (xeail O'ZNy cemem Eil[90nI<e aISPT/Cemml Fit s3.O nNa .................. Nwker Pkm:9c Annotation mi ME, End Oa+e WellOore Last Teg:RKB 3,9540 3132019 1D-120 LOst M04 By zembae i Last Rev Reason Automation Rev Reason, P&A Final site clearance -UPDATED MARKER &TAG DEPTHS End Data Wellbore Lss+Moa By 3112019 1D -12B pproven Casing Strings C45ucTOP: 991]10 Calling Dare -[ion CONDUCTOR OD (inj 16 ID tan) Top (xIKB) 15.06 53.3 lelI i11h .xKB) 121.6 set Data+n lrvO.... Wvteu (I... GrWa Top 1210 62.58 H4 Thread WELDED Casing Dascnplio, SURFACE 5.5x35 OD(in) 51/2 IDlln) T -F ru"j 6.95 53.3 sae Daps lnxel 4,509.9 sef Oart.(Trad wuten S._Graa. TOPTM1mad 4,296.1 15.50 L$0 BTC RESWmITON: 366n Tubing Strings - _.. nbing oescrip(ion srma ma... IO(inl rota (xKBj set -dam (f[..Set oerh UVDJ I - We pbPg Grade Ter eonnectlOn TUBING 3112 2.99 53.3 3,764.9 3,5907 9.30 L-80 ABM-EUE Completion Details roplrv0) rota and Nominal Top (xrcel Ixrcel 1°1 Ihm Des cam Ip Pnj 3,725.1 3,5532 19.29 NIPPLE CAMCO W-1 NIPPLE w12812" SELECTIVE PROFILE 2812 3,763.9 3,589.8 19.23 SEALASSV BAKER GBH 22 LOCATOR EALA EMBLY- 'a EUAL 3.000 STAB INTO TAPERED SURFACE CSG GAs urr; 3.ezz.a Other In Hole (Wireline retrievable plugs, Valves, pumps, fish, etc.) Tap ODD) Top ma To,(.I (xrce) 1°I Des cam m(in) 53.0 53.0 000 Marker Plate P&A Remain plate with wellinfo 0.000 385.0 385.0 049 RESTRICITON Restriction in tubing. Able to get thru Will short 751.]50RIPPLE;3,M1 assembly 3,]40.0 3,56].2 192] TUBING PERF Tubing Perforation at 3/40' 2.9903,954.0 A�o Pexe 3T4o.o 3,]69.4 18.97 FILL FILL 0000TUBING 3,9540 3]694 189] TAG FILLAT TAG FILL0.000PAHWeld SCpalch;IT 11"cd mularlarstatedw/cii-c Genian PWg; 3,]dSDPo(a Perforations & Slots Shot SBALASBY, 3.79e ToplxKBl etmlxKB) Top lNul Ban (xKB. UndaDene (xKB) Lin Fed Zane Deh "Neslt Typo Co. 31e66.0 3,898.0 3,886.2 3,716.5 WS D, 1D-120 5/11/1998 4.0 .PERF .S FIC, D. ., Odeg Phasing, 90 deg Orient 3,934.0 7,970.0 3,750.5 3784S WS B, 1D-120 5/11/1998 4.0 IPERF 5 H. .P., e0 deg Phasing, 90 deg Orient 3,981.0 40010 3,]50 3,813.9 WSA4, 1D-120 511111998 4.0 IPERF .5 HG'ID..,10deg Phasing, 90 deg Orient 4,0680 4,0810 3,8773 3,889.6 WS A3,10-120 31111998 4.0 IPERF .5 H..1 .P., 180 deg Phasing, 90 deg Orient eememsPe.m: seeS.SMaa IPExF: sa�.oa,aesd 4,100.0 4,109.0 3,907.6 3,916.1 AS A2, 1D-120 5/11/1998 4.0 IPERF 2SH.. .P., le deg Phasing, W tleg Orient 4,118.0 4,148.0 3,9246 3,953.0 WS A2, .-120 5e"me8 4.0 IPERF 25 H. N. P., 180 deg Phasing, 90 tleg Orient 411800 41195.0 3,983.3 3,997.5 WS A2, 1D-120 5/9/1998 4.0 IPERF 2. .ro.P., tleg Ga... 3... Phasing, 90 tleg Orient PERF, 3,n.MaiO.O Cement Squeezes TAG PU-Nr', 3.954.0 Top IND) Btire( Go Top(xKBl Btm NNUS) MININ (xKB) Des Start Ooh Com 3,745.0 3,954.0 3,571.9 3,769.4 Cementplug 61812019 Stage#1-LINER 3,9340 3,9540 3,750.5 3,769.4 amen 67812019 WSB-SAND Squeeze 3,866.0 3,898.0 3,686.2 3,7165 amen 61612019 WSD-SAND Squeeze IPERF., S,w1.o-a,aol O� 53.0 3,7450 53.0 3,571.9 Cement Plug 611712019 5lage,-TUBING 53.0 3,745.0 530 3,5719 Cement Plug 6/172019 Stage #2 -IA Mandrel Inserts at .b IPERF4.ould -0,011.0� N ToplxKBl Tar ITV01 GREE Make Madel OD(N) Sam Valve Trans LaRh raps Pmt Sim (In) TRORon (Fee Run Doh Cam 1 3,6]29 3,5039 BST ATX 1 GAS LIFT DMV T-1 0.000 0.0 12/11.1997 pai a.ido. t..o- Notes: General & Safety End U.S. Assent do 5/611998 NOTE: Ddx & tag w22'x2 fi25" W 4412' Wq Broached tight spat @ 3283 w/WL is 2.803' IPERF: 4,118PA,10 O- 11/172010 NOTE: Vim Schematic rel Alaska Schematic9.0 31152019 NOTE: TAGGED TOP OF FILL @3954 702019 NOTE:P&Ad13'ofwellheadremove3.Mamerplaw gilded>4'beloworiginaltundra. IPERn4,RaoF,. i ALLSIRDO SURFACEeaA 5;5n9 aol 1D-120 P&A ABANDON WELL DTTMSTJOBTYP SUMMARYOPS 3/15/19 ANNCOMM DRIFT W/ 2.72" CENT, / S-BLR ASSEMBLY @ TAG TD @ 3954' RKB (EST. 241' OF FILL); ATTEMPT TO RUN 2.78 & 2.69 DMY WRP AND UNABLE TO GET PAST 365' RKB; MADE SEVERAL DRIFT RUNS AS SMALL AS 10 OF 1 3/4" BAILER AND UNABLE TO PASS RESTRICTION (SCARRING ON OUTSIDE OF BAILER). IN PROGRESS. 3/16/19 ANNCOMM MADE SEVERAL DRIFT RUNS (LARGEST 5'x 1.75" BAILER & SMALLEST 5'x 1.25" W/ 1.75 CENT) & ABLE PASS RESTRICTION @ 365-415' RKB GOING 380 FPM & TOOLS BOUNCING THRU (UNABLE TO PASS & LOOSE TOOL ACTION ANY SLOWER THAN 380 FPM). JOB SUSPENDED FOR PLAN FORWARD. 3/31/19 ANNCOMM (AC EVAL) : MIT -IA PASSED TO 2050 PSI. 4/19/19 ANNCOMM RUN A 35' DUMMY RUN MADE OF 5X4'1" STEM, 1-3/8" 5' PERF GUN ASSY. THROUGH THE RESTRICTION AT 360'. MADE TO PERF DEPTH W/ ARMED GUN AND FIRED SHOTS AT 3740' TOPSHOT. CHARGES IN 1-3/8" PERF GUN INSUFFECTANT TO PUNCH HOLES IN 3-1/2" 9.3# TUBING. MAKE UP 1-9/16" PERF GUN AND PLACE IN TOOL STRING. MADE TO PERF DEPTH 3740' TOPSHOT. GUN FIRED. GOOD CONFIRMATION OF FIRE. TUBING TO IA COMMUNICATION WAS AGAIN CONFIRMED WITH 1 BBL /MIN FLOW RATE DOWN THE IA AND INCREASE OF PRESSURE ON THE TUBING. TUBING WAS THEN DIESEL CAPPED WITH 2OBBLS. 6/8/19 ANNCOMM CIRCULATED WELL WITH 120 -BBL LEAD FRESHWATER FOLLOWED BY 5.5 - BBL 15.8# CLASS G, 5 -BBL FW TAIL SPACER, 5 -BBL FLOVIS, AND 14.5 -BBL DIESEL. CLOSED IA TO HALT RETURNS AND PUMPED ADDITIONAL8.5-BBL DIESEL TO PLACE CEMENT AT PERFS (EST 4.1 -BBL INITO PERFS AND 1.5 - BBL REMAINING IN TBG). SLIGHTLY OPENED CHOKE CIRCULATING IN MIIN RATE 19 -BBL DIESEL FP, THEN SLOWLY EQUALIZED TBG AND IA. TRAPPED 730 -PSI WHP. 6/11/19 ANNCOMM (PRE STATE WITNESSED) TAG TOP OF CEMENT @ 3745' RKB. CMIT T X IA TO 1500 (PASS). DDT TO 0 PSI (PASS). READY FOR STATE WITNESSED. 6/13/19 ANNCOMM (STATE WITNESSED) TAGGED TOC @ 3745' RKB w/ 1.75" SAMPLE BAILER. PERFORMED CMIT TxIA TO 1500 PSI **PASS**. PERFORMED DDT TO 0 PSI **PASS**. PERFORMED STEP RATE CIRC TEST DWN TBG TAKING RETURNS UP IA. (2 BPM @ 700 PSI) READY FOR CEMENT. IN PROGRESS 6/17/19 ANNCOMM CIRCULATED WELL WITH 120 -BBL LEAD FRESHWATER FOLLOWED BY 82 - BBL 15.8# CLASS G CEMENT. JOB COMPLETE. 6/22/19 ANNCOMM (P&A PREP) T/IA DDT PASSED TOC OF IA = 11". (IN PROGRESS) 7/2/19 ANNCOMM (P & A) REMOVE WELL HEAD AND CELLAR 7/3/19 ANNCOMM (P&A) DRIVE 10' X 16" PIPE & IN GROUND FOR SHORING 7/4/19 ANNCOMM (P&A) DRIVE PIPE TO 15' AND REMOVE SOIL FROM INSIDE 7/5/19 ANNCOMM (P&A) REMOVE SOIL FROM PIPE (14.5') 7/6/19 ANNCOMM CUT 10'6" OF WELL OFF (13' TOTAL WELL REMOVED) AND PREP FOR MARKER PLATE. 7/7/19 ANNCOMM (P&A) STATE WITNESS GOOD CEMENT & MARKER PLATE, WELD PLATE AND BURY is :moi. �,�„�' _ .. �_.�� + �..c v � a:', i �� :� ,� J ... .P . i.. F /; 5` j ��,� � S � � j �r PPj 1. C � � � } .� 3 S� �<7�`l . >3m �,n • �I' n� ) 'v •H7� RR 2 � Y� �a wry.., 3 � � � '; .` ao — `r:. .. � s MEMORANDUM TO: Jim Regg ( 'e, 1j'z4jt j P. I. Supervisor FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: July 8, 2019 SUBJECT: Surface Abandonment KRU 1D-120 CPAI PTD 1972210; Sundry 319-229 July 7, 2019: 1 traveled to KRU 1 D pad to inspect the casing cut-off and marker plate on well 1 D-120. When I arrived, I met with CPA representative Roger Winters. We discussed the items that I wanted to inspect. The marker plate was found to have the proper items welded on to it (Company Name, Well Name, PTD and API numbers). The plate was 3/8 -inch thick and 16 inches in diameter. It fit the outermost string of pipe. The pipe was cut 4 feet below tundra level. All strings were full of good hard cement. I approved welding the marker plate on the casing stub and burying it. This well is in the middle of an active well row so the gravel will be left at pad grade. CPAI asked about location clearance inspection - I told Mr. Winters that AOGCC witness is waived but to send a picture after the well site was buried and graded — copy attached. Attachments: Photos (4) 2019-0707_Surface_Abandonment_KRU_1D-120_bn.docx Pagel of 3 Surface Abandonment— KRU 1D-120 (PTD 1972210) Photos by AOGCC Inspector B. Noble 7/7/2019 2019-0707_Surface_Abandonment_KRU_l D-120_bn.docx Page 2 of 3 Marker Plate Checking cement for hardness 2019-0707_Surface_Abandonment_KRU_ID-120_bn.docx Page 3 of 3 Marker Plate installed Well location after burial ►i NISQ M TO: Jim Regg "'�ee,N �, jq f P.I. Supervisor FROM: Lou Laubenstein Petroleum Inspector Section: 23 Township: Drilling Rig: NA Rig Elevation: Operator Rep: Sid Ferguson Casing/Tubing Data (depths are MD): Conductor: 16" O.D. Shoe@ Surface: 51/2" 0. D. Shoe@ Intermediate: Csg 0. D. Shoe@ Production: Cut@ 0. D. Shoe@ Liner: 3.5' 0. D. Shoe@ Tubing: 3.5' - 0. D. Tail@ Plugging Data Test Data: State of Alaska Alaska Oil and Gas Conservation Commission DATE: June 13, 2019 SUBJECT: Well Bore Plug & Abandonment KRU 1D-120 ConocoPhillips alaska PTD 197-221 Sundry 319-229' 11N Range: 10E Meridian: Umiat NA Total Depth: 4530 Lease No.: ADL 25650 Suspend: P&A: X ' 121 - Feet 3765 Feet Feet Feet 4510 Feet 3765 Feet Tvpe Pluq Casing Removal: Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Tbg Cut@ Feet Tvpe Pluq Founded on Depth Btm Depth To MW Above Verified Perforation " Bottom 3954 ft MD' 3720 ft MD' I Wireline tag 1.;+;�i 1r min 30 min 45 min Result Tubing 15001445 1440 " IA 1430 1430 1425 P OA Remarks: I traveled to 1 D-120 to witness the tag of a Cement plug and a combo MIT- T/IA. Sid Ferguson with CPAI was on location to orchestrate the test. Cement plug was pumped to isolatge reservoir parts, set on fill that partially obstructs the perforated interval. I witness a sucessful tag of the top of cement @ 3720ft done with Slickline using a 1001b tool string with a Bailer. A cement sample was obtained from the bailer showing good cement. The combo MIT-T/IA passed without any issue. Attachments: none i rev. 11-28-18 2019-0613_Plug_Verification_KRU_1 D-120_11 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY John Peirce Sr. Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, KRU ID -120 Permit to Drill Number: 197-221 Sundry Number: 319-229 Dear Mr. Peirce: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.aloska.gov Enclosed is the approved application for the 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, 0/25�0- Daniel T. Seamount, Jr. Commissioner r DATED thisZ3 day of May, 2019. RBDMS&MAY 2 4 2019 RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 0 6 P019 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 A ; 1. Type of Request: Abandon Plug Perforations 21 • Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. ConocoPhilli s Alaska Inc. Exploratory ❑ Development ❑ Stratigraphic ❑ Service 0 . 197-221 ' 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22835-00-00 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 1D-120 Will planned perforations require a spacing exception? Yes ❑ No 121 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25650 Kuparuk River Field/ West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD. Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 4,530' 4,315' 4,530' 4,315' 1500psi NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 80' 16" 121' 121' Surface 3,724' 51/2 3,765' 3,591' Surface 732' 31/2 4,510' 4,296' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 3866-3898, 3934-3970, 3981- 3688-3716, 3750-3785, 3795- 3.500" L-80 3,765' 4001 4068-4081 4100-0195 3814, 3877-3890 3908-3997 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): N/A N/A 12. Attachments: Proposal Summary Wellbore schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development❑ Service O ' 14. Estimated Date for 5/26/2019 15. Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG '� GSTOR ❑ SPLUG ❑ 7 ( 16. Verbal Approval: Date: Commission Representative: GINJ ❑> Op Shutdown ❑ Abandoned p 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: John Peirce Contact Name: John Peirce Authorized Title: Sr. Wells Engineer Contact Email: John.W.Peirce@cop.com Contact Phone: (907) 265.6471 /6 Authorized Signature: � Date: J / 1. COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: /✓, l_�II Plug Integrity BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance �/ Other: (/GL r/�7 v�PC to 20f1 sfC 2 cl rcrn ted to a,ttow CL✓✓+Tv�� pl�q/ Post Initial Injection MIT Req'd? Yes ❑ I LI� Spacing Exception Required? Yes ❑ No Subsequent Form Required. (d ^ -q p RBDMS MAY 2 4 2019 APPROVED BY Approved by COMMISSIONER THE COMMISSION Date: f'1213117 ,/ o �',t1 IYTt '512211q /2 21 / y !��II////'�� 7I✓"('� R 11l/1�7 I N A ,y Submit Form and J X7 Fnrm 10-403 aemred 4/2017 Approved applicaO i! 171151 fEI12 r0orltll5 fib a date of approval. //� Attachments in Duplicate KUP INJ WELLNAME 1D-120 WELLBORE 1D-120 ConocOPhiiiips Alaska, Inc. 11thIM 4/N/A191?47:4A PM Last Tag Vm WCMnulactWl FnnWWm DepIM1 (11N8) Ent Ooh minwee IWIMWBy Last Tag: PIKE ,54.0 31152019 10.120 zembaej Last Rev Reason ................................................ _.......... RANGER; AS AnnoMfon E,p Ooh WellEore Lasl Mo40y Rev Reason: Pert Tubing 4/192019 1D-120 bwortu Cuing Strings toeing oescrlpoon oolm) iDonl ropinital $IDepMff XBo 3MDepmiho WOLenp,.. crate Top mrea] CONDUCTOR 16 15.06 41.0 121.p 121.0 62.58 H-00 WELDED Laden Description OD lint ID lint Top Petal SM OeIXE (RMB) setLues, IN01... WxLen ll_. Once Top Tarea4 SURFACE 5.5x3.5 51/2 4.95 1 40.6 4,509.9 4,2961 15.50 L-80 BTC Tubing Strings Tubing DescriRpon snmg M.._ 110 (in) Rep Mpa) gel Depm RL. sal Dep[n IND 1... W101Mx) GrMe roP eonnaelbn TUBING 3112 299 88 3,]64.9 3,590] 030 1_A0 ABM-EUE Completion Details wxWcroR; ato-1]LO Tev MD) rap llwl xommn TnPIIMB) ryucB) M Imm Dee com ID (in) MA 388 000 HANGER VETCO GRAY TUBING HANGER 3500 RESTMOITON;33y0 7725.1 5553.2 1929 NIPPLE CAMCO W-1 NIPPLE w/2.812" SELECTIVE PROFILE 2.812 3,]63.9 3,589.8 1923 SEAL ASSY KER A EALA EMBLY-1. 3.000 STAB INTO TAPERED SURFACE CSG Other In Hole )Wireline retrievable plugs, valves, pumps, fish, etc.) Top OVDl Topind Top o"ID (ntoe) C) oee 1 com Run Dale IDID) 385.0 385.0 049RESTRICITON Resvicuhe in tubing. Able'D get into no soon IJ" 371612019 1]50 assembly ws UFT;aan.9 3,740,0 3.5672 19.27 TUBING PERF Tubing Pedombon at 3]40' 4/192019 2.990 PATCH Wdd BC paten, 1411 connector reinstalled wrote Pon. 9/1]2006 Perforations & Slots NIPPLE. 3hM1 sea apes Topm s) ann(MB) roPITVo) ( 8) B.iTVD) ME) Lmketlzone os4 Ienolsm ) Type com MdNGPaRF3]460 3,866.0 3,898.0 3,6862 3.7165 WS O, I C1m 911/1998 4.0 IPERF 2.5 H. N.P., 180 deg Phasing, 90 deg Orient 3,934.0 3,9]0.0 3.)505 3)84.fi WS B. iD-120 911/1998 40 IPERF .5 HCID.P., TUd.g Pleasing. 90 deg Orient 3,981.0 4,0010 3.795.0 3,8139 WS A4, 10.1 911/1998 40 )PERF 6H. 1D. ., ag Phasing, 90 deg Orient sF-4l.Ase, Amo 4,0680 4,081.0 3.8]].3 3,889.8 WS A3, 1D -12T 91111998 4.0 IPERF 7n 2S HT77egh Phasing, 90 deg Onset 4,100.0 4,109.0 3,9076 3,916.1 WSA2, 1D-1 511111998 4.0 IPERF 2.5H.. eg Phasing, 90 tleg 0dent 4,118.0 4,148.0 3,9246 3,953.0 WS A$10.1 M 59/1998 4.0 IPERF 2.5 H.. Deg I I Phasing, 90 deg Opens 4,180.0 4,195.0 3,983.3 3,9925 WSA2,1D-120 9911998 4.0 IPERF2.5 H. 1D.P., e9 1 Phasing. 90 tleg Orient Mandrel Inserts IPEal 3..5. ,Rspp- at eu H ieplKKB) ToMe) (XNa) Meke Mo4N 0D'.' sery V+Ive Type lalcti pot Type Size gn) iRO Run lnsi) Run aab Com ]2.9 3503.9 BST ATX 1 GAS LIFT DMY T-1 0.000 0 1 111199] IPERF 35 DASRE.o� Motes: General & Safety Ent oma An" ion 5161190 NOTE:Ron&nag w/22'x2.625-to 4412'WL; Bmacbed tiger spot@ 3283 wANL@ 2.803' 111172010 NOTE:vom SMematicwl Aiaska SCheMa11C9.0 IPERF,$Ero hWta- IPERF.4.fBe,o4,®10� RPERF 4,100"Irs 0� IPERF; a1f A04,146.0� IPERF;4,19104,1950� ."a.EANa.s40.a age.- Current Completion J I I 1 D-120 Plug and Abandon PTD # 197-221 16", 62.5#, H-40 Conductor to 121' KB 5.5", 15.5#, L-80 Surface Casing to 3765' KB 3.5", 9.3#, L-80 Tubing & Liner to 4509.9' KB 3.5" Tubing restriction exists at 365 - 417' KB Cannot pass BHA's bigger than 5' OAL x 1.75" OD Tbg & IA Diesel Filled with Diesel GLM W/DV at 3672' KB 2.812" Nipple at 3725' KB Tubing Punches at 3740' KB Seal Assembly at 3763.9' KB Top of Fill tag at 3954' KB (3/15/19) 3 Paris Open: WS D 3866 - 3896' KB WS B 3934 - 3970' KB WS A4 3981 - 4001' KB WS A3 4068 - 4081' KB� WS A2 4100 - 4109' KB WS A24118-4148'KB WS A2 4180 - 4195' KB 3.5", 9.3#, L-80 Liner 3765 - 4574.1' KB )A Cement Top Job nent Plug #2, .8# Class G, 0' KB in Tbg & IA ant Plug #1, W Class G, all at 3795' KB, Cement in Liner - 3954' KB, )ement in Paris JWP 4-25-19 Proposed Procedure for 1 D-120 Plug & Abandonment to Surface It is proposed that 1D-120 well work be performed to cement squeeze the perforations. The cement squeeze would be followed by a CMIT to verify that the formation is isolated. 1D-120 would then be filled with cement stage #2 to surface. The wellhead would also be removed, and ✓ a well ID plate would be welded onto the casing before 1 D-120 is backfilled and buried. Well History: 1D-120 West Sak injector was drilled & completed in Dec 1997 as a 'single casing' well with 5.5", 15.5#, L-80 Surface casing to 3765' RKB. 1D-120 has 3.5", 9.3#, L-80 tubing to 3765' RKB where seals are stabbed into a 4" ID Sealbore Extension at the XO in 5.5" x 3.5" Casing. The 3.5" liner is 9.3#, L-80 extending from the XO at 3765' RKB to 4509' RKB (4296' TVD). 1D-120 was on injection at 320 BWPD, 950 WHIP until 3/15/19 when SL tagged fill at 3954' RKB with a 1.75" Bailer. Fill currently covers A2, A3, and some of the B Sd perfs. A subsidence drift with 2.78" OD Dummy WRP tagged an obstruction at 365' RKB in the tubing. On 3/15/19, SL also ran a 2.69" dummy WRP to 365' RKB, but it would not drift past 365' RKB. On 3/16/19, SL RIH with 5'x 1.75" Bailer and worked thru the tubing restriction. On 3/31/19, an MIT -IA to 2050 psi passed. Due to the tubing restriction at 365' RKB, it is proposed that 1 D-120 be plugged and abandoned to surface. On 4/19/19, E -line ran a 1.562" OD perf gun BHA with knuckles every 5' to successfully shoot circulation holes at bottom of the IA at 3740' RKB. A circulation test pumped 20 bbls Diesel down tubing to IA to verify that circulation rate existed of at least 1 bpm. This proposal places cement into the open perfs above top of fill at 3954' RKB. Fill partly covers the B Sd perf interval at 3934 - 3970' RKB. The D Sd perf interval at 3866 - 3898' RKB is uncovered. Thus, cement will be squeezed into the open B sand perfs and open D sand perfs. Safe access with coil tubing or wireline tool to the or covered by fill to ena le a cement squeeze these perf interval—s—.Thus, this procedure cement squeezing only the perforation intervals that are open above top of fill at 3954' 1D-120 Proposed P&A Procedure COh Lug. Fullbore Cement P&A - Cement Plug #1: Objectives: Fullbore 5.5 bbls Cement down tubing to place 4 bbls cement into the open perfs above fill at 5 RRB, and to leave 1.5 bbls Cement under -displaced in 3.5" liner to leave TOC at 3839' RKB. WOC and obtain an AOGCC witnessed CMIT of this bottom cement plug that isolates the reservoir per 20 AAC 25.112. 2.992" ID Tubing and Liner Volumes to fill with Cement: In perforations above TOF at 3954' RKB In 3.5" Liner above TOF at 3954' RKB Total 15.8 ppg Class 'G' Cement = 0.0087 bbl/ft = Total squeeze volume = 4.0 bbls _ (3954 - 3782')(0.0087) = 1.5 bbls = 5.5 bbls 1. Schedule pilot testing of P&A cement design. Cement job requires 5.5 bbls of pumpable 15.8 ppg Class 'G' Cement. 2. MIRU Cement Van. Conduct PJSM. Inspect location for pre-existing conditions. Mitigate hazards. Mitigate personnel exposure for PT, and then PT equipment. 3. Pump Stage #1 Cement job as follows: Tubing Volume to Circ Holes at 3740' RKB = (.0087)(3740) = 32.54 bbls. Tubing + Liner Volume to first open D Sand perfs = (.0087)(3866) = 33.63 bbls: Tubing + Liner Volume to top of fill in B Sand perfs = (.0087)(3954) = 34.40 bbls. One barrel in 3.5" tubing fills —115' tubing. a) Open IA to tanks and circulate 120 bbls of Lead Freshwater down tubing through tubing punches at 3740' RKB and up IA to tanks at max rate to 3 bpm to circulate all Diesel FP from tubing & IA to tanks to prepare well for cement job. As soon as good circulation is cid at circ rates of at least 1 bpm, start mixing 15.8 ppg Class 'G' Cement to provide a 5.5 bbl 'pumpable' batch of cement pump immediately after the 120 bbls of Lead Freshwater has been pumped. As approaching 120 bbls Lead Freshwater pumped away, leave IA open and adjust pump rate to 1 bpm, then swap to b) 5.5 bbls of 15.8 ppg Class 'G' Cement down tubing (Cum—Vol = 5.5), followed by c) Foam Wiper Ball foF 3.5" Tubing (Cum—Vol still = 5.5), followed by d) 5 bbls Freshwater Tail Spacer (Cum_Vol = 10. 5), followed by e) 5 bbls Biozan Cement Contaminant stage (Cum—Vol = 15.5), followed by f) 14.5 bbls Diesel FP (Cum—Vol = 30), followed by g) Close IA to halt returns. To enable squeezing cement to open perfs without getting cement into IA as cement passes open circ holes at 3740' RKB which starts when Cum Vol = 32.54 bbls away. This closes IA at —2.5 bbls before cement is due at circ holes, because we don't want cement circulated through the circ holes. h) With IA closed, pump another 8.5 bbls Diesel down tubing at rate that can be achieved below 1200 psi WHIP, or at least at 0.25 bpm to slowly squeeze cement to open perfs. Pumping at 0.25 bpm mimics 320 BWPD PWI rate 1D-120 was injecting before becoming Sl. Pumping > 1200 psi WHP would likely be over Frac pressure at perfs. After the additional 8.5 bbls of Diesel is pumped away (Cum—Vol = 38.5), then I) Shutdown. Close Tubing & hold pressure. Do Not Overdisplace Cement. At Shutdown, Cum Vol pumped = 38.5 bbls away. The Wiper Ball has been displaced with 33 bbls of fluid to put it at 33 bbls x 115 ft/bbl = 3795' RKB = 55' d below the circ holes at 3740' RKB. 4 bbls Cement should be squeezed into perfs and -1.5 bbls of cement remains in 3.5" liner across perfs that were squeezed. However, 23 bbls of Diesel is in the Tubing and no Diesel is yet in the IA, so we need to get Diesel in IA by performing step j to complete freeze protection. j) Slightly open IA to take returns from IA on choke while bringing up the pump to pump another 19 bbls of Diesel down the Tubing. Pump at slow rate to hold tubing & IA pressure constant to SD pressure on tubing (as in step 'i' above). Objective is to get Diesel FP needed into well while holding squeeze pressure on the cement job constant, so that we don't over -displace the cement job or allow it to flow back up wellbore. Keep cement job stationary as possible until it sets up. After the additional 19 bbls of Diesel has been pumped away, k) Shutdown pumping and close IA & tubing to trap the final squeeze pressure on the well. Do not bleed off final pressure from well. Jumper tubing to IA to let Diesel FP U-tube and fully equalize from tubing to IA. Allow sufficient time for Diesel FP to equalize between IA and tubing. With U -tubing we also continue fluid flow through circ holes at 3740' RKB to ensure that we remove any cement from the circ holes before it sets. With total of 42 bbls Diesel fully equalized we leave IA & Tbg FP to 2000' TVD. m) Rig Down & MOL. n) WOC at least 24 hours before performing SL work. Slickline / Pumping v Objectives: Tag TOC, State Witnessed CMIT, Combo DDT of Tbg / IA 4. WOC per UCA data (minimum 24 h`rs) before performing tag & CMIT. Z L n <— 4 ttio f-) t GI -c- T'T 5. Notify AOGCC Inspector in advance regarding timing of Cement Plug #1 tag and MIT. 6. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. RU SL. PT equipment as required. 8. Tag TOC in tubing at -3795' RKB. Taq must be AOGCC witnessed. Record results. 9. RU Pumping Unit. PT Surface Equipment as required. 10. Perform AOGCC witnessed CMIT to 1500 psi. Record Results. 11. Perform Combo DDT on Tubing & IA. Record Results. 12. If CMIT or DDT fails, contact John Peirce: (907)-265-6471 office, to discuss possible need to pump another Cement Plug #1 job. 13. If CMIT passed, prepare to perform Cement Plug #2 placement. We first need to verify that we still have ability to circulate through the circ holes in tubing at 3740' RKB at sufficient rates to place a Cement Plug #2. a) Perform step rate circulation test at different circ rates pumping Diesel down tubing while taking returns from IA. Record injection rates & circ pressures. Do not exceed 3 bpm circ rate or 1500 psi max circ pressure during the circulation test. b) Since Diesel was displaced from IA during circ test, jumper Tbg to IA together to let Diesel U-tube in well and fully equalize from tubing to IA. Allow sufficient time for Diesel FP to equalize between IA and tubing. 14. If inadequate circ rates exists for pumping a Cement Plug #2 job, contact John Peirce: (907)-265-6471 office, to discuss where to shoot new circ holes in tubing. 15. RD & MOL. Fullbore Cement P&A - Cement Plug #2: Objective: Fullbore cement down Tubing and up IA to cement fill tubing and IA to surface. 2.992" ID Tubing and Liner 4.950" ID Csg x 3.5" OD Tbg (IA) Volumes to fill with Cement: In 3.5" Tbg & 3.5" Liner In 4.950" ID Csg x 3.5" OD Tbg (IA) Plus —10% excess Total 15.8 ppg Class 'G' Cement = 0.0087 bbl/ft = 0.0119 bbl/ft _ (3795'- 0')(0.0087) = 33.0 bbls _ (3763' - 0')(0.0119) = 44.8 bbls = 7.2 bbls = 85.0 bbls Only pump 15.8 ppg Class 'G' Cement. The tubing restriction at —365' RKB creates an unacceptable risk in trying to attempt a Cement Plug #3 ArcticSet job across the permafrost, so we will not be performing a Cement Plug #3. 16. Verify with John Peirce, 265-6471 office, 240-5533 cell, that circulation testing results (per step 13a) look good to perform a P&A before starting work on a cement job. 17. Schedule pilot testing of P&A cement design. The cement job requires 85 bbls of pumpable 15.8 ppg Class 'G' Cement. 18. MIRU Cement Van. Conduct PJSM. 19. Inspect wellhead and location for pre-existing conditions. Mitigate hazards. Establish site control. Ensure hardline is rigged up to pump down tubing and to take returns to tanks from IA. Ensure full opening returns from 2" hardline. Prepare for fluids and cement to exit a downspout on wellhead into drum and have a Vac truck on location to manage fluids. Tie in cement wash up lines, and isolation valves that will allow for surface lines to be flushed when cement is seen to surface. 20. Mitigate personnel exposure for PT and then PT equipment as needed. 21. Circulate 120 bbls (-1.5 wellbore volumes) of Lead Freshwater down tubing through tubing punches and up IA to return tanks at max rate up to 3 bpm or 1500 psi max circ pressure to begin pumping. This pumping displaces all Diesel (contaminant to cement) from wellbore to tanks. When it is verified that good return rates ; Lead Freshwater pumping, start mixing 85 while pumping away the Freshwater stage. re being observed from IA to tanks during bbls of 'pumpable' 15.8 ppg Cl 'G' Cement After Freshwater stage is pumped away, be ready to swap to fullbore pumping Cement down tubing. 22. Pump 85 bbls of 15.8 ppg Class 'G' Cement down tubing and up IA at rate of at least 1 bpm to provide good sweep, until cement arrives back to surface from IA, which should begin to occur at 77.8 bbls of cement is pumped away (assuming no cement losses are occurring to formation). 23. Monitor returns on surface and take samples to check pH and density. Once good cement returns are verified on surface using mud scale for cement density measurements, shut down pumping and open up surface bypass line to flush all lines with water from Freshwater transport. 24. Wash up cement pumps. 25. RDMO. 26. WOC 48 hrs. � � ql ,7. Notify AOGCC at lest 24 hrs befo the MIT's to be p�rformed below. i Pumping: 2 . Proceed after equired ela sed WOC and if GCC Rep i resent to witn/r T's. 9. RU LRS & T equipme t. 30. MIT -T with Dies o 1500 psi. Rec results. 31. MIT -IA h Diesel to 15 psi. Record results. 7- L_ 32 IT -OA with Di el to 1500 psi. Record results. 33. Perform drawdown test on tubing, IA, and OA. Proceed to Wellhead Excavation and Final P&A work steps below. Wellhead Excavation / Final P&A: 34. Remove Well House if still installed. 35. Bleed off T/I/O to ensure all pressure is bled off the system. 36. Remove production tree, in preparation for excavation and casing cut 37. If shallow thaw conditions are found, have shoring box installed during the excavation activity to prevent lose ground from falling into the excavation. 38. Cut off wellhead and all casing strings at 4 feet below original ground level. 39. Perform Top Job and verify that cement is at surface in all strings. AOGCC witness and photo document required. 40. Send the casing head w/ stub to materials shop. Photo document. 41. Weld %" thick cover plate (16" OD) over all casing strings with the following informat+oh bead welded into the top. Photo document. AOGCC Witness Required. ConocoPhillips KRU 1D-120 PTD #: 197-221 API #: 50-029-22835-00 42. Remove Cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 43. Obtain site clearance approval from AOGCC. RDMO. 44. 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. 2 Loepp, Victoria T (CED) From: Peirce, John W <John.W.Peirce@conocophillips.com> Sent: Wednesday, May 22, 2019 7:29 AM To: Loepp, Victoria T (CED) Subject: RE: [EXTERNAL]KRU 1 D-120 (PTD 197-221, Sundry 319-229) Plug and Abandon Victoria, We plan to pump 1D-120 P&A job such that we should still be able to tag Cement Plug #1 below the tubing restriction, but there is some possibility that after pumping Cement Plug #1 through the tubing restriction that we may not be able to get back down the tubing to tag the top of it. Pumping cement through the restricted tubing may result in lower likelihood that we will still be able to get back down through the restriction. If we can't tag Cement Plug #1, we could perform a CMIT. If a CMIT passes and we can still circulate down tubing and up IA through circ holes at bottom of the IA, that would indicate we have a good Cement Plug #1 across the perfs and remaining ability to circulate Cement Plug # 2 down tubing and up IA. A worst case scenario possible may be that we can't tag or circulate because the tubing restriction becomes more restricted or cemented off due to pumping Cement Plug #1. The circ holes may also become cemented off as a result of pumping Cement Plug #1, but we believe we can mitigate that possibility. Good job execution will be critical, but there are issues that can still potentially occur as a result of pumping the job as proposed. Because there are potential issues that may arise by pumping Cement Plug #1 followed by Cement Plug #2, 1 had initially thought we would be better off just pumping a ^2 bbl sand plug to isolate the open D sand perfs and partly covered B sand perfs, and then capping the sand plug with an impermeable Calcium Carbonate Cap, followed by CMIT. If CMIT passes, then we would just pump a single stage cement job down the tubing and up IA to surface to get the P&A cementing work completed while we know we have the tubing restriction open and our circ holes open. I still like a single stage cement approach given the condition of the tubing. However, there is a risk that if we were to pump a sand plug down the tubing that it may bridge off at the tubing restriction. If we choose the two cement stage approach to get the P&A done, I think we add some risks and complications that may arise in completing 1D-120 P&A, but we probably still have risks with a single stage cement job P&A option as well. The proposed drop of the 'foam ball' behind the Cement Plug #1 that I proposed in my procedure may be better to omit from my procedure, because it is difficult to shut down momentarily to get the ball away, which results in the ball not dropped exactly at the tail of the cement stage. We don't want the ball arriving late or having it potential shredded or lodged in the restricted tubing area. We're still thinking over pros and cons regarding a foam ball drop. John Peirce Sr Wells Engr CPAI Drilling & Wells (907)-265-6471 office From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Tuesday, May 21, 2019 8:27 AM To: Peirce, John W <John.W.Peirce@conocophillips.com> Subject: [EXTERNAL]KRU 1D-120 (PTD 197-221, Sundry 319-229) Plug and Abandon John, With the tubing restriction, will it be possible to slick line tag the cement plug #1? 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. LoeooCa)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 Vicio(ia.Loeipo@alaska.gov L�,app Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Thursday, May 9, 2019 1:54 PM To: Peirce, John W Cc: Roby, David S (DOA) Subject: KRU 1 D-120 (PTD 197-221, Sundry 319-229) P&A Hi John, The State witnessed MITs as outlined in steps 27 through 32 are not required and will be deleted from your procedure before approval. 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 LoeppOlalaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without Tint 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.Qoy From: Peirce, John W <John.W.Peirce@conocophillips.com> Sent: Wednesday, May 8, 2019 3:47 PM To: Roby, David S (DOA) <dave.roby@alaska.gov> Cc: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]Sundry application for KRU 1D-120 (PTD 197-221) Dave, OK, thanks. Our Slope staff that does the work explained tome today that doing the MIT's per work steps 27, 28, 29, 30, 31, and 32 of my proposed procedure were not required by AOGCC and we would probably just create a spill anyway using Diesel trying to do the MIT's on the surface plug. John Peirce Sr Wells Engr CPAI Drilling & Wells (907)-265-6471 office From: Roby, David S (DOA) <dave.robv@alaska.aov> Sent: Wednesday, May 8, 2019 3:38 PM To: Loepp, Victoria T (DOA) <victoria.loeoo@alaska.aov> Cc: Peirce, John W <John.W.Peirce conocophillips.com> Subject: FW: [EXTERNAL]Sundry application for KRU 1D-120 (PTD 197-221) John, I just review the reservoir engineering impacts of proposed work, the actually work procedures are reviewed by Victoria Loepp, the AOGCC drilling engineer assigned to review CP's work. So I'm passing this along to her for her consideration. Thanks, Dave Roby 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.robv@alaska.zov. From: Peirce, John W <John.W.Peirce @conocophillips.com> Sent: Wednesday, May 8, 2019 3:32 PM To: Roby, David S (DOA) <dave.roby@alaska.gov> Subject: RE: [EXTERNAL]Sundry application for KRU 1D-120 (PTD 197-221) David, I would like to revise the proposed 113-120 P&A Procedure to remove work steps 27, 28, 29, 30, 31, and 32 of the procedure that I sent over for approval. The revised procedure would look like the revised procedure (attached). Is this OK with you? I'm told today from our Slope staff that AOGCC has only requested that we do a DTT on Tubing and IA in the past on similar P&A's. This is still in the revised procedure attached as work step 27. Regards, John Peirce Sr Wells Engr CPA[ Drilling & Wells (907)-265-6471 office From: Roby, David S (DOA) <dave.roby@alaska.gov> Sent: Wednesday, May 8, 2019 2:57 PM To: Peirce, John W <John W Peirce@conocophillips.com> Subject: RE: [EXTERNAL]Sundry application for KRU 1D-120 (PTD 197-221) Hi John, Thanks for the response, this resolves my questions/concerns. Regards, Dave Roby 907-793-1232 Roby David S (DOA) From: Roby, David S (DOA) Sent: Wednesday, May 8, 2019 2:57 PM To: Peirce, John W Subject: RE: [EXTERNAL]Sundry application for KRU 1D-120 (PTD 197-221) Hi John, Thanks for the response, this resolves my questions/concerns. Regards, Dave Roby 907-793-1232 CONF/DEN77ALrrYN077CE: 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 robe alaska.gov. From: Peirce, John W <John.W.Peirce@conocophillips.com> Sent: Wednesday, May 8, 2019 2:52 PM To: Roby, David S (DOA) <dave.roby@alaska.gov> Subject: RE: [EXTERNAL)Sundry application for KRU SD -120 (PTD 197-221) David, I'm sorry for a delayed response, but I wanted to first discuss your questions with Pete Fox to get his input. Pete is the drillsite engineer for 1D-120. Regarding question #1, Pete & I agree that subsidence damage to the single 5.5" casing string is a big concern now. We expect that the 3.5" tubing is directly being impacted by deformed 5.5" casing. Only slim tools were able to drift through for the tubing restriction to punch holes for circulation. Additionally, the GLM below the subsidence damage likely can't be pulled, and a subsidence repair on -rig would be high risk of failure, and challenged with moderate life expectancy at best. Delay in performing the current non -rig P&A could easily result in additional complexity and risk with minimal positive benefit, if any. Regarding question #2, Pete responded that we are planning to hold a 1D pad development workshop with CTD / Rotary to strategize long term what options we should pursue to maximize our pad production to EOFL. Broadly speaking, 1D pad has been fairly well supported from an injected volume to produced volume ratio perspective. But more details need to be analyzed to provide a longer term strategy portfolio of options to select from. Please contact me if you have any other questions. Thanks, John Peirce Sr Wells Engr CPA] Drilling & Wells (907)-265-6471 office From: Roby, David S (DOA) <dave.robv@alaska.eov> Sent: Tuesday, May 7, 2019 11:15 AM To: Peirce, John W <John.W.Peirce@conocophillips.com> Cc: Loepp, Victoria T (DOA) <victoria.loepp@alaska.aov>; Wallace, Chris D (DOA) <chris.wallace@alaska.F;ov>; Davies, Stephen F (DOA) <steve.davies@alaska.aov>; Boyer, David L (DOA) <david. boyer2@alaska.eov> Subject: [EXTERNAL]Sundry application for KRU 1D-120 (PTD 197-221) Hi John, I'm reviewing the above referenced sundry application and have a couple of questions. 1) Why is this well being proposed for P&A instead of pulling and replacing the tubing? 2) Will losing this injector impact recovery in this portion of the pool? Thank you, David Roby Senior Reservoir Engineer Alaska Oil and Gas Conservation Commission 907-793-1232 CONFIDEN77ALITYNOTICEE 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.robv@alaska.eov. CONOCOPHILLIPS ALASKA, INC., KUPARUK RIV U WSAK 1D-120 (197-221; KUPARUK RIVER, WEST SAK OIL Monthly Injection Rates 1,000,000 LL u 10,000 V 1,000 d 3 u v c m v, 3 O L 100 F Cum. Inj Gas (mcf): 0--- - - - Cum. Inj Liquid (bbls): 2,513,071 —_ —. 10 ! Jan -1995 Jan -2000 Jan -2005 Jan -2010 Jan -2015 • Injected Gas (MCFM) • Injected Water (BOPM) Jan -2020 1,000,000 100,000 W d m 10,000 ly K A Z m I Z 1,000 03 7 .r 7 100 —i 10 Jan -2025 SPREADSHEET _1972210_KRU_1D-120_Prod-Inject_Cuwes_W ell_Oil_V 120_20190507.xlsx 5/7/2019 P T',D / 17- -- Z 2 J Loepp, Victoria T (DOA) From: Peirce, John W <John.W.Peirce@conocophillips.com> Sent: Monday, May 13, 2019 7:10 AM To: Loepp, Victoria T (DOA) Subject: RE: [EXTERNAL]KRU 1 D-120 (PTD 197-221, Sundry 319-229) P&A Follow Up Flag: Follow up Flag Status: Flagged Victoria, Sounds good. Thanks, John Peirce Sr Wells Engr CPAI Drilling & Wells (907)-265-6471 office From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Thursday, May 9, 2019 1:54 PM To: Peirce, John W<John.W.Peirce @conocophilIips.com> Cc: Roby, David S (DOA) <dave.roby@alaska.gov> Subject: [EXTERNAL]KRU 1D-120 (PTD 197-221, Sundry 319-229) P&A Hi John, The State witnessed MITs as outlined in steps 27 through 32 are not required and will be deleted from your procedure before approval. 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. LoeppOalaska.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 if to you, contact Victoria Loepp at (907)793-1247 or Victoria Loeoo@alaska aov From: Peirce, John W <John W Peirce conocoohill igs.com> Sent: Wednesday, May 8, 2019 3:47 PM To: Roby, David S (DOA) <dave.roby@alaska.aov> Cc: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]Sundry application for KRU 1D-120 (PTD 197-221) Dave, OK, thanks. Our Slope staff that does the work explained tome today that doing the MIT's per work steps 27, 28, 29, 30, 31, and 32 of my proposed procedure were not required by AOGCC and we would probably just create a spill anyway using Diesel trying to do the MIT's on the surface plug. John Peirce Sr Wells Engr CPAI Drilling & Wells (907)-265-6471 office From: Roby, David S (DOA) <dave.roby@alaska.Rov> Sent: Wednesday, May 8, 2019 3:38 PM To: Loepp, Victoria T (DOA) <yictoria.loepp@alaska.¢ov> Cc: Peirce, John W <John.W.Peirce@conocophillips.com> Subject: FW: [EXTERNAL]Sundry application for KRU 1D-120 (PTD 197-221) John, 1 just review the reservoir engineering impacts of proposed work, the actually work procedures are reviewed by Victoria Loepp, the AOGCC drilling engineer assigned to review CP's work. So I'm passing this along to her for her consideration. Thanks, Dave Roby 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.robv@alaska.gov. From: Peirce, John W <John.W.Peirce@conocophillips.com> Sent: Wednesday, May 8, 2019 3:32 PM To: Roby, David S (DOA) <dave.robv@alaska.aov> Subject: RE: [EXTERNAL]Sundry application for KRU 1D-120 (PTD 197-221) David, I would like to revise the proposed 1D-120 P&A Procedure to remove work steps 27, 28, 29, 30, 31, and 32 of the procedure that I sent over for approval. The revised procedure would look like the revised procedure (attached). Is this OK with you? I'm told today from our Slope staff that AOGCC has only requested that we do a DTT on Tubing and IA in the past on similar P&A's. This is still in the revised procedure attached as work step 27. Regards, John Peirce Sr Wells Engr CPAI Drilling & Wells (907)-265-6471 office From: Roby, David S (DOA) <dave.roby@alaska.gov> Sent: Wednesday, May 8, 2019 2:57 PM To: Peirce, John W <John.W.Peirce @conocophillips.com> Subject: RE: [EXTERNAL]Sundry application for KRU 1D-120 (PTD 197-221) Hi John, Thanks for the response, this resolves my questions/concerns. Regards, Dave Roby 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.robv@alaska.eov. From: Peirce, John W <John.W.Peirce @conocophiIli ps.com> Sent: Wednesday, May 8, 2019 2:52 PM To: Roby, David S (DOA) <dave.roby@alaska.gov> Subject: RE: [EXTERNAL]Sundry application for KRU 1D-120 (PTD 197-221) David, I'm sorry for a delayed response, but I wanted to first discuss your questions with Pete Fox to get his input. Pete is the drillsite engineer for 1D-120. Regarding question #1, Pete & I agree that subsidence damage to the single 5.5" casing string is a big concern now. We expect that the 3.5" tubing is directly being impacted by deformed 5.5" casing. Only slim tools were able to drift through for the tubing restriction to punch holes for circulation. Additionally, the GLM below the subsidence damage likely can't be pulled, and a subsidence repair on -rig would be high risk of failure, and challenged with moderate life expectancy at best. Delay in performing the current non -rig P&A could easily result in additional complexity and risk with minimal positive benefit, if any. Regarding question #2, Pete responded that we are planning to hold a 1D pad development workshop with CTD / Rotary to strategize long term what options we should pursue to maximize our pad production to EOFL. Broadly speaking, 1D pad has been fairly well supported from an injected volume to produced volume ratio perspective. But more details need to be analyzed to provide a longer term strategy portfolio of options to select from. Please contact me if you have any other questions. Thanks, John Peirce Sr Wells Engr CPAI Drilling & Wells (907)-265-6471 office From: Roby, David S (DOA) <dave.robv@alaska.aov> Sent: Tuesday, May 7, 2019 11:15 AM To: Peirce, John W <John.W.Peirce@conocophillips.com> Cc: Loepp, Victoria T (DOA) <victoria.loepp@alaska.laov>; Wallace, Chris D (DOA) <chris.waIlace@alaska.eov>; Davies, Stephen F (DOA) <steve.davies@alaska.eov>; Boyer, David L (DOA) <david.boyer2@alaska.eov> Subject: [EXTERNAL]Sundry application for KRU 1D-120 (PTD 197-221) Hi John, I'm reviewing the above referenced sundry application and have a couple of questions. 1) Why is this well being proposed for P&A instead of pulling and replacing the tubing? 2) Will losing this injector impact recovery in this portion of the pool? Thank you, David Roby Senior 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.robv@alaska.¢ov. 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 19722' TRANSMITTAL DATE: TRANSMITTAL #: FIELD .® BP North Slope EOA, PBOC, PRB-20 (Office 109) D&C Wells Project Aids 900 E. Benson Blbd. - Anchorage, AK 0 1 0 1 0 Conoco Phillips Alaska Inc. Ik� _Ay O 6 'L13 11 L 1 0 0 Attn: NSK-69 /±GG 700 G Street pkoG Anchorage, Alaska 99501 AOGCC 0 0 1 ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501-3539 DNR 0 0 1 Attn: Garrett Brown -Geologist I DNR, Division of Oil & Gas 550 West 7th Ave, Suite #1100 - Anchorage, AK 99501 Date Please return via e-mail a copy to both Alaska E -Line Services and Woco Phillips Alaska: MEMORANDUM TO: Jim Regg P.I. Supervisor ~ ,. 7j2~ ll G, FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, July 22, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1D-120 KUPARUK RIV U WSAK 1D-120 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Comm Well Name: KUPARUK RIV U WSAK 1D-120 Insp Num: mitRCN100718141806 Rel Insp Num: API Well Number: 50-029-2283s-00-00 Permit Number: 197-221-0 Inspector Name: Bob Noble Inspection Date: 7/16/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1D-I2o Type Inj. N TVD 3590 IA 20 1760 1720 1700 P.T.D 197221° ' TypeTest SPT i Test psi 1760 OA -~ - Interval aYRTST p/p' P ~ Tubing sso sso s6o 560 I Notes: ~jvt, r~~ ~~ ~fi r ~'~~ ` ra ~~~ t ~ .. Thursday, July 22, 2010 Page 1 of 1 04/30/09 ~~~~ NO. 5203 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth b'{, l~~N Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnkerl 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD 3F-03 ANHY-00070 INJECT 2D-03 ANHY-00075 ION PROFILE - ~ PRODUC 04/04/09 1 1 1 E-29 B04C-00030 TION PROFILE '" PRODUC 04/10/09 1 1 3G-13 3F-18 1D-117 ANHY-00079 604C-00031 614B-00027 TION PROFILE l 9 INJECTION PROFILE _ t/ PRODUCTION PROFILE 1 - INJECTIO 04/14/09 04/15/09 04/15/09 1 1 1 1 1 1 1 D-128 AYS4-00057 N PROFILE ~ . ~}_ INJECTION PRO 04/16/09 1 1 iH-21 1 D-120 2K-22 1E-15 8146-00028 AYS4-00058 AYS4-00059 AYS4-00061 FILE PRODUCTION PROFILE L INJECTION PROFILE IBP/SBHP - INJECTION P ' 04/16/09 04/17/09 04/17/09 04/18/09 1 1 1 i 1 1 1 i 1Y-04 AYS4-00071 ROFILE _. - INJECTION PRO 04/20/09 1 1 3F-02 iG-04 AYS4-00063 B14B-00036 FILE PRODUCTION PROFILE c _ SBHP SURVEY ' ° 04/28/09 04/22/09 1 1 1 1 i R-03A AYS4-00063 ~, L ~( SBHP SURV 04/23/09 1 1 iG-06 EY , S -1_ (` ~~,(b _ (,~~~ ~ • 9y(o 04/23/09 1 1 B14B-00035 SBHP SURVEY ~~ (~~ _~~~ Q°~-~~~~ 04/23/09 iR-10 B14B-00031 S - 1 1 2F-02 i R-15 AYS4-00060 6148-00032 BHP SURVEY - (~ c - INJECTION PROFILE J C - )~ I GI SBHP SU '" 04/20/09 04/19/09 1 1 1 1 RVEY. - ~ ~ ~. 04/20/09 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . ~/ ConocoPhillips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 29, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 sCANNED JAN 1 6 2007 Anchorage, AK 99501 \l\1-~~1 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids were first filled with cement to a level of approximately 1.0 foot. The remaining volume of annular void respectively was coated with a corrosion inhibiter, RG2401 that was engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top-fill operation was completed on December 16, 2006 and the sealant top was completed on December 27,2006 for IH-Pad and December 28, 2006 for ID-Pad. Schlumberger Well Services mixed 15.7 ppg Expando cement in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The 2401 sealant was pumped in a similar manner. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call myself or M.l. Loveland at 907-659-7043, if you have any questions. Sincerely, ~--/cD~ Jerry Dethlefs ConocoPhillips Problem \tVells Supervisor " . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement and Sealant Top-off Kuparuk Field 12/29/2006 Initial Top Cement Final Top Sealant Well Name PTD# of Cement Volume of Cement Cement Volume Sealant Feet Barrels Feet Date Gallons Date 1 H-01 193-006 12" na 12" na 7.4 12/27/2006 1 H-02 193-008 21' 4" 2.9 14'6" 12/16/2006 na na 1H-10 193-030 4' na 4' na 29 12/27/2006 1 H-11 193-036 Surface na Surface na 1 12/28/2006 1 H-12 193-044 4'8" 0.6 8" 12/16/2006 4.98 12/27/2006 1 H-13 193-049 6' 0.8 4' 12/16/2006 29 12/27/2006 1 H-14 193-052 35' 4.7 12" 12/16/2006 7.4 12/27/2006 1 H-18 193-020 14'4" 2.7 12" 12/16/2006 7.4 12/27/2006 1 H-21 193-046 4" na 4" na 2.4 12/27/2006 1 H-401 198-101 45' 4.4 18" 12/16/2006 20.1 12/27/2006 10-109 197-235 10'9" 2.1 12" 12/16/2006 10.8 12/28/2006 1 0-11 0 200-039 8'6" 1.4 10" 12/16/2006 9 12/28/2006 10-111 198-166 17' 7" 3.4 25" 12/16/2006 21 12/28/2006 10-120 197-221 13' 6" 2.9 18" 12/16/2006 16 12/28/2006 10-121 197-181 13' 2.2 20" 12/16/2006 16.2 12/28/2006 1 0-132 198-121 10'8" 2.0 14" 12/16/2006 11 12/28/2006 1 0-133 197 -206 6' 1.0 6" 12/16/2006 4.6 12/28/2006 1 0-136 200-046 10' 2" 2.0 10" 12/16/2006 6.4 12/28/2006 10-137 200-047 11 ' 2.00 24" 12/16/2006 13.2 12/28/2006 1 0-138 200-048 11' 7" 2.3 4'6" 12/16/2006 29.7 12/28/2006 1 0-139 200-049 11'2" 2.2 18" 12/16/2006 9.9 12/28/2006 1 0-140 200-136 29'9" 3.4 12" 12/16/2006 na na 11/21/06 ScbllllRbepgep NO. 4049 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Ï\ (1J I) ~(~ Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 UTC '1 0---=t- ~8d-1 Field: Kuparuk Well Log Description Date Color CD BL Job# 2U-09 11416231 SBHP SURVEY 10/29/06 1 3J-18 11483494 GlS 11/13/06 1 3J-13 11483495 INJECTION PROFILE 11/14/06 1 1 R-07 11486070 SBHP SURVEY 11/11/06 1 2X-17 . 11486068 PRODUCTION PROFilE 11/09/06 1 1 D-36 . 11486077 SBHP SURVEY 11/19/06 1 1D-120 ' 11486073 INJECTION PROFILE 11/14/06 1 1R-35 ' 11486074 PROD PROFilE-INCOMPLETE OPERATION 11/15/06 1 t' Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. o /,lL-- . . e e «MIT KRU 1D 10-22-06.xls» «MIT KRU 1J 10-22-06.xls» All, Enclosed are the state witnessed MITrA data for the two recent surface casing repairs 1 D-1 09, & ({ 10-120 and the initial MITIA post conversion of 1J-127, 1J-156, and 1J-170. \<\ ~ -d-d-\ One thing to note regarding the 1 J data is that all three wells are currently on a vacuum thus the tubing pressure is listed as zero. If you have any questions let me know Perry Klein Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 n1617@conocophillips.com f\ t~' 'ìnnQ t) f: (,,}¡,; -<;.. ,-:J MIT KRU ID Content-Description: MIT KRU ID lO-22-06.xls Content-Type: applicationlvnd.ms-excel Content-Encoding: base64 KRU IJ Content-Description: MIT KRU 11 lO-22-06.xls Content-Type: applicationlvnd.ms-excel Content-Encoding: base64 1 of 1 10/30/20069:14 AM e e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk I KRU /10 10/22/06 Greenwood / Noble Jeff Jones ; d--~ \ .:) \q1~Jv.;\6ß / Packer Depth Pretest Initial 15 Min. 30 Min. Well 1D-109 I Type Inj. I W TVD I 3,550' Tubing 1000 950 950 950 Interval I 0 P.T.D./1972350 I Type test I P Test psi! 1500 Casing 750 1900 1875 1875 P/FI P Notes: Post csg repair under sundry approval 306-094 OA NA NA NA NA Well/1D-120 I Type Inj. I W TVD I 3,591' Tubing 925 925 925 925 Interval 0 P.T.D. /1972210 I Type test I P Test psi! 1500 Casing 0 2240 2155 2150 P/F P Notes: Post csg repair under sundry approval 305-227 OA NA NA NA NA Weld I Type Inj. I TVD I Tubing Interval P.TD.I I Type test I Test psil Casing P/FI Notes: OA Weill I Type Inj. I TVD I Tubing Interval I p.T.D.1 I Type test I Test psi/ Casing P/FI Notes: OA Weill I Type Inj. I TVD I Tubing Interval p.T.D.1 I Type test I Test psi! Casing P/FI Notes: OA Weill I Type Inj. I TVD I Tubing Interval I p.T.D.1 I Type test I Test psi! Casing P/FI Notes: OA Weill I Type Inj. I TVD I Tubing Interval p.T.D.1 I Type test I Test psi! Casing P/F/ Notes: OA Weill I Type Inj. I TVD I Tubing Interval I P.T.D.I I Type test I Test psi! Casing P/FI Notes: OA Weill I Type Inj. I TVD I Tubing Interval P.T.D.I I Type test I Test psi I Casing P/F Notes: OA D = Drilling Waste G=Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) MIT KRU 10 10-22-06.xls . Conoc~illips Alaska . P.O. BOX 100360 ANCHORAGE, ALA5KA 99510-0360 September 28, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 '--"ç~.t:. r,,!, . n" ,. \'~ I. "\"'~c"~\~¡Fil,',!c, :u .. "'iJ-ii.i·\i~i,.;.;.-i " C' t ~ // ~.. ,-:; Dear Mr. Maunder: Enclosed please find 10-4 4 Re ort of Sundry Well Operatiòns for ConocoPhillips Alaska, Inc. wells D-120 PTD 197-221) and 1D-121 (PTD 197-181). The reports record the completion of the surface casing excavation, inspection, and repair on each well. Also included are two paper copies of the previously faxed 10-403 application for Sundry Approval to add a ~4' extension on the conductor ofwell1D-133 (PTD 197-206). Please call Jerry Dethlefs or me at 659-7043 or Marie McConnell or Perry Klein at 659- 7224 if you have any questions. / /' Since:;", /,' /,~, ß / / / /;7~ ?~c..- / i MJ LÓveland Problem Well Supervisor Attachments Il1't - 8'd \ 1. Operations Performed: Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 112' 8. Property Designation: Kuparuk River Unit tf Þ l 2~ thO 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SUR CASING SUR CASING Perforation depth: . RECEIVED . OCT 0 2 2006 STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Alaska Oil & Gas Cons. ClHT1missior Repair Well 0' Pull Tubing 0 Ope rat. ShutdownD Other o o o Stimulate 0 Waiver 0 Plug Perforations 0 Perforate New Pool 0 Perforate 0 4. Current Well Status: Development 0 Stratigraphic 0 Time Extension Re-enter Suspended Well Exploratory Service o 0' 5. Permit to Drill Number: 197-221 . 6. API Number: 50-029-22835-00 . 9. Well Name and Number: 10-120 b'~'Ø" 10. Field/Pool(s): Kuparuk River Field 1 West Sak Oil Pool measured 4530' feet true vertical 4315' feet measured feet true vertical 6276' feet Length Size MD 121' 16" 121' 3653' 5-1/2" 3765' 745' 3-1/2" 4510' Plugs (measured) Junk (measured) Burst Collapse TVD Measured depth: 3866-3898,3934-3970,3981-4001,4068-4081 true vertical depth: 3908-3916,3925-3953,3983-3997 Tubing (size, grade, and measured depth) 3-1/2" , L-80, 3765' MD. Packers & SSSV (type & measured depth) Baker GBH-22 3764' no SSSV no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) 13. Treatment descriptions including volumes used and final pressure: NIA Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casin Pressure Tubin Pressure NA NA NA NA NA 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: OilO GasD WAG 0 GINJ 0 WINJ 0 · WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Signature Sundry Number or N/A it C.O. Exempt: 305-227 Problem Wells Supervisor 907-659-7224 Date ORIGINAL RBDMS 8Ft OCT 0 ,1 ZO~Ö(~Subm~~~~~·o," ~(~/C6 . 1 D-120 DESCRIPTION OF WORK COMPLETED SUMMARY . Date Event Summary 9/8/2006 Conductor Removal, Inspect SC. Rigged up WACHS window cutter & cut 24" X 18" window in conductor @ 7' 6" down from top of mandrel hanger. Cut off conductor 13' 6" below top of mandrel hanger. Remove the 13' 6" section of the conductor, chipped away rotten cement and found heavily corroded Suface casing with multiple holes (3). Total conductor removed= 13' 6", Holes located down from top of conductor 7'3",7'9" & 8' v 9/9/2006 Removed additional 24"section of conductor, revealing what apears to be good pipe. Waiting on UT. T/I= SilO. 9/10/2006 Called (left message)and Notified AOGCC state inspector on 9/10/06 @ 5:30 p.m. that the Conductor was removed from 10-120 and that there was at least a 3-4 day window that he may come over and witness the production casing damage 9/11/2006 Called AOGCC state inspector (John Spaulding) @ 4:55 p.m. and notified him again about the Visual inspection he said that he mayor may not be over to witness. 9/17/2006 Weld SC patch, Drilled 3/4" hole in existing hole in IA and vac'd out to 3' below wedding band weld. Purge N2 and assist welders during SC patch weld. patch 13' long. MITIA - passed. (Post SC patch), T/I = 0/0. Re-installed VR plug in IA. Pressuered up IA to 3000 psi with 1 bbl diesel, no visable leaks, started MITIA, T/I = 0/3000, 15 min T/I = 0/2900, 30 min T/I = 0/2880, 45 min T/I = 0/2880, 60 min T/I = 0/2880. Bled IA to 0 psi. Final T/I = 9/18/2006 0/0 Weld Conductor Sleeves. welded 14' 11" piece of 16" H-40 pipe with machined groove for 9/19/2006 conductor. Reinstallation has cement circ port for future cementing and sealant. e e WELL LOG TRANSMITTAL PROAcDVE DiAqNOSDC SERvicES, INC. To: AOGCC. Attn: Ceresa Tolley 333 West 7th Avenue Suite 1 00 Anchorage. Alaska 99501-3539 RE: Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection[Caliper / MTT] The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to : ProActive Diagnositc Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 - 8952 1 ] 2] 3] 4J 5] 6] l q 7 - 2;t I 7] 8] Signed: Print Name: 1C-119 MTT Report 1C - 121 MTT Report 1C - 131 MTT Report 1 D - 1 27 MTT Report 1 D - 121 MTT Report 1 D - 1 09 MTT Report 1 D - 120 MTT Report 16-May-06 16-May-06 14-Jun-06 14-Jun-06 14-Jun-06 S:CJ\N:~fC) Jt) ~).i 15-Jun-06 15-Jun-06 1 D - 111 MTT Report 15-Jun-06 ~ öU Date: it Jut; ~~ ~ µ Ò I..U ""iI'À~ 0 k l Cl-"",,¿" PRoAcTivE DiAGNOSTic SERVicES, INC., I}O W. INTERNATioNAl AiRpoRT Rd SUiTE C, ANclfORAGE, AK 99 ~ 18 PIfONE: (907)24~~89~ 1 FAX: (907)24~~89~2 E-MAil: pdS.,,¡\ld1ORMie@MEMO!tv10f¡.COM WEbsiTE: MEMoRyloG.coM c:iMy Documentsl W ork\ DistributionLablesNewl Transrnit_ Original. doc I I I I I I I I I I I I I I I I I I I Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: Pipe2 Desc.: Pipe2 Use: Pipe3 Desc.: Pipe3 Use: e e Memory Magnetic Thickness Tool Log Results Summary 1/Î-'r' \~ ConocoPhillips Alaska, Inc. June 15, 2006 8035 2 3.5" 9.3 Ib EUE Tubing 5.5" 15.5 Ib Production Casing 16" 62.6 lb. Conductor Pipe Well: 1D-120 Field: Kuparuk State: Alaska API No.: 50-029-22835-00 Top Log Intvl.: Surface Bot. Log Intvl.: 196 Ft. (MD) Top Log Intvl.: Surface Bot. Log Intvl.: 196 Ft. (MD) Top Log Intvl.: Surface Bot. Log Intvl.: 121 Ft. (MD) Inspection Type: Assess External Co"osive Damage (Metal Loss) to Production Casing. COMMENTS: This MTT data is tied into the Tubing Hanger @ 0' Depth. This is the first log of this well with the 12 Arm Magnetic Thickness Tool (MTT). The Magnetic Thickness Tool responds to the total thickness of metal of the 3.5" tubing, 5.5" production casing, and 16" conductor pipe within the logged interval. Due to the concentric pipe strings in the log interval, the MTT response is qualitative - indicating an overall increase or decrease in metal surrounding the tool, but not distinguishing in which pipe string the change in metal thickness occurs. In this log, the MTT was calibrated down hole (60'), where the readings are assumed to represent undamaged tubing, casing and conductor pipe. All other readings are relative to this reference point, which include influences from the 3.5"" tubing, 5.5" casing, and 16" conductor pipe. INTERPRETATION OF MTT LOG RE5UL T5 : The MTT log results cover the interval 0' - 196'. A log plot of the entire log interval, plus detailed sections of intervals showing metal loss are included in this report. The Delta Metal Loss (%) curve in these plots refers to total metal surrounding the MTT tool and the results show two intervals of metal loss. A maximum of (-15%) circumferencial metal loss is recorded in the interval between 19' and 29'. A maximum of (-13%) circumferencial metal loss is recorded in the interval between 3' and 11'. The percent circumferencial metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which may include influences from the 3.5",5.5" and 16" pipe. If all of the metal loss is specific to the 5.5" production casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. Some of the metal loss indicated could be from either the 3.5" tubing or 16" conductor. Analyst: M. Tahtouh & J. Burton Witness: T. Sendon PmActive Diagnostic Services, 1nc. Phone: (281) or (888) 565-9085 Fax: Prudhoe Bay Fie!d Office Phone: p.o. Box 1369f Stafford, TX 77497 565-1369 [-mail: PDS@memoryìog.com 659-2307 Fax: 659-2314 I Field Engineer: R. Richey & N. Kesseru I I I I I I I I I I I I I I I I I I I <Irk MagrJ~tilÞ Thickness Tool (10 Pass) PRoÅcIÍVE DiAq~,.ìc SElitvicESþ IN(;. Database File: d:\warrior\data\1d-120\1 d-120.db Dataset Pathname: KRP/1 d-120/run1 liog1 Ohz.1 Presentation Format: mtt10hz Dataset Creation: Fri Jun 16 13:42:48 2006 by Calc Sondex Warrior V70 Charted by: Depth in Feet scaled 1 :150 -50 De!ta Metal Thickness (%) 50 2.2 MTTP01 (rad) 122 0 Line Speed (ftfmin) -200 -6.6 MTTP12 (rad) 3.4 Tree bing Ha 3.5"Col! Pup Jt. I T 13% Metal Loss- ~ \, , , 3.5" f----.-- ~.- -- r- ¡ t Jt. 1 I--- tr' Line 'fJ'::'.!'?U 20 j ~ - ;£'. ~ ? " { 15% Meta! Loss- I I I T \ - \. I T I - 3.5" Col! J I Pup Jt. ; I f-- I----: 3.5" Colla !----- Pup Jt. 1 4U 1-* 1-.-- "":..5.5" Casing Collar =t ! ~ - ~^^-~-- - ..- ._-~ - 3.5" -L ~ Jt 2 l! iF ;....; - ; -- ~ >-- :;-: 60 - ~ ~ -35"tllaÎ - -.- - -. J- Bottom of 16" Conductor .......... i 80 I :1 I 3.5" I -.,1 '-- 5 5" C . C II Jt. 3 I <.. c.. r-' ., rS1n? ~. ar t ( JI I J 1 IJ i I .1 .t IJ ... I " " ,,- . , I \ 7Ç -- I I I I I I I I I I I I I I I I I I I (" I I I L I(' .;r ) I ! , ~I '\ ~ ~- 100 35" C,ollar ~--- M__~__ - é ..-... ---- -. -- ---~ -- - -- --~ .:: ! '0 ,- -- ---- - -- 3.5" m Jt 4 120 I l -- -~_. J ~ 5" CasIng Colla, I 3. 5" Collar ) ) 140 ! 3_5" Jt 5 I--- =rn , , - -- -- -~ 160 - - h ~ 1 ~ j t:::> > ;= 5.5" Casing Collar p ,"- ):::::::b .;:::::.- ~ I ,ì ¿ ) '7 ) I~ --ç ~ 1 - \ . ,~ 180 "s 0' ill 3.5" I Jt. 6 ': ~,. ; , ;ttm J ')t=~ ¿. ~ ¡¡¡.. :::::Þ- ,.,- :> -50 Delta Metal Thickness (%) 50 2.2 MTTP01 (rad) 12.2 0 Line Speed (ft/min) -200 -6,6 MTTP12 (rad) 3.4 I I I I I I I I I I I I I I I I I I I clrk Detail of Metal Loss Features - PRoAcJíVE DW:¡_Tic !>Emc"", INC. -- Database File: d:\warrior\data\1 d-120\1 d-120.db Dataset Pathname: KRP/1 d-120/run1 IIog1 Ohz.1 Presentation Format mtt10hz Dataset Creation Fri Jun 1613:42:48 2006 by Calc Sondex Warrior V70 Charted by: Depth in Feet scaled 1 :75 -~u uelta Metal Thickness (%) 50 2.2 MTTP01 (rad) 12.2 0 Line Speed (ft/min) -200 -6.6 MTTP12 (rad) 3.4 .. . Tubing Hanger I 0 3.5" Collar Pup Jt Ir t> .... øf ;> = 13% Metal Loss- ... - - ;.. ~ \1 \ \ L "\ ~ ) ~ 1 1 . I I 3.5" Jt 1 I ! II""F'" Line Speea f } 20 .I ~ J J. 1: j j , 1/ ~"x I 1/ - /' ,/ ~l ./' I( ( ( l '> J - 15% Metal Loss- -h -- ~ I I\t P- 51 \1 i ~ I. 1 '\ \ \ \ '~ '\ ) \, . 't \ '«: - '-......... > I \ 3.5" Collar I $'" Pup Jt ~ ~..., .....- -- 4> 3 5" Colla --- Pup Jt. :::::!!!!: . ._~ 40 ¡ . ., II ~ 1 I~~ ..¿; -50 Delta Metal Thickness (%) 50 2.2 MTTP01 (rad) 12.2 0 Line Speed (ft/min) -200 -6.6 MTTP12 (rad) 3.4 ------------------- ______m__________ I I I Gas Lift ,ndrel/Oummy Valve 1 (3673-3674, 00:4.750) I NIPPLE (3725-3726, I 00:3500) TUBING (0·3765, 00:3.500, 10:2.992) I SUR. CASING I (0-3765, J 00:5.500, Wt15.50) SEAL (3764-3765, 00:4.000) I I SUR. CASING (3765-4510, 00:3.500, Wt:9.30) I Perf (3866-3898) I Perf (3934-3970) Date I Perf (3981-4001) I Perf I (4068-4081) I Perf (4100-4109) I Perf (4118-4148) I Perf (4180-4195) I I KRU 1D-120 ttwa: LOnOCOïnllUp:s CXl;(:lV(:lUUll OC l'.t;paU rlVJI;;\.,lj -- ---- Subject: [Fwd: ConocoPhillips Excavation & Repair Project] From: Thomas Maunder <torn _ maunder@admin.state.ak.us> Date: Tue, 20 lun 2006 07:00:24 -0800 [J'ö::.JjouGrimaldi<lou_grimaldi@admin.state.ak.us>, John Spaulding EjohJí_spaulding@admin.state.ak.us>, John Crisp <john_crisp@adlnin.state.ak.us>, Jeff Jones [8èff..jones@admin.state.ak.us>, Chuck Scheve <chuck_scheve@admin~state.ak.us>, Jim Regg <jiîrìi... regg@admin.state.ak.us> All, Enclosed, FYI and scheduling, is a message from Problem Wells regarding the "big dig" project they will be starting soon. Jerry has also included a copy of the SPE paper he/they prepared regarding causes and repairs. Tom -------- Original Message -------- ConocoPhillips Excavation & Repair Project Mon, 19 Jun 2006 14:06:18 -0800 NSK Well Integrity proj <N1878@conocophillips.com> tom maunder@admin.state.ak.us Ñsï{-weiTmlntegrity proj <N1878@conocophillips.com>, aogcc prudhoe bay@admin.state.ak.us "\ \)- \ð-C) \~\-ð-Ò-\ Subject: Date: From: To: CC: SCANNED JUN 2 7 2006 Tom: I don't remember how much of our plans we have shared with you on excavating and repairing wells at lC & ID pads. We have been submitting a lot of 10-403s for the work and there is a reason for that. Starting in the next two weeks we will focus on this project, which is pretty ambitious. The attached spreadsheet lists the wells we intend to excavate. Some of these were determined this last year to have surface casing leaks. Others we have chosen to "pro-actively" excavate and inspect to get a better understanding of the level of damage to be expected for the other single casing wells. At any point in time we will have two wells in progress, and hope to continue for the bulk of the summer. A couple of them we will intentionally target late in the year when the ground has less water encroachment problems. We have submitted Sundry requests for all but one well, three of which are in the mail to you today. Like the others, we expect that you agree inspections and repairs on these wells are important and will approve those as well. As we go through the project we will keep the Inspectors notified of our progress so they can see these casings exposed. However, we will be under a tight timeline and will not hold excavations open longer than is necessary. Hopefully they can arrange to inspect them in the several day period that each of them is exposed. If you have any questions about our project please let us know. The SPE paper we wrote on the subject is a good primer on the mechanism involved. I have attached a copy in case there is interest in your shop. Talk to you soon. «lC and ID Casing Repair List AOGCC.xls» «SPE-I00432-PP SC Corrosion West Region 2006 Final.doc» Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7043 IC and ID Casing Repair List Content-Type: application/vnd.ms-excel Content-Encoding: base64 SPE-I00432-PP SC Corrosion West Region 2006 Final.doc Content-Type: application/msword 10f2 6/26/20067:51 AM ì \ c.;~ - ~ if , PRIORITY 1 2 3 4 -----r 5 ~ 6 7 8 9 10 11 12 13 14 15 16 ) NAME 1 C-121 1 C-1 31 1 0-1 09 1 0-111 1 0-120 --. :1'D~:1-i1----_c--1 1 ...--.,--. ..-...-.....'-...._._._.....:.~..-.......--... -- "...--.... ---1 .___ - - - - ..__:~_:~I_~=~_:~'?:n____.___.__hJ 1 0-132 I 1-' _n... -- -----------------.-.- --- . --I . 1 0-.136 : 1----··----..·----·..·--'-·-..·..·..·....----...··--------.....-------·..1 ! 1 0-137 I l_ ,,_n _______.._".___....___..__.__________.. """_____ _ ___I 1 0-138 1 0-139 1 C-119 .-.- --- n-7-":-c----"------,-,----·--~ - --------.---·-1 1C-t35. : .--, ;.-.-------..-....-......-.-..-.,~. ..---- -- ---- .-.-"" -- ---.--. i 1:Ð~135 .! : .:_._...;C":" .,..__....;_-:,....._..._C...____._..___...;_;_..~ 1 D-141 ConocoPhillips Alaska, Inc. 1 C and 1 D Suñace Casing Corrosion Repair Candidates TYPE INJ INJ INJ INJ INJ Gas Lift Gas Lift INJ INJ INJ INJ INJ INJ Jet Pump ESP Gas Lift PTD# LEAK DEPTH (ft) 201-080 4 201-185 7 197 -235 5* 198-166 5* 197-221 7 197-181 None 198-1 09 None 198-121 5 200-046 None 200-047 None 200-048 8 200-049 None 201-139 16 201-220 None 197-184 None 200-112 None COMMENTS I STATUS Proactive dig Proactive dig Proactive dig Proactive dig Proactive dig Proactive dig Proactive dig, backup candidate (has 500' casing) Proactive dig backup candidate. Notes: 1. Repairs will be performed in the priority order as listed, two repairs in progress simultaneously. 2. 10-135 and 10-141 are backup options in case excavations cannot be made on other wells. 3. List is a combination of wells with known leaks (8) and proactive inspections (2 injectors and 3 producers). 4. Proactive inspections are scheduled for wells that are currently shut-in and should not have rate impacts except 1 C-135 Jet Pump producer. 5. Rate impacts may be encountered if neighboring wells are shut-in during excavator activities or if additional flowlines need removal. 6. If excavations cannot be completed prior to rig arrival then SIMOPS operations will be considered or delays will be encountered. NSK Problem Well Supervisor 6/26/2006 ( ,I~,' n ';\ "1' :,::11- r1\, -(I~I~ ,:¡-:-I_J \,\."-'J :' j.' i\ \\!11 ' \\'>- 'i'I' U ,\ ,¡ ,I 'I:;:::¡ ~'~ "I 11: ï ~'\¡:! :¡ '0' :¡J 1J U:W ,l..:::J .,.."..-........"\~, ,( ,,..,.', .I ¡¡-- 'I :\" I . ~ r¡ ,I ~-I i\Jd) U~ ri' r-' Y'::--" n ;""',7 /-~ ! ;1, \ !! j ,;\ ~,(CLJ 'ilfl) ?A ,I r ,\ \ \1 ,I Ii', ".', I' i 'I \ ,\ L~\ Lb ¿~ dj)IJ',,~ L!~~ FRANK H. MURKOWSKI, GOVERNOR AT,ASIiA ORAND GAS CONSERVATION COltDlISSION 333 W. -¡r>< AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Brad Gatham Problem Well Supervisor Co naco Phillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 l c 7 -;;>':J-, J Re: KRU-West Sak 1D-120 Sundry Number: 305-227 SCÅN~~EJ~ AUG ~~ 2: 2005 Dear Mr. Gatham: 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: Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision uperior Court unless rehearing has been requested. DATED thisiJ day of August, 2005 Encl. 11. Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 4530' 4315' Casing Length Size CONDUCTOR 121' 16" SUR. CASING 3653' 5-1/2" SUR. CASING 745' 3-1/2" Perforation Depth MD (ft): 3866-3898,3934-3970,3981-4001,4068-4081 4100-4109,4118-4148,4180-4195 Packers and SSSV Type: Baker GBH-22 no SSSV 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name ~Brad Gathma; RBDMS 8Ft. AI:G .9. 9 700\ Signature ...", Commission Use Only 1. Type of Request: Abandon D D D Alter casing Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 112' 8. Property Designation: Kuparuk River Unit ô/S ~/0 CfiJ Z,6-DÇ ~. RECEIVED II, APPLICATION FOR SUNDRY APPROVAL AUG 11 2005 20 AAC 25.280 Operation Shutdown D Plug Perforations D Perforate New Pool D STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspend D o D D Alaska ai~i&ps (,~. CRmœl~~I~ D AnGho~e D Time Extension LJ Other D Re-enter Suspended Well D Perforate Repair well Stimulate Pull Tubing 4. Current Well Class: Development D Stratigraphic D 5. Permit to Drill NUJI1ber: 197-221 V 6. API Number: 50-029-22835-00 ../ 9. Well Name and Number: 1 D-120 Exploratory D Service 0 10. Field/Pool(s): Kuparuk River Field / West Sak Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): MD 121' 3765' 4510' TVD Burst Collapse Perforation Depth TVD (ft): 3686-3716,3751-3785,3795-3814,3877 -3890 3908-3916,3925-3953,3983-3997 Packers and SSSV MD (ft) 3764' no SSSV 13. Well Class after proposed work: Exploratory D Development D fY<ir/'hj 15. Well Status after proposed work: %/'Sf::3-"'Ö S' ;tr~ ,rr Oil D Gas D ~h, WAG D GINJ D Tubing Size: Tubing Grade: Tubing MD (ft): 3-1/2" L-80 3765' Service 0 Plugged D WINJ 0 Abandoned D WDSPL D Date: Contact: Title: MJ Loveland/Marie McConnell Problem Well Supervisor Date 'G--... 5-0r Phone 659-7224 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: .305-22. '1 Plug Integrity 0 BOP Test D Mechanical Integrity Test ~ Location Clearance D other: V"t*~Y~c.-\-c\~'X~\~~,~\\~(-\o '\;)\fè~ C47\"'S\>ñCÇ--\ö ~~\ ~\ \f'<-\à~ ~"''CÀO'S <;:)-\ t<tI(O::,,~ <D~,I'- __ COMMISSIONER ~~~~g~~::SION Date: <6Í ~ ~S INSTRUCTIONS ON REVERSE 0 RIG' N A L'bmit· DU~ v. { ConocoPhillips Alaska, Inc. Kuparuk WelllD-120 (PTD 1972210) RECEI\lED AUG 11 2005 A\aska Oi\ & Gas Cons. Commissìo" SUNDRY NOTICE 1 0-403 APPROVAL REQUEST Anchorage 08/03/05 This application for Sundry approval for Kuparuk welllD-I20 is for the repair ofa surface casing leak. The well is a 5-1/2" x 3-1/2" tapered casing completion that is designated as a water only injector, completed in December of 1997. On July 21, 2005, liquids in the conductor were observed while attempting a MITIA. The AOGCC was ~ notified and the well was immediately plugged until diagnostics could be performed and remains secured until the casing is repaired. On 07/23/05 diagnostics were performed to locate the leak. The leak site was determined to be approximately 8' below the conductor top. With approval, repair of the surface casing will require the following general steps: 1. Notify AOGCC Field Inspector of repair operation so they may witness the event. 2. Safe-out the well with plugs and load the tubing and IA with seawater and diesel freeze protection cap. 3. Remove the floor grate and equipment from around the wellhead. 4. Install nitrogen purge equipment for the IA and conductor so that hot work may be conducted in a safe manner. 5. Cut away the conductor casing and remove cement around surface casing for inspection. Approximately the top IO-feet of conductor will be removed to provide access to the surface casing. 6. CP AI Mechanical Engineers will determine appropriate patch and/or repair to return the casing to operational integrity. 7. QA/QC the repair and MIT -IA for a final integrity check. 8. Install anti-corrosion coating to repaired area of surface casing. 9. Replace the conductor and fill the void with material designed to seal out water and oxygen. 10. Backfill as needed with gravel around the wellhead. 11. Remove plugs and return the well to production. 12. File 10-404 with the AOGCC post repair. ORIGINAL ..Î Co i'I OCO Ph ill IPS, , Alaskaj tt1C. 1D-120 Gas Lift 1drel/Oummy Valve 1 (3673-3674, 00:4,750) PLUG (3725-3726, J 00:2,812) NIPPLE (3725-3726, 00:3,500) TUBING (0-3765, 00:3,500, 10:2,992) SEAL (3764-3765, 00:4,000) API: 500292283500 SSSV Type: ~ Annular Fluid: :/b::::~ ".,.".,..... Reference Log: ):::¡t:t::· L~st ~:~6;;~ ~2~1999 :<}t:! ,CasmgStnng-CONDUCTOR :{: ~ Description I 1,-11 ~~~~[~~~~:E ~ ~ Size I Top ~ ~ 3.500 0 ~ ,.. ~ Perforations Summary I ~ Interval TVD t ~: ,...~ 3866 - 3898 3686 - 3716 J i((@l\((((;((((¡¡¡l\i¡ I 3934 - 3970 3751 - 3785 r ~:¡!::::':r!¡!!!',''!¡!,'I' :: : ::: :: : :: .. 4100 - 4109 3908 - 3916 Perf 4118 - 4148 3925 - 3953 (3866-3898) 4180 - 4195 3983 - 3997 Perf (3934-3970) Perf (3981-4001) Perf (4068-4081 ) Perf (4118-4148) Perf (4180-4195) KRU 1 D-120 Well Type: INJ Orig Completion: 12/11/1997 Last W/O: Angle ~ TS: deg ~ Angle ~ TD: 18 deg @ 4530 Rev Reason: Pull Plug, Set WRP Last Update: 7/26/2005 Ref Log Date: 11): 4530 ftKB Max Hole Angle: 24 deg ~ 2528 Size Top Bottom TVD Wt I Grade I Thread 16.000 0 121 121 62.58 H-40 Size Top Bottom TVD Wt Grade Thread 5.500 0 3765 3591 15.50 L-80 3.500 3765 4510 4296 9.30 L-80 Bottom TVD 3765 3591 Zone Status Ft SPF Date Type Comment WSD 32 4 5/11/1998 IPERF 2.5 H.C.lD.P., 180 deg Phasing, 90 deg Orient WSB 36 4 5/11/1998 IPERF 2.5 H.C.lD.P., 180 deg Phasing, 90 deg Orient WSA4 20 4 5/11/1998 IPERF 2.5 H.C.lD.P., 180 deg Phasing, 90 deg Orient WSA3 13 4 5/11/1998 IPERF 2.5 H,C.lD.P., 180 deg Phasing, 90 deg Orient WSA2 9 4 5/11/1998 IPERF 2.5 H.C.lD.P., 180 deg Phasing, 90 deg Orient WSA2 30 4 5/9/1998 IPERF 2.5 H,C.lD.P., 180 deg Phasing, 90 deg Orient WSA2 15 4 5/9/1998 IPERF 2.5 H.C.lD.P., 180 deg 90 Orient St MD TVD Man Man Type V Mfr Mfr 3673 3504 BST ATX V Type V OD Latch Port TRO Date Vlv Run Cmnt DMY 1.0 T-1 0.000 0 12/11/1997 Description ID 2.812 0.000 3.000 4.000 - Depth 3725 3725 3764 3765 TVD 3553 3553 3590 3591 Type NIPPLE PLUG SEAL SBE Cameo 'W-1' Selective Nipple WRP set 7/25/2005 Baker 'GBH-22' Locator Seal Assy. Seals are stabbed into SBE at XO in 51/2 X3 1/2 Date Note 5/6/1998 Drift & tag w/22' x 2.625" to 4412' WL. Broached tight spot ~ 3283 WL with 2,803' R:EC;EI\/F: AUG 11 2005 Alaska Oi' & Gas GomL':,d}fr m~)$on Anchor~gQ lD-120 (PTD 197-221) & lD-109 (1972210) ert of failed MITrA ... e Subject: ID-120 (PTD 197-221) & ID-109 (1972210) Report of failed MITIA - IAxAtmos corom From: NSK Problem Well Supv <nI617@conocophillips.com> Date: Fri, 22 Jul2005 14:48:37 -0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us>, James Regg <jim Jegg@admin.state.ak.us>, bob _ fleckenstein@admin.state.ak.us Tom, Jim & Bob, Attached is MITT & MITIA data for 10-120. This test was performed to check the wellbore integrity of this mono-annulus injector. A plug was set in the tbg and an MITT passed, but an MITIA failed with diesel breaching the conductor top on 7/21/05. No diesel was spilled to the cellar. The diesel was contained in liner wrapped around the top of the conductor and the leak stopped as soon as the IA pressure was bleed down. The well has been left SI with a tbg plug. Prior to setting the TTP, 10-120 was on injection at 485 BWPO and TII = 1120/5. Additional diagnostics will be performed to determine the liquid leak rate and estimated depth of the leak to evaluate if an excavation repair is feasible. A 10-403 will be submitted for repair once a repair plan has been determined. Integrity verification is progressing at 10. Today, 10-109 passed an MITT with a TTP, but failed an MITIA with diesel to surface at the conductor top. The fluids were contained similar to 10-120 and no diesel was spilled to the cellar. 10-109 was on injection at 300 BWPO and TII = 1040/35. Only preliminary data is available at this time. I will send the MIT form for 10-109's failure tomorrow. There are nine more mono-annulus injectors at 10 that will be tested to verify integrity over the next few weeks at a rate of about one per day. Please let me know if you have any questions. Thanks, ~Jot,~t~~T! Marie McConnell. Problem Well Supervisor 659-7224 «MIT KRU 10-12007-21-05.xls» «10-120.pdf» «10-109.pdf» ,~~; \.;" '~ / _..L ¢-os! Content-Description: MIT KRU ID-120 07-21-05.xls MIT KRU ID-120 07-21-05.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: ID-120.pdf ID-120.pdf Content-Type: application/octet-stream Content-Encoding: base64 Content-Description: ID-I09.pdf ID-109.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 "'"' e e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us OPERATOR: FIELD 1 UNIT 1 PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. West Sak 1 KRU/1D-120 07121/05 Arend 1 Brake - AES o P o F Well P.T.D. Notes: Well P.T.D. Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential T emperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) MIT Report Form Revised: 06/19/02 MIT KRU 10-120 07-21-05.xls e e ARca Alaska, I nc.A GKA 1 D-12(J API: 500292283500 Well Type: INJ Angle @ TS: deg @ SSSV Ty pe: Orig Completion: 12/11/97 Angle @ TD: 18 deg @4530 Annular Fluid: Last W/O: Rev Reason: TAGGED FILUCORRECTED PERFS BY VG Reference Log: Ref Log Date: Last Update: 3/27/99 Last Tag: 4365 ID: 4530 ftKB GasUl! Last Tag Date: 3/24/99 Max Hole Angle: 24 deg @ 2528 landreJlDummy Valve 1 I Size I Top I Bottom I TVD I Wt I Grade I Thread I (3673-3674, ~121 I 121 I 62.58 I H-40 I I 00:4.750) TUBING Size Top Bottom I TVD I Wt I Grade I Thread I (CJ..3765, I 5.500 I 0 I 3765 I 3591 I 15.50 I L-80 I I 00:3.500, I 3.500 I 3765 I 4510 I 4296 I 9.30 I L-80 I I 10:2.992) SUR CASING I Size I Top I Bottom I TVD I Wt I Grade I Thread I (CJ..3765, I 3.500 I 0 I 3765 I 3591 I 9.30 I L-80 I ABM EUE 00:5.500, Wt:15.50) Interval TVD Zone tatus Fee SPF Date Type Comment 3866 - 3898 3686 - 3716 32 45/11/98 IPERF 2.5 H.C.lD.P., 180 deg Phasing, 90 deg Orient 3934 - 3970 3751 - 3785 36 4 5/11/98 IPERF 2.5 H.C.lD.P., 180 deg Phasing, 90 deg Orient 3981 - 4001 3795 - 3814 20 4 5/11/98 IPERF 2.5 H.C.lD.P., 180 deg Phasing, 90 deg Orient 4068 - 4081 3877 - 3890 13 45/11/98 IPERF 2.5 H.C.lD.P., 180 deg Phasing, 90 deg Orient 4100 - 4109 3908 - 3916 9 45/11/98 IPERF 2.5 H.C./O.P., 180 deg Phasing, 90 NIPPLE deg Orient (3725-3726, 4118 - 4148 3925 - 3953 30 4 5/9/98 IPERF 2.5 H.C.lO.P., 180 deg Phasing, 90 00:3.500) deg Orient 4180 - 4195 3983 - 3997 15 4 5/9/98 IPERF 2.5 H.C.lO.P., 180 deg Phasing, 90 deg Orient Stn MD TVD Man Man VMfr V Type VOD atch Port TRO Date Vlv Mfr Type Run þommen 1 3673 3504 BST 3 1/2 X 1 DV 1.0 T-1 0.000 0 12/11/97 ATX De pth TVD Type Description ID 3725 3553 NIPPLE Cameo 'W-1' Selective Nipple 2.812 3764 3590 SEAL ASSY Baker 'GBH-22' Locator Seal Assy . 3.000 3765 3591 SBE Baker; Seals are stabbed into SBE at XO in 5 1/2 X 3 1/2 Csg 4.000 Date I Note 5/6/98 IDrift & tag w/22' x 2.625" to 4412' WL . Broached tight spot @ 3283 WL with 2.803' SEAL ASSY (3764-3765, 00:4.(00) " SBE (3765-3766, 00:4.500) SUR. CASING (37654510, 00:3.500, Wt:9.30) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille O. Taylort~'~ DATE: July 11, 2002 Chair t[' SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder ~~~.~..~ Ph,llipsAlaska. P.I. Supervisor ~ 1 D Pad 1D-10,1D-119,1 D-120,1 D-130 FROM: John Crisp Kuparuk River Field Petroleum Inspector Kuparuk River Unit NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. I1D-10I T~,p~,nj.I ' S I-,-.v.,:,. I ~,,~o' ITu,:,~n, i " , 0118 4 i i 4 I P,T.'D.I 1980490 ITypetestl P ITestpsil 1545 I Casingl 0 I 1822 I 1789 I 1783 I P/F I -P I Notes: Rosemount DigitaI,Gaugeobservedfor test, 1 1/2 bbls. Pumped for test pressure. I WellI 1D-119 ITypelnj. I S J T.V.D. I 3564 I Tubingl 1850 11850 I~0 I~,~0 JlntervalI 4 I P:T.D.I 1972220 JTypetestl ' P ]TestiS'siI 1500 ]CasingJ 0 I1725 I 1700 I 1690 I P/F I P } NOtes: 2 bbls. Pu~p~d for test pressure. ' - I WellI 1D-120 I Typelnj.I N J T.V.D'I 359~ J TubingI 920 J 920 I 890 ] 890 J lntervalI 4 P.T.D.I 1972210ITypetestl P I Testpsil 1500 I CasingI 0 118O01175O1175O1. P/F J P Notes: 1 1/2 bbls. Pumped for test pressure. "We,,I ~-~0 I T~pe,.~.l S I T.V.D. } '~5~8 J Tubingl'900 ]~000 I~000 I~000 J,.te~v~,} 4 P.T.D.I 1971830 ITypetestl P ITestpsil 1500 I CasingI 1,75 I 1865 I lS25 ,I lS25 I,P/F I P .Notes! 1 bbl. pumped for test pressure. . We"I I Type ~j. P.T,D.I I Type test Notes: Type INJ, Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING 4 MIT's witnessed, no failures. Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) M.I.T.'s performed: 4 Attachments: Number of Failures: 0 Total Time during tests: 3 hrs. ..cc: MIT report form 5/12/00 L.G. SCANNED AUG 0 I 2002 MIT PAl 1D 07-11-02jc.xls 7/24/2002 ON'OR 2001 PL E ~A_T E IA L "-' _M '~ u n~ D E R C:LO~ILM. DOC ~ AOGCC Geological Materials Inventory PERMIT 9 7-221 ARCO Log Data_ Sent Received 8220 o,~SPERRY MPT/GR/EWR4 1/14/1998 1/14/1998 CBL ~'~3560-4110 " 3/27/1998 3/25/1998 DGR/EWR4-MD C" 121-4530 1/14/1998 1/14/1998 DGR/EWR4-TVD ~21-4315 1/14/1998 1/14/1998 Box MWD SRVY R SPERRY 0.-4530. 1/13/1998 1/14/1998 ~:407 Completion Date }¢t/C{~ Daily well ops JV"~'/~ ~/lL/ftJ2 Are dry ditch samples required? yes --~"~o And received? ~__~.~q~~ no Was the well cored? Are tests required? Well is in compliance Comments yes ~ no i~lt~ial~'4'~ Analysis description received? Received? ~~o~.- Wednesday, October 13, 1999 Page 1 of 1 ARCO Alaska, Inc. - Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 6, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1 D- 120 (Permit No. 97-221) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 1D-120. If there are any questions, please call 265-6120. Sincerely, T. W. Mc Kay Drilling Team Leader Kuparuk Drill Site Development TWM/skad O !8!NAL ? 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 E~ GAS E~ SUSPENDED [~ ABANDONED~ SERVICE [~ Injector 2 Name of Operator 7 Permit Number ARCO Alaska, thC 97-221 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22835 ~ ~./~ ili;. ' Kuparuk River Unit 166' FNL, 598' FEL, Sec. 23, T11N, R10E, UM ! At Top Producing Interval i .Ou~'~ [ 10 Well Number 60'FNL, 364'FWL, Sec. 24, T11N, R10E, UM i_ '-.~.-~' i WestSak1D-120 At Total Depth ............ 11 Field and Pool 29' FNL, 576' FWL, Sec. 24, T11N, R10E, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. West Sak Oil Pool RKB 41', Pad 71'I ADL 25650 ALK 468 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. J 15 Water Depth, if offshore J 16 No. of Completions 07-Dec-97 08-Dec-97 11-Dec-97 NA feet MSLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 4530' MD & 4315' TVD 4448' MD & 4235' TVD YES xL~ NO U NA feet MD 1520' APPROX 22 Type Electdc or Other Logs Run GR/Res/CDR, CBL 16' 62.58# H-40 SURF. 121' 24' 10 cu yds High Early ~-~ ''~: !'~ 5.5' 15.5# L-80 SURF. 3765' 8.5' 305 sx AS III LW, 485 sx Class G, & 3.5' 9.3# L-80 3765' 4510' 8.5" 60 sx AS I (tapered stdng) ; r 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) 38(~5'-3898' MD 368b'-37]~' 'rvD 3.5' 3765' 3934'-3970' MD 3750'-3784' TVD 3981'-4001' MD 3795'-3814' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 4068'-4081' MD 3877'-3889' TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 4100'-4109' MD 3907'-3916' TVD 4118'-4148' MD 3924'-3953' I~/D 4180'-4195' MD 3983'-3997' TVD 4 spf 27 PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Injector Date of Test Hours Tested PRODUCTION FOI OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOI: Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBl. OIL GRAVITY-APl (corr) Press. 24-HOUR RATE: 20° 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. ~ ~ :' GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure date, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top West Sak Sand 3862' 3682' Base West Sak Sand 4322' 4118' Annulus left open - freeze protected with diesel. 31. LIST OF AI~ACHMENTS Summary of Daily Drilling Reports, Directional Survey 32.1 hereby certify that the foregoing is true and correct to the best of my knowledge, ~ ~/~~ ~ Signed Title ~~ DATE _ Prepared by Name/Number Sharon AIIsup-Drake/263-4612 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 Date: 7/1/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:iD-120 WELL_ID: AK9021 TYPE: AFC: AK9021 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:12/07/97 START COMP: RIG:PARKER 245 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22835-00 12/06/97 (D1) TD: 121' (121) SUPV:GRW MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 DRILLING @ 400' Move rig from 1D-121 to 1D-120, 15' N/U diverter stack. 12/07/97 (D2) TD: 3036' (2915) SUPV:GRW MW: 9.1 VISC: 288 PV/YP: 30/43 DRILLING @ 3800' Drill from 121' to 3036' APIWL: 7.4 12/08/97 (D3) TD: 4530'(1494) SUPV:GRW MW: 9.2 VISC: 290 PV/YP: 38/55 RUNNING CASING Drill from 3036' to 4530' APIWL: 6.6 12/09/97 (D4) TD: 4530'( SUPV:DEB 0) MW: 9.3 VISC: 104 PV/YP: 31/36 APIWL: 6.2 PREPARE TO PU CLEAN OUT ASSY. Hold pre-job safety meeting. Run 3.5" & 5.5" casing. Pump first and second stage cement. 12/10/97 (D5) TD: 4530'( SUPV:DEB 0) MW: 8.9 VISC: 42 PV/YP: 7/12 APIWL: 20.0 RUNNING 3.5" COMPLETION ASSY Safety meeting. Drill out cement, plugs and stage collar at 1748' Clean out to 1806'. RIH DP. 12/11/97 (D6) TD: 4530'( SUPV:DEB 0) MW: 8.8 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED Run 3.5" tubing. ND BOPE. NU tree and test to 5000 psi. Test packoff to 5000 psi. Released rig @ 2300 hrs. 12/11/97. End of WellSummary for Well:AK9021 ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-120(W4-6)) WELL 1D-120 DATE 05/09/98 DAY 4 JOB SCOPE PERFORATE, PERF SUPPORT DALLY WORK RUN BRIDGE PLUG, TEST & PERF OPERATION COMPLETE I SUCCESSFUL NO ~ YES Initial Tbg Press 350 PSI DALLY SUMMARY Final Tbg Press 100 PSI IKEY PERSON SWS-BARTZ JOB NUMBER 0409980032.1 UNIT NUMBER 2128 Initial InnerAnn I I 0 PSI SUPERVISOR JONES Final Inner Ann I Initial Outer Ann I Final Outer Ann 200 PSII 0 PSII 0 PSI ISWS RAN HRS 3.5" WIRELINE BRIDGE PLUG, SET PLUG W/COE @ 4396', TESTED W/3000# FOR 30 MIN, GOOD. PERFED 3.5" LINER IN 2 RUNS FROM 4118' TO 4148' & 4180' TO 4195'. TIME LOG ENTRY 08:30 SWS (BARTZ & CREW) MIRU, HELD TGSM (PERF SAFETY) & SECURED RADIO SILENCE. MU HRS 3.5" BRIDGE PLUG & PT LUBRICATOR TO 3000#. 09:30 10:00 MIH W/HRS 3.5" WlRELINE BRIDGE PLUG, SETTING TOOL & CCL (20' OAL). CORR TO CBL LOG 2-25-98 & SET W/COE @ 4396'. PU FROM PLUG & RETAG PLUG. 11:30 POH & LD TOOLS. PLUG SET. 12:30 FOUND BAD SPOT ON E-LINE WHILE POH. STRIPPED OF 325' OF E-LINE & REHEADED. TESTED 3.5" TBG, SEAL ASSY & 3.5" LINER TO 3000# FOR 30 MIN, TEST GOOD. 14:00 MU GUN & PT LUBRICATOR TO 3000#. 14:45 MIH W/20' GUN (W/TOP 5' BLANK), 2.5" HC, DP, 4 SPF, 180 DEG PHASED, 90 ORIENT. CORR TO ABOVE LOG & PERFED FROM 4180' TO 4195'. 15:45 POH & LD GUN, ALL SHOTS FIRED. 16:30 MU GUN & PT LUBRICATOR TO 3000#. 17:30 RIH W/SWITCHED 10' (BTM) & 20' GUN AS ABOVE, CORR EACH GUN TO ABOVE LOG & PERF FROM 4118' TO 4148'. 18:30 POH & LD GUNS, ALL SHOTS FIRED. 19:15 RIG DOWN. 20:00 RELEASED SWS. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-120(W4-6)) WELL JOB SCOPE JOB NUMBER 1 D-120 PERFORATE, PERF SUPPORT 0409980032.1 DATE 05/11/98 DAY 5 DALLY WORK FINISHED PERFORATING OPERATION COMPLETE I SUCCESSFUL YESI YES Initial Tbg Press I Final Tbg Press Initial Inner Ann 400 PSII 300 PSI 0 PSI DAILY SUMMARY UNIT NUMBER 2128 KEY PERSON SWS-BARTZ · SUPERVISOR JONES Final Outer Ann 0 PSI SWS PERFORATED FROM 3866'-3898', 3934'-3970', 3981'-4001', 4068'-4081' & 4100'- 4109' IN 7 RUNS W/2.5" HC, 4SPF, DP, 180 I PHASED, 90 DEG ORIENT. I TIME LOG ENTRY 07:45 SWS (BARTZ & CREW) MIRU, HELD TGSM. SECURED RADIO SILENCE, MU GUN & PT LUBRICATOR TO 3000#. 09:15 10:00 10:30 11:20 11:45 12:45 13:15 14:00 14:20 RIH W/10' GUN (TOP 1' BLANK) 2.5" HC, 4 SPF, DP, 180 DEG PHASED, 90 DEG ORIENTED. CORR TO CBL LOG 2-25-98 & PERFED FROM 4100' TO 4109'. POH, LD GUN, ALL SHOTS FIRED. MU GUN & PT LUB TO 3000#. RIH W/20' GUN (TOP 7' BLANK) AS ABOVE & CORR TO ABOVE LOG. PERFED FROM 4068' TO 4081'. POH & LD GUN, ALL SHOTS FIRED. MU GUN, PT LUB TO 3000#. RIH W/20' GUN AS ABOVE, CORR TO ABOVE LOG. PERFED FROM 3981' TO 4001'. POH & LD GUN, ALL SHOTS FIRED. MU GUN & PT LUB TO 3000#/ RIH W/20' GUN AS ABOVE, CORR TO ABOVE LOG. PERFED FROM 3950' TO 3970'. POH & LD GUN, ALL SHOTS FIRED. MU GUN & PT TO 3000#. RIH W/20' GUN (TOP 4' BLANK) AS ABOVE, CORR TO ABOVE LOG. PERFED FROM 3934' TO 3950'. 15:20 POH & LD GUN, ALL SHOTS FIRED. 15:45 MU GUN & PT LUB TO 3000#. RIH W/20' GUN AS ABOVE, CORR TO ABOVE LOG. PERFED FROM 3878' TO 3898'. 16:30 POH & LD GUN, ALL SHOTS FIRED. 17:00 MU GUN & PT LUB TO 3000#. RIH W/20' GUN, (TOP 8' BLANK) AS ABOVE, CORR TO ABOVE LOG & PERFED FROM 3866' TO 3878'. 17:40 POH & LD GUN, ALL SHOTS FIRED. 18:15 RIG DOWN. 19:00 RELEASED SWS. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 1 ARCO ALASKA, INC. WEST SAK / 1D-120 500292283500 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/13/98 DATE OF SURVEY: 120897 MWD SURVEY JOB NUMBER: AKMM80034 KELLY BUSHING ELEV. = 111.60 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. .00 .00 -111.60 0 0 N .00 E .00 121.00 121.00 9.40 0 0 N .00 E .00 363.00 363.00 251.40 0 30 N 55.00 W .21 652.93 652.92 541.32 0 21 N 32.03 E .21 924.29 924.26 812.66 0 43 N 14.36 E .15 .00N .00E .00 .00N .00E .00 .61N .86W -.80 2.08N 1.43W -1.21 4.46N .56W -.10 1017.43 1017.34 905.74 3 24 N 84.68 E 3.48 1107.27 1106.88 995.28 5 45 N 88.78 E 2.64 1198.07 1196.90 1085.30 9 6 N 88.69 E 3.69 1293.32 1290.34 1178.74 13 7 N 87.78 E 4.22 1387.55 1381.91 1270.31 14 10 N 87.97 E 1.12 5.29N 2.34E 2.88 5.63N 9.51E 10.04 5.90N 21.26E 21.75 6.49N 39.61E 40.07 7.31N 61.84E 62.27 1482.53 1473.71 1362.11 15 30 N 87.62 E 1.39 1579.85 1566.95 1455.35 17 44 N 85.66 E 2.37 1675.69 1657.97 1546.37 18 45 N 84.32 E 1.14 1767.90 1744.62 1633.02 21 10 N 84.01 E 2.63 1961.12 1925.04 1813.44 20 45 N 84.19 E .21 8.25N 86.15E 86.54 9.91N 113.92E 114.34 12.54N 143.81E 144.34 15.75N 175.12E 175.81 22.85N 243.88E 244.94 2152.08 2102.29 1990.69 22 52 N 82.798 E 1.13 2340.67 2276.20 2164.60 22 37 N 82.07 E .23 2528.14 2448.13 2336.53 24 20 N 84.92 E 1.09 2716.89 2620.35 2508.75 23 57 N 83.79 E .32 2907.27 2794.45 2682.85 23 46 N 83.30 E .14 30.82N 314.40E 315.90 40.30N 386.72E 388.82 48.70N 460.93E 463.49 56.29N 537.77E 540.71 64.95N 614.32E 617.74 3095.99 2967.17 2855.57 23 45 N 81.55 E .37 3285.43 3141.89 3030.29 21 40 N 84.51 E 1.25 3473.32 3316.65 3205.05 21 23 N 83.67 E .22 3662.78 3494.21 3382.61 19 23 N 82.93 E 1.07 3851.41 3672.30 3560.70 19 6 N 82.76 E .16 74.97N 689.70E 693.76 83.93N 762.26E 766.86 91.03N 830.88E 835.84 98.71N 896.45E 901.85 106.45N 958.13E 964.01 4040.09 3850.72 3739.12 18 51 N 82.36 E .14 4229.15 4029.65 3918.05 18 49 N 81.58 E .13 4472.45 4260.37 4148.77 18 10 N 80.95 E .28 4530.00 4315.05 4203.45 18 10 N 80.95 E .00 114.40N 1018.98E 1025.35 122.93N 1079.45E 1086.38 134.64N 1155.76E 1163.49 137.47N 1173.48E 1181.41 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 1181.50 FEET AT NORTH 83 DEG. 19 MIN. EAST AT MD = 4530 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 84.05 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY AT 4,530.00' MD SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 ARCO ALASKA, INC. WEST SAK / 1D-120 500292283500 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/13/98 DATE OF SURVEY: 120897 JOB NUMBER: AKMM80034 KELLY BUSHING ELEV. = 111.60 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION .00 .00 -111.60 1000.00 999.94 888.34 2000.00 1961.40 1849.80 3000.00 2879.31 2767.71 4000.00 3812.78 3701.18 .00 N .00 E .00 5.18 N 1.40 E .06 .06 24.25 N 257.59 E 38.60 38.54 69.31 N 651.46 E 120.69 82.09 112.67 N 1006.14 E 187.22 66.53 4530.00 4315.05 4203.45 137.47 N 1173.48 E 214.95 27.73 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA ARCO ALASKA, INC. WEST SAK / 1D-120 500292283500 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/13/98 DATE OF SURVEY: 120897 JOB NUMBER: AKMM80034 KELLY BUSHING ELEV. = 111.60 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -111.60 111.60 111.60 .00 211.60 211.60 100.00 311.60 311.60 200.00 411.61 411.60 300.00 .00 N .00 E .00 .00 N .00 E .00 .00 .00 N .00 E .00 .00 .35 N .50 W .00 .00 .85 N 1.21 W .01 .00 511.61 511.60 400.00 611.61 611.60 5.00.00 711.61 711.60 600.00 811.62 811.60 700.00 911.63 911.60 800.00 1.35 N 1.85 W .01 .00 1.87 N 1.57 W .01 .00 2.39 N 1.24 W .01 .00 3.07 N .92 W .02 .00 4.30 N .60 W .03 .01 1011.68 1011.60 900.00 1112.02 1111.60 1000.00 1212.98 1211.60 1100.00 1315.15 1311.60 1200.00 1418.18 1411.60 1300.00 5.25 N 2.04 E .08 .05 5.65 N 10.02 E .42 .34 5.96 N 23.73 E 1.38 .96 6.68 N 44.57 E 3.55 2.17 7.58 N 69.34 E 6.58 3.03 1521.86 1511.60 1400.00 1626.76 1611.60 1500.00 1732.50 1711.60 1600.00 1839.73 1811.60 1700.00 1946.74 1911.60 1800.00 8.70 N 96.68 E 11.03 N 128.24 E 14.42 N 162.43 E 18.45 N 200.92 E 22.34 N 238.81 E 10.26 3.68 15.16 4.90 20.90 5.75 28.13 7.23 35.14 7.01 2053.72 2011.60 1900.00 2162.18 2111.60 2000.00 2270.68 2211.60 2100.00 2379.02 2311.60 2200.00 2488.05 2411.60 2300.00 26.20 N 276.62 E 31.30 N 318.30 E 36.59 N 360.05 E 42.34 N 401.34 E 47.24 N 444.47 E 42.12 6.98 50.58 8.46 59.08 8.50 67.42 8.34 76.45 9.03 2597.81 2511.60 2400.00 2707.31 2611.60 2500.00 2816.73 2711.60 2600.00 2926.01 2811.60 2700.00 3035.28 2911.60 2800.00 51.24 N 489.53 E 55.87 N 533.90 E 60.70 N 578.05 E 65.83 N 621.83 E 71.38 N 665.51 E 86.21 9.76 95.71 9.50 105.13 9.42 114.41 9.28 123.68 9.27 3144.53 3011.60 2900.00 3252.84 3111.60 3000.00 3360.45 3211.60 3100.00 3467.89 3311.60 3200.00 77.85 N 709.04 E 82.77 N 750.28 E 86.58 N 789.85 E 90.81 N 828.91 E 132.93 9.25 141.24 8.31 148.85 7.61 156.29 7.44 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 ARCO ALASKA, INC. WEST SAK / 1D-120 500292283500 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/13/98 DATE OF SURVEY: 120897 JOB NUMBER: AKMM80034 KELLY BUSHING ELEV. = 111.60 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 3575.18 3411.60 3300.00 95.13 N 867.52 E 163.58 7.29 3681.22 3511.60 3400.00 99.46 N 902.52 E 169.62 6.04 3787.18 3611.60 3500.00 103.80 N 937.28 E 175.57 5.96 3893.00 3711.60 3600.00 108.17 N 971.64 E 181.40 5.83 3998.75 3811.60 3700.00 112.62 N 1005.74 E 187.15 5.75 4104.42 3911.60 3800.00 117.16 N 1039.60 E 192.82 5.67 4210.08 4011.60 3900.00 122.03 N 1073.36 E 198.48 5.66 4315.74 4111.60 4000.00 127.02 N 1107.10 E 204.14 5.65 4421.12 4211.60 4100.00 132.13 N 1139.95 E 209.52 5.38 4530.00 4315.05 4203.45 137.47 N 1173.48 E 214.95 5.43 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS 3/27/98 GeoQuest 500 W. International Airport Road ~chorage, AK 99518-1199 .;J"N: Sherrie NO. 11965 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 West Sak (Reservoir Analysis Logs) Well Job # Log Description Date BL RF Sepia Floppy Disk WS 1 D-119 CBL SLIM-CMT 9 8 0 2 2 5 I 1 WS 1 D-120 CBL SLIM-CMT 9 8 0 2 2 5 1 1 . . SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: 0 !::t I I__1-- I ~J CS WELL LOG TRANSM1TrAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 January 14, 1998 RE: MWD Formation Evaluation Logs 1D-120, AK-MM-80034 The technical data listed below is being submitted herewith. Please address any problems or concems to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, ~-G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-22835-00 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company WELL LOG TRANSMITTAL To: State of Alaska January 14, 1998 Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 RE' MWD Formation Evaluation Logs 1D-120, AK-MM-80034 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1D-120: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-22835-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22835-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (907) 563-3256 ° Fax (907) 563-7252 spe -sur, 0 !::i I I--I-- I I~ (~ S E I:t~JI I-- E S 13-Jan-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1D-120 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD n/a' MD 4,530.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 December 1, 1997 Michael Zanghi Drill Site Develop. Supv. ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re; Kuparuk River Unit West Sak 1D-120(F6) ARCO Alaska. Inc. Permit No: 97-221 Sur. Loc.' 166'FNL, 598'FEL, Sec. 23, T11N, R10E, UM Btmhole Loc: 45'FNL, 565'FWL, Sec. 24, T11N, R10E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to drill the above referenced well· The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25·035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. · Chairman BY ORDER OF THE COMMISSION dlffenclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALAS,,,,-~ OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Reddll lb Type of Well Exploratory E] Stratigraphic Test [~ Development Oil Re-Entry Deepen Service X Development Gas E] SingleZone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 71' feet Kuparuk River Field 3. Address 6. Property Designation West Sak Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25650, ALK 468 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 166' FNL, 598' FEL, Sec. 23, T11 N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 63' FNL, 393' FWL, Sec. 24, T11 N, R10E, UM West Sak 1 D-120 (F6) #U-630610 At total depth 9. Approximate spud date Amount 45' FNL, 565' FWL, Sec. 24, T11 N, R10E, UM 12/5/97 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1D-04 4520' MD 565' @ TD feet 42.1' @ 720' feet 2560 4304' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 1000' feet Maximum hole angle 22.3° Maximum surface 1441 psig At total depth 1893 psig (TVD) 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 77' 41' 41' 118' 118' +200 CF 8.5" 5.5" 15.5# L-80 BTC-MOE 3709' 41' 41' 3750' 3581' 475 Sx Arcticset III & 8.5" 3.5" 9.3# L-80 8rd 770' 3750' 3675' 4520' 4304' 450 Sx Class G & 60 sx AS I 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 ~nrt°~u%~id(~te R ~ C ~ ~V FI,. D Liner Perforation depth: measured , ;.. ~- . =: true vertical 0 R I C. ! lkl L *-0 20. Attachments Filing fee X Property plat [] BOP Sketch [] Diverter Sketch ~d~.0[I & ~J}~'i~Z~- X Drilling fluid program X Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 2~.~00 r~e~l~uirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ ~4..-(~ Drill Date //"'-- /¢'"' ~2 Signed 7' ~'~' ~ //~//~ ~-~'~'~4itle Site Develop. S upv. Commission Use Only q 7-- 2Z ! 50- OZq- ,~,,~. g~r !¢--'/ -~;"'~/ other requirements Conditions of approval Samples required r- Yes r'~ No Mud Icg required r- Yes [~ No Hydrogen sulfide measures i---lYes [~No Directional survey required [~*Yes ~ No Required workingpres.~ureforBOPEi 1[~I2ML4_.r ~ 3M E~ 5M E~] 10M [~ 15M Other: Original Signed 8y by order of Approved by David W, Johnston Commissioner the commission Date /._:~ -'//.-'~,~ Form 10-401 Rev. 7-24-89 Submit in triplicate ARCO Alaska, Inc. Kuparuk Drillsite Development Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor November 19, 1997 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill West Sak 1D-120 (F6) West Sak Phase lA Development Well, Kuparuk River Unit Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the West Sak interval from 1D pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and develop the production potential of the West Sak sands in the vicinity of 1D pad. The well is designed as a monobore injection well using a 5-1/2" x 3-1/2" tapered casing string, with 3-1/2" tubing used as a tieback string. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). Note the 40 acre spacing requirements governed by the West Sak pool rules. 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b). Note that due to the pressures expected in the West Sak sands, ARCO proposes to test the 5000 psi BOP equipment to a maximum of 3000 psi, pending AOGCC approval per this letter and APD. Please note that due to the large number of KRU wells which have penetrated the West Sak sands in this area, ARCO has a clear understanding of the formation pressures to be encountered. As a result, no overpressured strata is expected in this area. There are also no shallow hazards expected at WS 1D- 120 (F6), such as shallow gas. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany There have been eight (8) Kuparuk wells and several West Sak wells drilled from KRU 1D pad, and no occurrences of shallow gas or other hazards have been observed. There is a gas sand at approximately 2,100' TVD which is present, but has not caused any past problems in the existing wells which penetrated this sand using a diverter system only. An exception to the requirements set out by 20 AAC 25.033 (e) and 25.061 (a) are hereby requested for this APD because of this regional experience. A prediction of the maximum downhole and surface pressures which may be encountered however are included in this APD per 20 AAC 25.035 (d) (2). 6) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 8) A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. 9) Also note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S monitoring equipment functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. 10) Please note that because of the large volume of regional information available in this area, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned. An exception to the requirements detailed in 20 AAC 25.005 (c) (8) is thus requested. Please note that the anticipated spud date for this well is December 05, 1997. If you have any questions or require further information, please contact Tom Brockway at (907) 263-4135 or Tom McKay at (907) 265-6890. Si ncer. e'.!Y; ~ ..? Thomas A. Brockway" Operations Drilling Engineer Attachments CC; West Sak 1D-120 (F6) Well File Tom McKay ATO-1202 Keith Lynch AT0-1228 Ike Bellaci AT0-1260 Cliff Crabtree NSK-6 RECEIVED Nov 199i' Alaska Oil & Gas Cons. Commission Anchorage Drill, Case and Completion Plan for West Sak 1D-120 (F6) Monobore Injector General Procedure: ! Excavate cellar, install cellar box, set and cement 16" conductor to +/- 110' RKB. Weld landing ring on conductor. 2. Move in / rig up drilling rig. Install diverter & function test same. . Spud and directionally drill 8-1/2" hole to desired target through West Sak interval. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. NOTE: A 9-7/8" hole may be drilled depending on the hole conditions encountered. 4. Condition hole for casing, trip out. , Run and cement 3-1/2" 9.3# L80 8RD x 5-1/2" 15.5# L80 BTC tapered casing string to surface, displace cement with mud. Perform stage job and top job as required. NOTE: Stage (DV) tool to be installed +/- 200 ft TVD below the base of permafrost interval. , Nipple down diverter and install 'wellhead. Nipple up BOP stack and pressure test same to 3000 psi. . Pick up 4-3/4" mill tooth bit, 3-1/2" drill collars, and 2-7/8" drill pipe. Trip in and drill out stage collar. Clean out to top of 3-1/2" casing. , Pressure casing to 3,000 psi for 30 minutes per AOGCC regulations. Record results. . Swap well over to non-freezing completion brine. Circulate well clean. Trip out. 10. Rig up and run 3-1/2" tubing tieback to surface for monobore injector. Sting into seal bore and pressure test tubing and annulus to 3,000 psi. Set tubing hanger. Install back pressure valve. 11. Nipple down BOP stack. Install production tree and pressure test same. 12. Secure well, release rig. Page 1 13. 14. 15. 16. 17. Rig up Coiled Tubing Unit (CTU) and clean out 3-1/2" monobore tubing to PBTD. Circulate well to clean brine. Secure well and release CTU. Rig up E-line unit and RIH with CBL/CET, and run cement bond log across West Sak interval. Report results to office for remedial action if necessary. Rig up E-line unit and RIH with through-tubing perforating guns. Perforate well overbalanced. POOH with perf guns. Repeat runs as required to perforate all desired West Sak intervals. Rig down E-line unit. Install back pressure valve, shut in and secure well. TAB, 11/19/97, Rev.2 Page 2 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS & DRILLING AREA RISKS West Sak 1 D-120 (F6) Drillinq Fluid Type Extended Bentonite Slurry Drilling Fluid Properties: Property Density Plastic Viscosity Yield Point Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to TD Initial 8.5-9.0 ppg 8-15 35-7O 10-25 10-30 8-15 8.0-10.0 4-6 % Drill Out to TD Final 10.0 ppg 15-35 35-70 10-25 10-35 5-7 8.0-9.5 8-12% Drilling Fluid System: Tandem Brandt Scalping Shale Shakers Triple Derrick Flow Line Cleaners Solids Processing System to Minimize Drilling Waste Desander, Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Mud Hoppers with Mixing Pumps *Spud mud should be adjusted to a FV between 200 - 250 sec/qt to drill gravel beds. Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Only one hole section will be drilled in this well. This single hole section will be drilled using a diverter system only for well control. A tapered 5-1/2" x 3-1/2" surface / production casing string will be run at total depth (TD). This combination surface / production casing will be cemented to surface using a stage (DV) collar. The stage collar will be placed approximately 200 feet TVD below the base of the permafrost interval. MASP (Maximum Anticipated Surface Pressure): Based on actual well test data from the nearby WS1-01 well, expected reservoir pressures in the West Sak sands in the 1D pad area vary from 0.43 to 0.46 psi/fi, or 8.2 to 8.8 ppg EMW (equivalent mud weight), depending on the TVD of the sand layer being evaluated. Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.6 ppg can be predicted as a maximum mud weight required to safely drill this formation, assuming a TVD of 3,675' MD/TVD. Experience in the area has proven that these zones can be safely drilled using a diverter system only for well control purposes. The rig diverter system will be filled with water or mud and function tested prior to spudding the well. Since the combination surface / production casing will not be drilled out, leakoff test and MASP calculations are not necessary for drilling ahead. However, MASP calculations for cased hole operations are in order. Calculating MASP based on the highest recorded reservoir pressure from the WS1-01 well, and assuming a gas gradient of 0.11 psi/fi from the West Sak base in the West Sak 1D-120 (F6) well to surface, the following MASP can be computed: MASP (4116 ft)(0.46 - O. 11 psi/fi) 1441 psi Based on this cal?dlation for MASP, it will only be necessary to test the BOP equipment to a maximum of 3,000 psi. Following the cementing of the ,5-1/2" x 3-1/2" combination surface / production casing in this well, the BOP stack will be installed and tested to 3,000 psi. The stage collar will then be drilled out and the well cleaned out to PBTD. At that time, the casing will be pressure tested for 30 minutes at a surface pressure of 3,000 psi as well. The 5-1/2" 15.5# 1_80 BTC casing to be used has a burst rating of 7',000 psi; 70 % of this burst rating is 4,900 psi. After testing, a 3-1/2" tubing tieback string will be installed in the well to be used as the injection string. Drillinq Area Risks: Drilling risks in the West Sak 1D-120 (F6) area are limited to lost circulation and potential borehole instability in and below the permafrost formation. Lost circulation will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. Based on previous Drill Site 1D drilling results, 10.0 ppg mud should be more than adequate to control both the Ugnu and West Sak formation pressures without resulting in lost circulation. ARCO has drilled through the West Sak formation many times in nearby Kuparuk wells. For this reason, AAI requests that the requirements listed in 20 AAC 25.033 (e) and 20 AAC 25.061 (a) (pertaining to predicted overpressured strata and seismic refraction / reflection analysis, respectively) be waived for the drilling of West Sak 1D-120 (F6). Well Proximity Risks: The nearest existing well to West Sak 1D-120 (F6) is KRU 1D-04. As designed, the minimum distance between the two wells would be 42' at 440' MD. Annular Pumpinq Activities: Incidental fluids generated from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface / production casing annulus of an existing well on DS-1D. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. In addition, the West Sak 1D-120 (F6) surface casing / production tubing annulus will be filled with diesel and/or non-freezing brine after setting the 3-1/2" tubing tieback string and prior to the drilling rig moving off of the well. TAB, 11/17/97 O'e,:,t,,d b:,. f~.~. For: T McKAY Da~e p~olte~ : 5-0ct-97 Plot Reference is WS 10-120/F6 Vets. ~5. Coordrnotes are in fee[ reference s~o[ ~120. T~e Vertical Depths ore reference ~8 Structure : Pod 1D II : FO Field : Kuporuk River Unit Location : North Slope, 0 100 200 300 400 I I I I I I I I I 250 5o0 750 lOOO 1250 1500 1750 2000 2250 2500 2750 3000 3250 3500 3750 4000 4250 4500 RKB ELEVATION: 112' SURFACE LOCATION: 166' FNL, 598' FEL SEC. 23, T11N, R10E K0P TVD=t000 TMD=1000 DEP=0 3.00 6.00 9.00 12.00 DLS: 3.00 deg per 100 ft 15.00 18.00 B/ PERMAFROST TVD=1632 TMD=1644- DEP=108 21.00 EOC TVD=1725 TMD=1744 OEP=143 MAXIMUM ANGLE 22.31 DEG T/ UGNU SNDS TVD=3003 TMD=3125 DEP=667 22.00 East (feet) -> 500 600 700 800 900 1000 1100 1200 I I I I I I f I I I I I I I f TARGET LOCATION: 63' FNL, 393' FWL SEC. 24, T11N, RIOE TARGET TVD--3827 TMD=4012 DEP--996 NORTH 103 EAST 991 84.05 AZIMUTH 996' (TO TARGET) BEGIN ANGLE DROP TVD=3567 TMD=3735 DEP=899 T/ W SAK SNDS(EOD) TVD=3675 TMD=3851 DEP=941 TARGET - A3 TVD-3827 TMD-4012 DEP=996 B/ W SAK SNDS TVD=4116 TMD=4320 DEP=1101 ~ TD - CSG PT TVD=4304 TMD=4520 I)EP=llT0 400 I i iI i I ii i i i 0 250 500 750 1000 1250 Vertical Section (feet) -> TD LOCATION: 45' FNL, 565' FWL SEC. 24, T11N, RI OE RECEIVED NOV 20 Naska 0il & Gas Cons. A~ch0rage Azimuth 84.05 with reference 0.00 N, 0.00 E from slot #120 TARGET ANGLE 20 DEG 300 ' 200 o 100 ~ / o.ot,~ u~ ~; .... For: T McKAY[ Coord~atel are In feet reference liar ~120. / rul Vir~;C=l Dopt~~RKB (Po~er A}[' CO AL.AS]KA, I .e. Structure : Pad 1D Well : F6 Field : Kuparuk River Unit Location : North Slope, Alaska 280 240 200 160 120 A 80 I 40 Q) ',4,-- 0 ,-4-- o Z 4o 80 120 160 200 240 East (feet) -> 80 40 0 40 80 120 160 200 240 280 320 350 400 440 480 520 560 600 640 680 720 750 i i i i i i i __L___-L__ _JI I I I I I I I I I I I I I I I I I L I I I I I i I I I I I J 1 ...... L___ ',,. I / ./-"300 2~ooi 18oy,, ....::':'"'" t /~.,..//.././'1200 ~ 20001 t'~ '"w lOOO~ r .... ~.- ...... %-.. ~ ............ ~soo .................... 7 ....... :~ % Wo~ °o o ........ G ~ ooo ..............: ......... ~ ,~ /o~ Ua o ~ . ............... ~--? ....... ~ ~oooe % % 2000/" / 21 O0/' / ,' fo~O0 1500 1600 1700 oonn,.. ,..,.,~, .,' 'v' - : .... / / 2300 .,"" .... el 000 ,' /' 24.00 ...... ~ 1800 -"~'-"---------_~900 ~"~-~_. 2000 2100 220O 230O 1000 ~ 1500 .... t'"';) ~, 14 ......... 'T ....... 1 ....... ~ ...... ~ ....... I ......... I ...... [ ' ' I~ I .... ~ ....... f ........ I ......... 1 ~ ......... 1 I ...... I ...... [ ..... I ...... I ........... I ......... I ...... f ........ I ......... I ...... 1 .......... % ....... f ..... r ...... l ..... ~ ..... 1 f ........ f .... f ..... f .......... f .... ~ ........ 1 ....... I .... I ...... f ........ 80 40 O 40 80 120 160 200 240 280 520 360 400 440 480 520 560 600 640 680 720 760 East ('feet) -> 28O 240 200 160 120 8o A I Z 40 o ,-4- 0 ~ 4-0 ~ , 120 160 200 24O ARCO ALASICA, Inc. Pad 1D F6 slot #120 Kuparu~ River Unit North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE by Baker Hughes INTEQ REPORT Your ref : WS 1D-120/F6 Vets. #3 Our ref : prop2206 License : Date printed : 27-0ct-97 Date created : 17-Apr-97 Last revised : 6-0ct-97 Field is centred on nT0 16 18.576,w150 5 56.536 Structure is centred on n70 18 1.316,w149 30 18.908 Slot location is nT0 17 59.683,w149 30 36.341 Slot Grid coordinates are N 5959498.691, E 560490.310 Slot local coordinates are 166.00 S 598.00 W Projection tyl~e: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath Closest approach with 3-D Minimum Distance method Last revised Distance PGMS <0-8365'>,,1,Pad 1D 4-Aug-92 402.5 TOTCO Survey,,WS-8,Pad 1D 16-0ct-96 432.2 PGMS <O-8930'>,,5,Pad 1D 4-Aug~92 74.4 PGMS <0-7502'>,,4,Pad 1D 4-Aug-92 42.1 PGMS <O-8070'>,,3,Pad 1D 4-Aug-92 163.0 PGMS <0-9783'>,,2,Pad 1D 4-Aug-92 282.8 PGMS <0-8610'>,,6,Pad 1D 25-Oct-97 197.0 MSS <3311-8200'>,,7,Pad 1D 25-Oct-97 317.0 WS 1D-130/H4 Version #4,,H4,Pad 1D 27-Oct-97 240.0 WS 1D-135/G7 Version #4,,GT,Pad 1D 22-0ct-97 360.0 WS 1D-129/J3 Version #3,,J3,Pad 1D 22-0ct-97 225.0 WS 1D-133/J5 Version #4,,JS,Pad 1D 22-0ct-97 285.0 WS 1D-121/G5 Version #3,,GS,Pad 1D 23-0ct-97 15.0 WS 1D-118/E5 Version #4,,ES,Pad 1D 22-0ct-97 59.6 WS 1D-119/F4 Vers.#3,,F4,Pad 1D 6-Oct-97 14.9 WS 1D-124/G3 Version #3,,G3,Pad 1D 22-Oct~97 105.0 WS 1D-105/C7 Version #4,,CT,Pad 1D 22-Oct-97 300.0 WS 1D-106/D6 Vers.#3,,D6,Pad 1D 8-0ct-97 270.0 WS 1D-109/D4 Vers. #2,,D4,Pad 1D 8-0ct-97 225.0 WS 1D-115/E3 Version #4,,E3,Pad 1D 22-0ct-97 105.0 WS 1D-117/E7 Version #4,,ET,Pad 1D 22-0ct-97 75.0 M.D. 1000.0 1125.0 1025.0 720.0 20.0 420.0 20.0 460.0 600.0 780.0 300.0 280.0 1000.0 1175.0 1075.0 900 0 380 0 1000 0 380 0 280 0 380 0 Diverging from M.D. 1000.0 1125 1025 720 88O 42O 680 460 600 78O 3OO 280 1000 1175 1075 900.0 380.0 1000.0 380.0 280.0 4519.9 West Sak, D-120 (F6) Monobore jector Well Proposed Completion Diagram Tapered Monobore Injector Isolate Injection Thief Zones Using Patches 3-1/2" Tubing 9.3# L-80 8RD EUE (tied back to surface from Seal Bore/PBR) 16" Conductor Casing @ 80' Weatherford Gemoco 754HO 5-1/2" DV Stage Collar Stnd. Grade BTC Threads (set +/- 200' TVD below permafrost) 5-1/2" Combination Surface/Production Casing 15.5# L-80 BTC (Cemented to Surface) Baker Seal Bore Extension - 12' Size 80-40 with 80-40 bottom sub to 3-1/2" tbg and 80-40 top sub, 5-1/2" to 3-1/2" (ASN 461-3435) (positioned +/- 100' above perfs) XO From 5-1/2" Casing to 3-1/2" Casing D Sands B Sands A Sands 3-1/2" Tapered Casing/Tubing 9.3# L-80 8RD EUE (Cemented to Surface) ARCO Alaska, Inc. TAB, 11/18/97, Rev. 1 KUPARUK R'rV'ER UNIT - WEST SA~ OPERATIONS 20" DIVERTER SCHEMATIC 3 2 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. . MAINTENANCE & OPERATION 'UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16"CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20"- 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20"- 2000 PSI ANNULAR PREVENTER. TWM, 9/15/97 8 6 5 4 13 5/8" 5000 PSi BOP STACK West Sak Operations - Injector Wells ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2_ ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON 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 WATER. 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. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TESTAS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUTOF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 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 DRILUNG POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES. 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 BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DALLY. VBRS WILL ACCOMODATE 3-1/2" TO 6" OR 4-1/2" TO 7" PIPE ODS AS APPROPRIATE. 1. 16" - STARTING HEAD 2_ 7-1/16" - 5000 PSI TUBING HEAD 3. 7-1/16" - 5000 PSI X 13-5/8" - 5000 PSI DOUBLE STUDDED ADAPTER/SPACER SPOOL 4. 13-5/8" 5000 PSI X 13-5/8" 5000 PSI SPACER SPOOL 5. 13-5/8" - 5000 PSI PIPE RAMS 6. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 7. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 8. 13-5/8" - 5000 PSI ANNULAR TWM, 9/18/97 1 .9/02/97! AJR APP I 9E$CRIPTION i AS-BUicT'PER K.SI3~ K97082ACS Pood D.S. 1-D Q 1 105~} 2 106 03 e 115 e 117 118 ~ 4 ~0 5 124 6 129 130 133 b7 135 (~ 8 i REVI DATE i BY i ' 2 19/17/97t AJR !"-Pt '" A/RStRipi '~'~ APP OESCRIPT1ON AS-BUILT PER KSBi~ K97082ACS i 14 15 W~ST { SAK-1 THIS SURVEY VICIN! TY MAP SCALE: I" = I MILE NO SCALE LEGEND 0 EX/STING CONDUCTORS · NEW CONDUCTOR LOCATION ARCO Alaska, Inc. LK610410 9/02//97 SEE SHEET # 2 FOR NOTES AND LOCATION INFORMATION LOUNSBURY & ASSOCIATES, INC. E,~NEERS PLANNERS SURVEYORS AREA: lO MOOULE XX UNIT: Ol DRILL SITE 1-D WEST SAK PHASE I - WELL CONDUCTORS AS-BUILT CEA-D1DX-6104-D10 {SHEET: 10F2 2 REV! _'.ATE ] 8Y I CK I APP t DESCRIPTION iREV! OATS ] 3Y i 1. CCORDINA?ES SHOFifN ARE A.S.P. ZONE 4, N.A.D. 27. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL. ALL DISTANCES SHOWN ARE TRUE. 2. BASIS OF LOCATIONS AND ELEVATIONS ARE D.S. I-D ~,IONUMENTS PER LHD AND ASSOCIA TEE. ..T.CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTIONS ~4 & 23, TOWNSHIP 11 NORTH, RANGE 10 EAST, U.M. 4. DA TE OF SURVEYS: 8/25, 29 & 30/97, FIELD BK L97-24, pp. 52 - 45, 68 - 7J. 5. DRILL SITE 1-0 GRID NORTH IS ROTA TED 00' 01' 05" WEST FROM A.S.P. ZONE 4 GRID NORTH. 6. SEE DRAWING NSK-3.5-1 FOR AS-BUILT LOCATIONS OF CONDUCTORS tjtl THROUGH ijlB. ......... , " .".., i ~:"" 49th 'DESCRIPTION AS-BUILT PER KSB~ K97082ACS WEST SAK-1 THIS ! ~~~,~, SURVEY :, 'u'" .............. 2"' ................ VICINITY MAP SCALE: 1"= 1 MILE wen A.S.P.s LA TITUOE LONGITUDE ' "'~SEC',,,,~SEC' PAD O.G. No. 'Y' 'X' ~,1~ ~/,~ ELEV, ELEV. S;c. 14, T. 11 N., R. IO E. F.S.L.F.E.L.I 105 5,959,798,99 560,490.57 ?0' 18' 02.637" 149' 30' .76.265" I34' 595' 70.5' 62.0' 106 5,959,768.93 560,490.67 70' 18' 02.341" 149' .70' .76.268" 104' 595' 70.4' 62.,:7' 109 5,959,72.7.89 560,490.60 70' 18' 01,898" 149' .70' .76,280" 59' 596' 70.4' 62.7' S ;c. 25, T. 11 N., R. 10 E. F.N.L.F.E.L.! 115 5,959,60,.7.9.7 560,490.68 70' 18' .00.718' 149' 30' 36.$06' 61' 597' 70.4' 63.4' 117 5,959,575.95 5~0,490.65 70' 18' 00,425' 149' .70' .76,314' 91' 597' 70.4' 6.7.4' 118 5,959,558.95 560,490.68 70' 18' 00.276' 149' $0' ,,76,316' 106' 597' 70.4' 63.4' 119 5,959,5I$.86 560,490.72 70' 17' 59.8.72' 149' .70' .76..726" I5I' 598' 70.6' 66.0' 120 5,959,499.01 560,490.77 ?0' 17' 59.686" 149' .70' .76,327' 166' 598' 70.6' 66.0' 121 5,959,483.89 560,490.67 70' 17' 59,538' 149' .70' .76,335" 181' 598' 70.5' 66.0 124 5,959,393.96 560,490.70 70' 17' 58.653' I49' 30' .76,355' 271' 599' 70.3' 65.0' 129 5,959,27.7.92 560,490.79 70' 17' 57.472' 149' 30' 36.,.,~i80' 391' 600' 70.3' 68,2' 130 5,959,259.09 560,490.81 70' 17' 57.326' 149' ,70' 36.,,,'~83' 406' 600' 70.5' 68.2' I$$ 5,959.21.7.89 560,490.68 70' 17' 56,882' 149' .70' .76.$97' 451' 600' 70.4' 69.0' 135 5,959,1.79.02 560,490.80 70' 17' 56,146' 149' .70' .76,412' 526' 601' 70.5' 69.4' SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLA T REPRESENTS A SURVEY DONE 8Y ME OR UNDER MY DIRECT SUPERVISION AND THAi' ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF AUGUST .70, 1997. LOUNSBURY ASSOCIATES, INC. E~NEERS PLANNERS SURVEYORS ARCO Alaska, Inc. LK610410 9//02/97 . AREA' 1D MOOULE · XX DRILL SITE 1-D WEST SAK PHASE I - WELL CONDUCTORS AS-BUILT CEA-D1DX-6104-D10 I S"[[T:2 ~2 IRE:~ UNIT' D1 · WELL PERMIT CHECKLIST COMPANY )/~ ~,~0 WELLNAME ~j~/,lf~',C2,k 1~)-/20 PROGRAM:expf-ldevl-lredrllFlserv,J~wellboresegCann. disposalparareqC FIELD & POOL /~ ¢ 0//~" ~ INIT CLASS ,-('~' t/- t,L///1/~ GEOL AREA ~ C.~ ~ UNIT# / [ / ~ ~ ON/OFF SHORE ¢/Ct. ADMINISTRATION . 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. DATE 12. ¢,1 l~4¢t? 13. Permit fee attached ....................... -~.~) N Lease number appropriate ................... ( ~ N Unique well name and number .................. Y..) N Well located in a defined pool .................. ~ N Well located proper distance from drilling unit boundary .... N Well located proper distance from other wells .......... N Sufficient acreage available in drilling unit ............ L N If deviated, is wellbore plat included ............... I N Operator only affected party ................... ' N Operator has appropriate bond in force ............. ~, N Permit can be issued without conservation order ........ (~ N Permit can be issued without administrative approval ...... N Can permit be approved before 15-day wait ........... N REMARKS ENGINEERING 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. Conductor string provided ................... Surface casing protects all known USDWs ........... CMT vol adequate to circulate on conductor & surf csg ..... CMT vol adequate to tie-in long string to surf csg ........ CMT will cover all known productive horizons .......... Casing designs adequate for C, T, B & permafrost ....... N Adequate tankage or reserve pit ................. _. N. If a re-drill, has a 10-403 for abandonment been approved...~-~-Y~~"~'/ Adequate wellbore separation proposed ............. "(~N ~.-----~.,/. If diverter required, does it meet regulations .......... Y(..~N. Drilling fluid program schematic & equip list adequate ..... BOPEs, do they meet regulation ................ //Y:/'N BOPE press rating appropriate; test to ~ psig. ~N - Choke manifold complies w/APl RP-53 (May 84) ........ ~ N _ Work will occur without operation shutdown ........... Is presence of H2S gas probable ................. Y , , GEOLOGY DATE 30..Permit can be issued w/o hydrogen sulfide measures._.. ~-..-.. Y N 31. Data presented on potential overpres~sure-zone-s~ ;'"'T'. .... Y N 32. Seismic analysis of shall~0~m'~'6h~s ............. Y N 33. Seabed con~i~ey (if off-shore) .............. ' Y .N 34. C o~m e/p h o n e fo, we/eekxl~ ~orr?t~er~S~ne~rt s ....... Y'N .... . , GEOLOGY: RPC ~O ENGINEERING: COMMISSIONi BEW(~O~ ~/~''' DWJ~ JDH ~- RNC~ '" CO . Comments/Instructions: HOW/lit - A:\FORMS\cheklist rev 09197 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. U~L Memory Multi-Finger Caliper Log Results Summary 19 7 - ,¿ L( Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: ConocoPhillips Alaska, Inc. August 18, 2005 7013 1 3.5" 9.3Ib. L-80 Tubing & Liner Well: 1 D-120 Field: Kuparuk State: Alaska API No.: 50-029-22835-00 Top Log IntvI1.: Suñace Bot. Log IntvI1.: 3,800 Ft. (MD) I nspection Type : Corrosive & Mechanical Damage Inspection COMMENTS: This caliper data is tied into the "W-1" Nipple @ 3,725' (Driller's Depth). This log was run to assess the condition of the 3.5" tubing and liner with respect to corrosive and mechanical damages. The 3.5" tubing and liner logged appear to be in good to poor condition with respect to corrosive damage, with a maximum wall penetration of 81% in joint 93 (2,931'). Wall penetrations ranging from 20% to 81% are recorded in 82 of the 128 joints logged. The damage appears in the forms of general corrosion, isolated pitting, and lines of corrosion. A line of corrosive damage is recorded in the interval between joints 55 and 118 (1,720' - 3,800'). No significant areas of cross-sectional wall loss or 1.0. restrictions are recorded throughout the tubing and liner logged. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. MAXIMUM RECORDED WAll PENETRATIONS: Line of Corrosion Line of Corrosion Line of Corrosion Line of Pits Line of Corrosion (81 %) ( 76%) ( 73%) ( 71%) ( 70%) Jt. Jt. Jt. Jt. Jt. 93 @ 113 @ 85 @ 65 @ 87 @ 2,931 Ft. (MD) 3,559 Ft. (MD) 2,668 Ft. (MD) 2,042 Ft. (MD) 2,748 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL lOSS: No significant areas of cross-sectional wall loss (> 7%) are recorded throughout the tubing and liner logged. MAXIMUM RECORDED ID RESTRICTIONS: No significant 1.0. restrictions are recorded throughout the tubing and liner logged. . _.' '.' ....:-, q, C) <ì\, pr. ¡··.·.·.f·'.,(' \1'I..'~ii'\,.~\;·-~ .. ~lf~) 1<. v ¿ ..1 J.' .:;) 't.,;;p 1~.L 'ù r; '\¡~ ~,=. ,.r '--. I Field Engineer: 111I. McCrossan Analyst: M. Tahtouh Witness: C. Fitzpatrick I PrQActive Diagnostic Services/ Ine. I P.O. Box 1369r Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (.2.81) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (90.7) 659-2307 Fax: (907) 659-2314 clds," Well: Field: Company: Country: 10-120 Kuparuk ConocoPhillips Alaska, Inc. USA I Tubing: Nom.OD 3.5 ins Weight 9.3 ppf Grade & Thread L-80 Penetration and Metal loss (% wall) _ penetration body 150 ~ metal loss body 100 TI' ~ ¡ 50 Ii LLJ 0 o to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of joints analysed (total = 128) pene. 0 1 45 22 60 loss 1 1 27 0 0 0 o o Damage Configuration ( body) 80 60 40 20 o isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of joints damaged (total = 121) 35 17 69 0 0 PDS Report Overview Body Region Analysis Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: Nom.lD 2.992 ins August 18, 2005 MFC 24 No. 00387 1.69 24 M. T ahtouh Nom. Upset 3.5 ins Upper len. 1.2 ins Lower len. 1.2 ins Damage Profile (% wall) !IRIœ metal loss body 50 _ penetration body o °1 æ æ: = ¡ææ.. 100 48 " '. 98 GLM 1 r I -~" , ,m Bottom of Survey = 118.6 Analysis Overview page 2 i ( PDSKEPORT JOINT TABULATION sHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 10-120 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal 1.0.: 2.992 in Country: USA Survey Date: August 18/ 2005 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body 0/0 Loss 1.0. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 .1 32 0 0.03 11 6 2.86 PUP 1 35 0 0.04 17 .2 2.90 Shallow pitting. 1.1 66 0 0.01 6 .2 2.90 1.2 71 0 0.04 17 0 2.87 Shallow pitting. 2 73 0 0.04 15 .2 2.89 Shallow pitting. 3 104 0 0.04 15 3 2.88 Shallow corrosion. Lt. Deposits. 4 136 0 0.04 17 3 2.89 Shallow corrosion. Lt. Deposits. 5 167 0 0.04 17 3 2.90 Shallow corrosion. 6 199 0 0.03 13 .2 2.90 Shallow pitting. 7 230 0 0.03 13 .2 2.87 Shallow pitting. Lt. Deposits. 8 261 0 0.05 18 3 2.87 Line shallow corrosion. Lt. Deposits. 9 292 0 0.04 14 3 2.91 Shallow corrosion. 10 323 0 0.03 12 .2 2.90 11 355 0 0.04 17 3 2.90 Shallow corrosion. Lt. Deposits. 12 386 0 0.03 13 .2 2.90 Shallow pitting. 13 418 0 0.03 12 .2 2.90 14 448 0 0.03 13 .2 2.91 Shallow pitting. 15 478 0 0.05 18 .2 2.90 Shallow corrosion. Lt. Deposits. 16 510 0.06 0.04 15 5 2.90 Shallow corrosion. 17 541 0 0.04 15 2 2.90 Shallow pitting. 18 572 0 0.04 14 .2 2.90 Shallow pitting. 19 603 0 0.04 18 3 2.87 Shallow corrosion. Lt. Deposits. 20 634 0 0.04 14 2 2.91 Shallow pitting. 21 665 0 0.03 12 .2 2.91 22 696 0 0.03 11 3 2.89 23 728 0 0.04 17 3 2.89 Shallow corrosion. Lt. Deposits. 24 759 0 0.05 19 5 2.88 Shallow corrosion. Lt. Deposits. 25 791 0 0.04 17 3 2.88 Shallow corrosion. Lt. Deposits. 26 821 0 0.04 18 3 2.90 Shallow pitting. Lt. Deposits. 27 853 0 0.04 17 4 2.88 Shallow pitting. Lt. Deposits. 28 884 0 0.03 13 2 2.90 Shallow pitting. 29 916 0 0.04 17 3 2.89 Shallow corrosion. 30 947 0 0.04 14 .2 2.90 Shallow corrosion. 31 979 0 0.05 19 3 2.89 Shallow corrosion. 32 1009 0 0.05 18 .2 2.90 Shallow corrosion. 33 1041 0.06 0.04 16 4 2.87 Shallow corrosion. 34 1072 0 0.05 21 .2 2.90 Isolated pitting. 35 1103 0 0.03 13 5 2.89 Shallow pitting. 36 1133 0 0.05 21 .2 2.90 Isolated pitting. 37 1163 0 0.03 12 .2 2.89 Lt. Deposits. 38 1194 0 0.03 13 .2 2.92 Shallow pitting. 39 1225 0 0.05 20 3 2.90 Isolated pitting. 40 1257 0 0.04 14 4 2.90 Shallow pitting. Lt. Deposits. 41 1287 0 0.04 17 2 2.91 Shallow pitting. 42 1319 0 0.05 21 3 2.90 Isolated pitting. 43 1349 0 0.08 31 2 2.90 Isolated pitting. Lt. Deposits. 44 1380 0 0.03 13 3 2.90 Shallow corrosion. 45 1411 0 0.10 40 4 2.89 Isolated pitting. Lt. Deposits. 46 1443 0 0.05 20 .2 2.89 Isolated pitting. 47 1473 0 0.04 17 6 2.90 Shallow pitting. I Penetration Body ~!::r Metal Loss Body Page 1 ( 4 PDS KEPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Joint Jt. Depth Pen. Pen. Pen. Metal Min. No. (Ft.) Upset Body °/0 Loss I.D. (Ins. ) (Ins.) 01 (Ins.) 10 48 1504 0 0.03 13 4 2.89 49 1534 0 0.09 34 3 2.90 50 1566 0 0.09 34 4 2.88 51 1596 0 0.07 28 4 2.89 52 1628 0 0.06 24 :2 2.89 53 1659 0 0.06 22 4 2.90 54 1690 0 0.08 30 :2 2.90 55 1722 0 0.10 40 3 2.89 56 1752 0 0.11 44 5 2.89 57 1783 0 0.08 32 .., 2.90 .) 58 1814 0.07 0.13 50 4 2.88 59 1846 0 0.14 54 4 2.89 60 1877 0 0.10 39 4 2.91 61 1908 0 0.13 49 6 2.90 62 1940 0 0.13 50 6 2.89 63 1971 0 0.12 46 4 2.89 64 2003 0 0.15 58 4 2.90 65 2034 0 0.18 71 6 2.90 66 2065 0 0.12 49 5 2.89 67 2097 0.06 0.12 48 5 2.89 68 2128 0 0.13 50 5 2.90 69 2160 0 0.14 54 6 2.89 70 2191 0 0.13 50 6 2.89 71 2223 0 0.12 48 4 2.91 72 2254 0 0.14 54 4 2.90 73 2286 0 0.15 61 6 2.90 74 2317 0 0.13 50 5 2.89 75 2347 0 0.17 66 5 2.89 76 2379 0 0.16 62 5 2.90 77 2410 0 0.15 57 5 2.90 78 2442 0 0.15 59 6 2.89 79 2473 0 0.16 62 5 2.91 80 2505 0 0.16 62 5 2.90 81 2536 0 0.15 59 5 2.90 82 2568 0 0.17 68 8 2.91 83 2599 0 0.14 57 4 2.89 84 2631 0 0.17 66 6 2.89 85 2662 0 0.19 73 6 2.90 86 2693 0 0.16 63 5 2.89 87 2725 0 0.18 70 7 2.90 88 2757 0 0.15 60 5 2.89 89 2788 0 0.18 70 6 2.90 90 2820 0 0.15 57 7 2.89 91 2848 0 0.17 66 6 2.89 92 2880 0 0.16 64 6 2.89 93 2911 0 0.21 81 7 2.90 94 2943 0 0.17 65 5 2.89 95 2974 0 0.13 50 5 2.89 96 3006 0 0.15 59 5 2.87 97 3037 0 0.13 50 4 2.87 Well: Field: Company: Country: Survey Date: 1 D-120 Kuparuk ConocoPhillips Alaska, Inc. USA August 18/ 2005 Comments Shallow pitting. Isolated pitting. Isolated pitting. Lt. Deposits. Isolated pitting. Lt. Deposits. Isolated pitting. Line of pits. Line of pits. Line of pits. Line of pits. Lt. Deposits. Line of pits. Line of pits. Lt. Deposits. Line corrosion. Lt. Deposits. Line of pits. Line of pits. Lt. Deposits. Line of pits. Lt. Deposits. Line of pits. Lt. Deposits. Line of pits. Lt. Deposits. Line of pits. Lt. Deposits. Line corrosion. Lt. Deposits. Line corrosion. Lt. Deposits. Line corrosion. Lt. Deposits. Line corrosion. Lt. Deposits. Line corrosion. Lt. Deposits. Line corrosion. Lt. Deposits. Line corrosion. Lt. Deposits. Line corrosion. Lt. Deposits. Line corrosion. Lt. Deposits. Line corrosion. Lt. Deposits. Line corrosion. Lt. Deposits. Line corrosion. Lt. Deposits. Line corrosion. Lt. Deposits. Line corrosion. Lt. Deposits. Line corrosion. Lt. Deposits. Line corrosion. Lt. Deposits. Line corrosion. Lt. Deposits. Line corrosion. Lt. Deposits. Line corrosion. Lt. Deposits. Line corrosion. Lt. Deposits. Line corrosion. Lt. Deposits. Line corrosion. Lt. Deposits. Line corrosion. Line corrosion. Lt. Deposits. Line corrosion. Lt. Deposits. Line corrosion. Lt. Deposits. Line corrosion. Lt. Deposits. Line corrosion. Lt. Deposits. Line corrosion. Lt. Deposits. Line corrosion. Lt. Deposits. Line corrosion. Lt. Deposits. Line corrosion. Lt. Deposits. Page 2 Damage Profile (% wall) o 50 100 :.: .. ... .. .. ... .. .. II.. I II Penetration Body f;;~';,\ Metal Loss Body :I ~ PDS KEPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Joint Jt. Depth Pen. Pen. Pen. Metal Min. No. (Ft.) Upset Body 0/0 Loss I.D. (Ins.) (Ins.) DID (Ins.) 98 3068 0.07 0.13 50 4 2.88 99 3099 0 0.13 51 4 2.90 100 3131 0 0.11 45 4 2.90 101 3162 0 0.12 46 4 2.86 102 3193 0 0.14 56 4 2.89 103 3224 0.08 0.14 54 4 2.86 104 3255 0 0.15 57 6 2.89 105 3286 0 0.14 55 4 2.89 106 3318 0 0.13 50 4 2.89 107 3347 0 0.15 59 4 2.88 108 3377 0 0.13 50 4 2.89 109 3408 0 0.09 36 2 2.88 110 3439 0 0.11 41 3 2.88 111 3471 0 0.09 35 3 2.86 112 3501 0 0.10 41 3 2.86 113 3533 0 0.19 76 5 2.88 114 3564 0 0.16 64 5 2.88 115 3595 0 0.13 50 6 2.89 116 3626 0 0.10 41 3 2.90 116.1 3658 0 0.11 44 6 2.89 116.2 3672 0 0 0 0 N/A 116.3 3679 0.08 0.14 54 5 2.90 117 3693 0 0.15 59 3 2.89 117.1 3725 0 0 0 0 2.81 118 3727 0 0.10 38 3 2.89 118.1 3757 0 0.07 28 2 2.91 118.2 3764 0 0 0 0 3.00 118.3 3777 0 0.09 37 2 2.86 118.4 3783 0 0.07 26 3 2.86 118.5 3787 0.04 0.06 24 2 2.90 118.6 3794 0 0.08 32 2 2.90 Well: Field: Company: Country: Survey Date: 1 D-120 Kuparuk ConocoPhillips Alaska/ Inc. USA August 18, 2005 Comments Line corrosion. Lt. Deposits. Line corrosion. Lt. Deposits. Line corrosion. Lt. Deposits. Line corrosion. Lt. Deposits. Line corrosion. Lt. Deposits. Line corrosion. Lt. Deposits. Corrosion. Lt. Deposits. Line corrosion. Line corrosion. Lt. Deposits. Line corrosion. Lt. Deposits. Line corrosion. Line corrosion. Lt. Deposits. Line corrosion. Line corrosion. Line corrosion. Line corrosion. Lt. Deposits. Line corrosion. Lt. Deposits. Line corrosion. Line corrosion. Lt. Deposits. PUP Line corrosion. Lt. Deposits. GLM 1 (Latch @ 2:00) PUP Isolated pitting. Lt. Deposits. Line corrosion. Lt. Deposits. W-l Nipple Line corrosion. PUP Isolated pitting. SEAL PUP Isolated pitting. deposits. PUP Isolated pits. Lt. Deposits. PU P Isolated pits. PU P Line of pits. Page 3 Damage Profile (% wall) o 50 100 I .. .. I .. .. II. . .. - ... .. I. ~ . Penetration BQdy ~ Metal Loss Body ~.-.....C..-'~'"....'-....'..'" ._ -.... "'-, LS Ii' PDS Report Cross Sections Well: Field: Company: Country: Tubing: 10-120 Kuparuk ConocoPhillips Alaska, Inc. USA 3.5 ins 9.3 ppf L-80 Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: August 18/ 2005 MFC 24 No. 00387 1.69 24 M. Tahtouh Cross Section for Joint 93 at depth 2931.42 ft Tool speed = 52 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 94 % Tool deviation = 46 0 Finger 2 Penetration =0.205 ins Line of Corrosion 0.21 ins = 81% Wall Penetration HIGH SIDE = UP Cross Sections page 1 ckJ.. .. ..w_..~. n "'.' ~_ - --. -LS !to PDS Report Cross Sections Well: Field: Company: Country: Tubing: 1 0-120 Kuparuk ConocoPhillips Alaska/ Inc. USA 3.5 ins 9.3 ppf L-80 Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: August 18/ 2005 MFC 24 No. 00387 1.69 24 M. Tahtouh Cross Section for Joint 113 at depth 3558.75 ft Tool speed = 51 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 96 % Tool deviation = 44 0 Finger 2 Penetration = 0.194 ins Line of Corrosion 0.19 ins = 76% Wall Penetration HIGH SIDE = UP Cross Sections page 2 Sperry-Sun Drilling Services LIS Scan Utility Thu Jan 08 09:29:33 1998 Reel Header Service name ............. LISTPE Date ..................... 98/01/08 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Tape Header Service name ............. LISTPE Date ..................... 98/01/08 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 1 AK-MM-80034 S. BURKHARDT G. WHITLOCK Date.~.~~d / 1D-120 500292283500 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 08-JAN-98 23 liN 10E 166 598 .00 '111.60 70.60 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 4530.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 3. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN M. MUNYAK OF SPERRY-SUN DRILLING SERVICES AND MIKE WERNER OF ARCO ALASKA, INC. ON 07 JANUARY, 1998. 4. THIS WELL REACHED A TOTAL DEPTH (TD) OF 4530'MD, 4315'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB,001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/01/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE FET RPD RPM RPS RPX GR ROP $ START DEPTH STOP DEPTH 121.0 4493.0 121.0 4493.0 121.0 4493.0 121.0 4493.0 121.0 4493.0 121.0 4500.5 121.0 4530.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 121.0 4530.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD AAPI 4 1 68 RPX MWD OH~M 4 1 68 RPS MWD OH/~M 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR. 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean Nsam DEPT 121 4530.5 2325.75 8820 ROP 10.9277 899.56 259.053 8820 GR 8.3699 188.66 59.6675 8760 RPX 0.5002 2000 69.221 8745 RPS 0.5294 2000 70.0594 8745 RPM 0.7159 2000 80.3426 8745 RPD 0.2342 2000 95.7673 8745 FET 0.068 2.7224 0.299808 8745 First Reading 121 121 121 121 121 121 121 121 Last Reading 4530.5 4530.5 4500.5 4493 4493 4493 4493 4493 First Reading For Entire File .......... 121 Last Reading For Entire File ........... 4530.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/01/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/01/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 ~ Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FET 121.0 RPD 121.0 RPM 121.0 RPS 121.0 RPX 121.0 GR 121.0 ROP 121.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: STOP DEPTH 4493.0 4493.0 4493.0 4493.0 4493.0 4500.5 4530.5 08-DEC-97 ISC 5.06 CIM 5.46 MEMORY 4530.0 121.0 4530.0 .0 24.3 TOOL NUMBER P0891CRG6 P0891CRG6 8.500 8.5 SPUD MUD 175.00 288.0 9.0 MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ............ ........... Datum Specification Block sub-type...0 450 7.4 1.300 1.137 2.200 2.800 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 1 AAPI 4 1 68 RPX MWD 1 OHMM 4 1 68 RPS MWD 1 OHMM 4 1 68 RPM MWD 1 OHMM 4 1 68 RPD MWD 1 OHMM 4 1 68 ROP MWD 1 FT/H 4 1 68 FET MWD 1 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 27.3 Name Min Max Mean Nsam DEPT 121 4530.5 2325.75 8820 GR 8.3699 188.66 59.6675 8760 RPX 0~5002 2000 69.221 8745 RPS 0.5294 2000 70.0594 8745 RPM 0.7159 2000 80.3426 8745 RPD 0.2342 2000 95.7673 8745 ROP 10.9277 899.56 259.053 8820 FET 0.068 2.7224 0.299808 8745 First Reading 121 121 121 121 121 121 121 121 Last Reading 4530.5 4500.5 4493 4493 4493 4493 4530.5 4493 First Reading For Entire File .......... 121 Last Reading For Entire File ........... 4530.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/01/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/01/08 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 98/01/08 Origin ......... ~ ......... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Technical Services Library. Library. Scientific Scientific Physical EOF Physical EOF End Of LIS File