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191-034
• • RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JUL 2 5 2016 WELL COMPLETION OR RECOMPLETION REPORT A : tifirt la.Well Status: Oil Gasp SPLUG❑ Other ❑ Abandoned 0 . Suspended ❑ 1b.Well Clas 20AAC 25.105 20MC 25.110 Development ❑ Exploratory❑ GINJ ❑ WINJ❑ WAG❑ WDSPL❑ No.of Completions: Service 0 , Stratigraphic Test❑ 2.Operator Name: 6. Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 6/26/2016 , 191-034/316-308/ 3.Address: 7. Date Spudded: 15.API Number: P.O.Box 100360 Anchorage,AK 99510-0360 4/2/1991 50-103-20155-00' 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 114'FSL,529'FWL,Sec 27,T11N, R83, UM 4/3/1991 KRU 2M-23 ' Top of Productive Interval: 9. Ref Elevations: KB:140 17. Field/Pool(e- J 4(L. ktAy P146 not applicable GL: 105 BF: Kupurak River Field/I lc.Lli1 Reo1 Total Depth: 10.Plug Back Depth MD/TVD: 18. Property Designation: 1310'FSL, 1744'FWL,Sec 27,T11N,R8E,UM SURFACE ADL 25586 0 4b. Location of Well(State Base Plane Coordinates,NAD 27): 11.Total Depth MDITVD: 19. Land Use Permit: Surface: x- 488369 y- 5948986 Zone- 4 3535/2853 2672 TPI: x- NA y- NA Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 489584 y- 5950170 Zone- 4 NONE 1400/1392 5. Directional or Inclination Survey: Yes ❑ (attached) No 0 13.Water Depth, if Offshore: 21.Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL)I N/A 22. Logs Obtained: List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential, gamma ray,caliper, resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary NONE SCANNED SEP 2 9 2016 23. CASING,LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH ND AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT. PULLED 16 62.5 H-40 36 115 36 115 24 230 sx AS III 9.625 36 J-55 35 3515 35 2840 12.25 1150 sx AS III,985 sx ClassG 120 sx ASI 7 26 J-55 33 1524 33 1486 8.5 not applicable 24.Open to production or injection? Yes ❑ No 0 25.TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MDITVD) Size and Number): 2.875 1643 1599/1550 A6p<NVo1`►>O DAT 26.ACID,FRACTURE,CEMENT SQUEEZE, ETC. (8 Was hydraulic fracturing used during completion? Yes❑ No ID VERIFIED Per 20 AAC 25.283(i)(2)attach electronic and printed information Lt, DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): ABANDONED Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate �•► 4 Form 10-407 Revised 11/2015 /' VTL -6/ ),rl,,cO NTlNUED,O PAGE 2 RBDMS JUL 2 2gbmit ORIGINIAL o r� • • 28.CORE DATA Conventional Core(s): Yes ❑ No 0 Sidewall Cores: Yes ❑ No 0 If Yes,list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No 2 'Permafrost-Top Surface Surface If yes, list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1400 1392 Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval N/A N/A information, including reports,per 20 AAC 25.071. • Formation at total depth: N/A N/A 31. List of Attachments: Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report.production or well test results.Der 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. c..5./-Contact: Jill ISimek A 263-4131 Email: Jill.Simek(a)cop.com �-j�� Printed Name: G.L.Alvord (( , Title: Alaska Drilling Manager J 1 Signatur � $Al Z C� 1 • 14(-U(3� Phone: 265-6120 Date: 1/25 /�� INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated.Each segregated pool is a completion. Item 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation:Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 11/2015 • Submit ORIGINAL Only • • , SUNDRY NOTICE 10-407 ConocoPhillips Well 2M-23 Plug and Abandonment July 6, 2016 ConocoPhillips Alaska, Inc. performed Plug and Abandonment operations on 2M-23, commencing operations on June 7, 2016 and completing the Plug and Abandonment on June 26, 2016. / The tree and wellhead were removed at 7 ft. below tundra level. Cement was at surface in the tubing, production casing by surface casing annulus, and surface casing by conductor annulus. The tubing by production casing annulus top of cement was at 28' . A top job was performed to bring cement to surface in all annuli,then the well was capped and excavation backfilled. Pictures below show cement to surface in all annuli,marker plate installed, and final site condition after backfill. The field Well Service Report is attached. a !,ate ‘•1,441t-A 1(0/. / V • ,,, , , ' \ t2016- A1!raghYs ° has ph .h is prove - ' want '••:aa°: ' . 4 3Copying fora tither any other ,i$ ( �y a ed wit t '' asp t cif a' x '� 2\ o f 0• '` 3 • • 4 _ • .vim • ,,,,.i;-,:i!-,,,,,t,..,,, - ,,t,, 4,v, x 1 A ms.s [' r Ory r ° 4. ..a= "° sr¢ ., r H � d g a •, a ,4100 a3 : ont>coPhillipsAlaska, � ,- ;; � .. 3sr e ."-.7.:1111111111114 ~... s.. .� ... .` �; _ gg T te • • P&A WORK SUMMARY EVENT_DATE EVENT TEXT 6/7/2016 P&A Prep Initial T/I/0= 1/2/1 Bled OA to 0 psi in 5 sec(gas). Bled IA to 0 psi in 5 sec(gas). Bled T to 0 psi in 1 sec(gas). Left T, IA, and OA on open bleed for 30 min. Gas reading at end of 30 min bleed: OA= H2S-0 PPM ,CO- 12 PPM, 02-20.9%, LEL-55% IA= H2S-0 PPM, CO- 10 PPM, 02-20.9%, LEL-27% T= H2S-0 PPM, CO-0 PPM, 02-20.9%, LEL-0% Final T/I/O=0/0/0 • 6/23/2016 Notified AOGCC for Opportunity to Witness P&A cutoff. 6/24/2016 P&A Initial T/1/0=0/0/0 (IN PROGRESS) Verified pressures were at 0 PSI. Removed jewelry, valve handles and VR plug. Removed platform and then well head. Cut windows and removed 2'from below casing hanger. Flew structural shoring pipe into place. Began driving shoring pipe into the ground with pile driver vibrator. 6/25/2016 P&A(In Progress) AFC used piledriver to drive shoring 14.5 ft below pad level. 6/25/2016 T/1/0=0/0/0 Finished driving in shoring pipe the remaining length to pad level. Sucked out shoring pipe until reaching cement. Jack hammered cement until reaching base plate. Steve GBR welder cut base plate. Removed base plate. Continued jack hammering cement reaching approx 8'. Changed out with night shift who continued jack hammering cement. 6/26/2016 Stateman Jonnie Hill wavied oppertunity to witness cement top+ P&A marker plate welded in place. • • 6/26/2016 P&A In Progress Cleared dirt and debris from inside of shoring to 15 ft. below pad level. GBR welder Garry cut windows into conductor 9 ft below tundra level. Welded Weld-O-Let to SC to test for fluid (small amount of fluid in SC). 6/26/2016 P&A(COMPLETE) GBR welder JOSE attached weld o lets, drilled through casings and safety verified cutting conditions to be good then cut windows approx 7 below tundra level. Jose cut remaining tabs and AFC flew remaining piece of conductor, casings and tubing out of the hole. GBR welder Steve chipped cement and prepped the top of the cuts for marker plate. Topped off with Portland Type I/II Cement. Let cement cure,verified with pictures before welding marker plate on. Backfilled structural pipe cellar with gravel. Removed structural pipe cellar with vibrator and crane. Compacted with loader. Surveyors Came to remark and verify well#38 location marks. KUP DISP ! 2M-23 Conoc©Phdkps UWell Attributes Max Angle&MD TD Aia"k'1 lrtt: Wellbore API/UWI Field Name Wellbore Status ncl(3 Me(ftKB) Act Btm(ftKB) con.,: pu 501032015500 KUPARUK RIVER UNIT DISP 51.30 2,675.00 3,535.0 ..- Comment 1425(ppm) Data Annotation End Date KB-Grd(ft) Rig Release Date 2M-23,7120/2016 100825 AM SSSV'.NONE Last WO: 4/7/1991 veNcal schemata(acwaq. Annotation Depth(ftKB) End Data Annotation Last Mod By End Date Last Tag' 1,501.0 6/20/1998 Rev Reason:PERMANENT P&A,SEE NOTES pproven 7/10/2016 Casing Strings Casing Description OD(in) ID 0n) Top.(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.060 51.0 115.0 115.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(NO)...WVLen(I...Grade Top Thread SURFACE 9 5/8 8.921 51.0 3,514.9 2,839.8 36.00 J-55 BTC ,.i ,13:.: Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WVLen(1...Grade Top Thread RODUC7 6.276 51.0 1,524.4 1,486.5 26.00 J-55 BTC :.1 r CPirculationTION String 4 Tubing Strings I •�II Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connect on b TUBING 27/8 2.441 51.0 1,663.5 1,604.6 6.50 J-55 EUE8rd Completion Details Nominal ID rf0fist42 S Top(ftKB) Top(ND)(ftKB) Top Incl(') Item Des Com (in) 33 a� „„&: 51.0 51.0 0.00 HANGER FMC TUBING HANGER. 3.400 rt :;:. 1,619.3 1,567.8 32.80 LOCATOR BAKER LOCATOR 2.440 ,. 1,620.2 1,568.5 32.83 PACKER BAKER'D'PACKER 3.250 1,661.9 1,603.3 34.37 NIPPLE CAMCO'D'NIPPLE 2.250 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Ind Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) ANCONDUCTOR;51.0-115.0 �.) 30.0 30.0 0.00 CEMENT PUMPED 120 BBLS OF 15.7 PPG AS1 CEMENT 5/21/2012 6.276 CEMENT;30.0 . DOWN THE IA TAKING RETURNS FROM THE OA ~, ' UNTIL PURE CEMENT TO SURFACE. 5. 1,338.0 1,318.6 21.95 TBG PERFORATED TUBING w/1-9/16"TITAN,4 SPF,0 4/19/2012 2.441 TBG PUNCHES;1,338.0 '` PUNCHES DEG PHASE,DECENTRALIZED ,. ''*r@ w .�.^" 1,400.0 1,375.6 24.43 RETAINER INFLATABLE CEMENT RETAINER,PUMPED 34.4 4/10/2012 0.000 BBLS OF 15.78 AS1 BELOW RETAINER CEMENT;51.0 ftlB •* 2214.0 2,005.3 48.04 PLUG Baker BRIDGE PLUG 4/7/1991 0.000 7" a&' Perforations&Slots Shot .,,:,:,.....-.:..1.1.:„......:::..,':...!..::.:..: Dene RETAINER;1,400.0 Top(ND) Btm(TVD) (shotsk Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com ,,nali=i1M4 M4 a' 1,976.0 1,989.0 1,844.0 1,853.1 UGNU,2M-23 4/8/1991 2.0 IPERF Dyna Strip;UGNU Zone a PRODUCTION Circulation ti 'a w y� Cement Squeezes String;51.0-1524.4 , , ,.>'`., +b Top(ND) Btm(ND) 1,,,,,,,.,:).;: "4ti Top(ftKB) BM(ftKB) (ftKB) (ftKB) Des Start Date Com .a) 2' 51.0 1,362.0 51.0 1,340.8 CEMENT 5/21/2012 I, h "a"•; 51.0 1,599.4 51.0 1,551.0 CEMENT 5/21/2012 ff,°'. 1,362.0 2,214.0 1,340.8 2,005.3 CEMENT 1/1/2016 Mandrel Inserts GAS LIFT;1,5732 St as ° Top(ND) Valve Latch Port Size TRO Run J11- N Top(ftKB) (ftKB( Make Model OD(in) Sew Type Type (in) (psi) Run Date Com 1 1,573.2 1,528.7 MERLA TGPD 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/7/1991 ..... -. •• Notes:General&Safety End Date Annotation cEnnENr,51 a(IKa 1 r 9/29/2000 NOTE:PROD string acts as a circulation string for freeze protection 9/29/2000 NOTE:IA&OA am in direct Communication and provide a fluid flow path 9/29/2000 NOTE:Class 2 Dispoisal well;7"Production String is open-ended 10/30/2010 NOTE:View Schematic w/Alaska Schematic9.0 5/21/2011 NOTE:UNABLE TO WORK PAST OBSTRUCTION @ 1500'SLM. • PACKER,1,6202 4/14/2012 NOTE.TAGGED TOC @ 1362'SLM ae 6/26/2016 NOTE:P&A MARKER WELDED ON CASING •..,.. 6/26/2016 NOTE:PERMANENT P&A,WELLHEAD AND CASING REMOVED 9'below Tundra LEVEL 1 NIPPLE,1,661.9 qi,,., IPERF;1,976.0-1,989.0-. ► CEMENT;1,382.018(8 PLUG;2,214.0 iSURFACE,51.0-3,514.9- [ VOF 77t, • • Iyyys, THE STATE Alaska Oil and Gas of 1 ® Conservation Commission t` = 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 "*. Main: 907.279.1433 OF AL AS Fax: 907.276.7542 www.aogcc.alaska.gov Jim Simek OD JAN 0 9 2.017, Staff Well Integrity Engineer Sati Conoco Phillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Cretaceous U WDSP, KRU 2M-23 Permit to Drill Number: 191-034 Sundry Number: 316-308 Dear Ms. Simek: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair DATED this /U "aay of June, 2016. RBDMS L SUN 1 3 2016 • • RECEIVED • • STATE OF ALASKA JUN 0 3 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION OTS 6/la//.. APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon F Plug Perforations r Fracture Stimulate,, Repair Well Operations Shutdown Suspend ) Perforate FOther Stimulate Pull Tubing F' Change Approved Program T Plug for Redrill FT Perforate New Pool r Re-enter Susp Well I— Alter Casing F! Other: FT 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory T Development 1 -' 191-034` 3.Address: ri pt, 6.API Number: Stratigraphic Service P.O.Box 100360,Anchorage,Alaska 99510 50-103-20155-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? n/a Will planned perforations require a spacing exception? Yes r No F ✓ KRU 2M-23 9.Property Designation(Lease Number): 10.Field/Pool(s): U, WAS? / ADL 25586 • Kuparuk River Field/Kupartuk it root 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): 3,550' 2,862' 0 cement to surface n/a Casing Length Size MD TVD Burst Collapse Conductor 79' 16" 115' 115' Surface 3,480' 9 5/8 3,515' 2,840' Production 1,491' 7" 1,524' 1,486' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 1976-1989 1844-1853 2.875" J-55 1,643' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-BAKER'D'PACKER MD=1599 TVD=1551 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory FT Stratigraphic 1— Development FT Service F • 14.Estimated Date for 6/17/2016 15.Well Status after proposed work: Commencing Operations: OIL F-. WINJ F WDSPL r— Suspended T 16.Verbal Approval: Date: GAS FT WAG FT GSTOR FY• SPLUG FT Commission Representative: GINJ Ti Op Shutdown FT Abandoned F . 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Jill Simek @ 263-4131 Email Jill.Simek@conocophillips.com Printed Name Jill Simek Title Staff Well Integrity Engineer 6/2.11 Signature Phone 263-4131 Date r COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: \Lt— 0V Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: Post Initial Injection MIT Req'd? Yes ❑ No RBDMS \-- 'JUN 1 3 2016 Spacing Exception Required? Yes ❑ No E Subsequent Form Required: it 12 — .4 U APPROVED BY Approved by: P i, COMMISSIONER THE COMMISSION Date: 6_�0,,// y l ��6/t1'/ I� dI .it iiiSubmit Form and Form 10-403 Revised 11/2015 a p olid for 12 months from the date of approval. Attachments in Duplicate • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 1 June 2016 JUN 0 3 2016 Commissioner AOGCC State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby applies for an Application for Sundry Approval to abandon KRU 2M- 23 (PTD#: 191-034). The well is currently suspended with cement to surface. Per the attached procedure, abandonment operations will be performed to excavate 4ft below original ground level, remove wellhead and cellar, perform "top up" cement job, weld cover plate, and backfill to ground level. ✓ If you have any questions or require any further information,please contact me at 263-4131. Sincerely, r•-• 5.11 OSimek Well Integrity Engineer CPAI Drilling and Wells • • IIPPV ConocoPhillips KRU 2M-23 Permit to Drill #: 191-034 The objective of the proposed 2M-23 abandonment is to cut casing and tubing strings below grade and remove wellhead/tree. Wellhead Excavation /Final Abandonment: 1. Remove the Well House (if still installed). 2. Bleed off T/I/O to ensure all pressure is bled off the system. 3. Remove the tree, in preparation for the excavation and casing cut. 4. If shallow thaw conditions are found, have shoring box installed during the excavation activity to prevent lose ground from falling into the excavation. 5. Cut off the wellhead and all casing strings at 4 feet below original ground level. uv- ho ti 11-ab CC- Fwr 1-11r55 pj ciJ 6. Perform TopIab and verify that cement is at surface in all strings. AOGCC witness and photo document required. 7. Send the casing head w/stub to materials shop. Photo document. 8. Weld %" thick cover plate (16" O.D.) over all casing strings with the following information bead welded into the top. Photo document. AOGCC Witness Required. ConocoPhillips 2M-23 PTD # 191-034 API # 50-103-20155-00 9. Remove Cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 10. Obtain site clearance approval from AOGCC. RDMO. 11. Report the Final P&A has been completed to the AOGCC, and any other agencies required. Photo document final location condition after all work is completed. JS • • Schematic: v. KUP DSP 2M-23 Conoco (hips 1= .well Athtniues Max sem.&MO TO An^.. n iG_ WNIOore APW1VI Fie.Name Wetbore Std.s ncl l'1 MC faKell A4 atm l/d/E) �6Cayya# 5010824155IX1 KUPAR,I1R-ERt±t.R D':P f 011.30 2576.00 3.5350 ... Come* 3125 toot,* Date Annabel. End Date KE-Ord tm Fq Release Dae 2/5.3.CO,2016 2.IS 55C, 5.5551NONE LAM NO: 4/711931 tier...ai a:m.......a.....x. Mentation 0.0. ) Ery Dae Annotation .Mod Gy End Date Last T. 150'2 820/1558 Rea Reason.ADD 3558/7 mom 10/82012 Casing Strings Caewap Desonpao^ 2X3 toll Oiml ToprroARI let Depth#88) Set Depth RYD1..,WULen;I..Grade Top Thread CONDUCTOR 16 15.060 360 /150 1150 62501440 WOWED 1.11 Canna Deaonp5t'l 2O On) Of* Tap(8891 Set Depth(RK.) Set Dept(TSD)--.WOten(1...Grade Top Thread S1/RFACE 95/8 8 921 35.0. 3.5149 2,839 8 36 00.L55 Bit Damp Des.ryhoa CO a+) 911.) Tap(Ally Set Depth droll) Set Dem/9411...WdLen D...Gla& UP Tnre.0 I■ii- PRDOIX/TIGt1 5_276 330. 1..5244 1,4665 26 CID.-55 BTC 1" 00157.860 Stnrg ■as= Tubing St hats '301190CGmtlo '''''''-',4;.E am'a11 5 O 4812 48 "4p 119) 3 Set Dep82 P..SeDevr.54 W'185 0 G5d. TEEL 0106o Completion Details A lbminai?° 2500OWN Tol(TVD)OMR; lop i 3fy Rem Des Com tmi Il r X3 30.3 300/o.'iGER 0593 Til 35*+•3ER 3400 1.588.E 1,5503 3303 LOCATOR 84KER DI.ATCR 2440 i5584 1.551.0 3..35 PACKER 6AKER V PACKER 3.250 1.641.2 ?56x'-t 2361 1.13"LE CAA/CD 40PLE 2.2'.10 Other SO MDIe Olnnanne relnembie plugs.valves.pumps,fish, .) ,,,*(TVD) Tap Md. ' ` Tap w' tC' 4£9415 CI 1 nea Coal Fan Dae O{n) A 30.4 300 0.804'f5E14T PLASPE-T24 Bill 5 07/.5.7 PP^G AS1 CESAE.NT 53252012 8.276 L1C0681 T1¢3r5 T4,554C 9 T CRe,6,FROM 101E CIA LINTY FLARE ca-11I71 TS.SURFACE. 1.318.0 1.31105 21,411304 PERFORATED T'irafaGo.1-3/8.TITAN.4 SPF,6 4.19301? :4411 FRINCtf4 AEG P1/ASE 01E50/50RAL.150 .....,,4.0...4."laTN19 15 - 1,4211.0 _"135 5 24,43$TA9ER *Mauna 009 M RETAINER,RUM+E030.4 4/1012012 0.EEO 030.3 OF t 3A/I AEI PE¢:etfi RETAp£R 89.801:IOF ..r: 10aw 14 ^1 L.K. "^a+e =2L!-.. 447f994 0:1,00 'tillial 5$4 8/91/1/ai:02124 s` {Y.'S.'SS, " Spee Doss 1 .4,,,,.„ laQom/p zw sac.iltr :e8 .aae tenets,' n i Type Con 94 *0 1 5[ '"7 "i$2 ...1 :Ie.:, 4.10991 2 0 I51R8 03/705119SY 1E on Mined*,/$14 t . es}MT105gpsze,zfsnp a2pla:etreraa'trt¢aeen 0 05 95/12 224411 1.X45 20415.4 05:9E/71 4/x9410'.5=a a '3 ,440 1 3W D :140 1,3400 CEMENT ENT S2/012 5505 05 ., 5165/1£5 •are3) 1551 U calm Sal.)2012 s ! 1• C on b.mat vi,, t.% An Sire 19109., 114e3.W!'.6a0a 91 V111111�) Y1.89i Mae 8owi t81e?t Sore _ Type Tl2p. i0) 1001 Rw Dan tm :tu.:.. Ami. �70Fn 1'.:0.. LET 11,4 RK L2.CC v.0 47'^991 8 Safely End Daae Annotation 0150:`016 '40 :As55:.3x005/'54 wH f,Pr.u.mian StTaKl isz.pel2tRk1 0d:NICI/0/ 1401E IA936we. 314 Lor'r11.111.1.1 and pep le a f.0 flow Dalt 852.41130 NO10:PROD aaD5 ads.0 cra.d'Unn sadap fort/tem 5£4000005 St t14311,:09D NtOTE:1'1aW Schematic 01ATs4ta Sd>ems.4i1.0 -`° fY 0/2fL1111 NATE'INANE 10WORN PAM C 3,1RLICTk6d 01:510'SY).1. :..._-. ....- 171447.l72 NDTE'.TAC9GEUTDC a 1981 SIM • )IPAt0,tlw1A PRA/;/,9TSA9.SMna- 8/11916094* SielFACe:3515,1531,1,41 . Js STATE OF ALASKA AL&OIL AND GAS CONSERVATION CO SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r RugPerforations Pull Tubing Fracture Stimulate Operations shutdown "' Performed: Suspend r Perforate p r Other Stimulate r- Alter Casing r Change Approved Program Rug for Redrill rPerforate New Pool r5-0 Repair Well r Re-enter Susp Well rOther:Susp Well Insp 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 191-034 3.Address: 6.API Number: Stratigraphic r Service 17 P. O. Box 100360,Anchorage,Alaska 99510 50-103-20155-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25586 KRU 2M-23 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NA Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 3550 feet Plugs(measured) true vertical 2862 feet Junk(measured) Effective Depth measured 0 feet Packer(measured) 1599 true vertical 0 feet (true vertical) 1551 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 115 115 1640 630 SURFACE 3480 9 5/8 3515 2840 3520 2020 PRODUCTION 1491 7 1524 1486 4980 4330 Perforation depth: Measured depth: 1976-1989' e3 NOV 1 27_015 True Vertical Depth: 1843-1853' C AUG 12 2015 Tubing(size,grade,MD,and TVD) 2.875,J-55, 1641 MD, 1586 TVD X��°qq /"GC� C Packers&SSSV(type,MD,and TVD) PACKER=BAKER'D' PACKER @ 1599 MD and 1551 TVD SSSV=NONE 12.Stimulation or cement squeeze summary: NA Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 1 Exploratory r Development r Service J Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Rectronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: NA Contact MJ Loveland/Martin Walters Email n1878(c�conocophillips.com Printed Name Martin Walters Title Well Integrity Supervisor Signature / 4Ve /Z,Cat il Phone:659-7043 Date:Aug 7, 2015 t77-1- 4/z ' //sj RBDMQZ AUG 1 4 2015 Form 10-404 Revised 5/2015 Submit Original Only • • ConocoPhillips AUGE122015 Alaska A. �r P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 August 7, 2015 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Suspended Well Inspection 10-404 Sundry Kuparuk River Unit 2M-23 (PTD 191-034) Dear Commissioner Foerster: Enclosed please find the quinquennial suspended well inspection documentation as required by 20 AAC 25.110 for ConocoPhillips Alaska, Inc. Kuparuk River Unit well 2M-23 (PTD 191-034). The following documents are attached: - 10-404 Sundry - Suspended Well Check List - Wellbore Schematic - Location Plot Plan - Photographs Please call MJ Loveland or me at 659-7043 if you have any questions. Sincerely, M'aik/'7k1iii/ -. Martin Walters ConocoPhillips Well Integrity Projects Supervisor • • Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: KUPARUK RIV UNIT 2M-23 Field/Pool: KUP RIV/CRETACEOUS U WDSP Permit#(PTD): 191-034 Sundry 312-097 API Number: 50-103-20155-00 Operator: ConocoPhillips Alaska, Inc. Date Suspended: 5/21/2012 Surface Location: 114' FSL, 529' FWL Section: 29 Township: 11N Range: 8E Nearest active pad or road: KRU DS2M Meridian: UMIAT Take to Location Digital camera Map showing well location/Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Good Pad or location surface: Good Location cleanup needed: None Pits condition: Good Surrounding area condition: Good Water/fluids on pad: No Discoloration, Sheens on pad, pits or water: None Samples taken: None Access road condition: Good Photographs taken (#and description): None Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2)well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: Good Cellar description, condition, fluids: Good Rat Hole: NA Wellhouse or protective barriers: Removed for summer Well identification sign: Tubing Pressure (or casing if no tubing): 0 Annulus pressures: 0/0 Wellhead Photos taken (#and description): 2 of wellhead and cellar Work Required: None �--�� Operator Rep (name and signature): Martin Walters i t* - //00 AOGCC Inspector: Johnnie Hill Other Observers: Inspection Date: 8/7/2015 AOGCC Notice Date: 8/3/2015 Time of arrival: 9:20 AM Time of Departure: 9:28 AM Site access method: Passenger Truck KUP • 2M-23 • Conocophilhips Well Attributes Max Angle&MD TD ( ' A Wellbore API/UWI Field Name Well Status Incl(°) MO(ftKB) Act Btm(ftKB) Alaska. conocaatsikps elf 501032015500 KUPARUK RIVER UNIT DISP 51.30 2,675.00 3,535.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date "' SSSV:NONE Last WO: 4/7/1991 Well Como:-2M-23,10/8/2012 2 48 13 PM - Schemalk-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: 1,501.0 6/20/1998 Rev Reason:ADD CEMENT ninam 10/8/2012 Casing Strings Casing Description String 0... String ID...Top(ORB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd CONDUCTOR 16 15.060 36.0 115.0 115.0 62.50 H-40 WELDED Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd SURFACE 95/8 8.921 35.0 3,514.9 36.00 J-55 BTC Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd PRODUCTION 7 6.276 33.0 1,524.4 1,486.1 26.00 J-55 BTC Circulation String Tubing Strings § Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd IF TUBING _ 27/8 2.441 30.3 1,642.7 1,587.4 6.50 J-55 EUE8rd Corn.letion Details w:. Top Depth (TVD) Top led Noma... Top(ftKB) (RKB) e, Item Description Comment ID(In) 1 ' 30.3 30.3 -5.89 HANGER FMC TUBING HANGER 3.400 1,598.6 1,549.7 32.03 LOCATOR BAKER LOCATOR 2.440 1,599.4 1,550.4 32.06 PACKER BAKER'D'PACKER 3.250 1,641.2 1,586.1 33.61 NIPPLE CAMCO'D'NIPPLE 2.250 Other In Hole(Wireline retrievable plugs,valves,pkinsultati,etc.) Top Depth (TVD) Top Incl Top(ftKB) (KKR) C) Description Comment Run Date ID(in) MIS g 30 30.0 -5.89 CEMENT PUMPED 120 BBLS OF 15.7 PPG AS1 CEMENT DOWN 5/21/2012 6.276 THE IA TAKING RETURNS FROM THE OA UNTIL PURE CEMENT TO SURFACE. CONDUCTOR, 1,338 1,316.4 22.35 TBG PERFORATED TUBING w/1-9/16"TITAN,4 SPF,0 DEG 4/19/2012 2.441 36-115 PUNCHES PHASE,DECENTRALIZED CEMENT,30 1,400 1,374.9 24.65 RETAINER INFLATABLE CEMENT RETAINER,PUMPED 34.4 BBLS 4/10/2012 0.000 t'; ''.. OF 15.78 AS1 BELOW RETAINER TBG PUNCHES, ?! 2,2141 2,005.3 47.97 PLUG Baker BRIDGE PLUG 4/7/1991 0.000 1,338 I Perforations&Slots Shot ---— CEMENT,33 Top(TVD) Btm(TVD) Dens Top(ftKB)Btm(ftKB) (RKB) (ftKB) Zone Date (.h-• Type Comment 1,976 1,989 1,843.3 1,852.7 UGNU,2M-23 4/8/1991 2.0 IPERF Dyna Strip;UGNU Zone RETAINER, Notes:General&Safety 1,400 End Date Annotation 9/29/2000 NOTE:PROD string acts as a circulation string for freeze protection 9/29/2000 NOTE:IA 8 OA are in direct communication and provide a fluid flow path PRODUCTION uTIOn 9/29/2000 NOTE:Class 2 Dis olsal well;7'Production Stun Is open-ended Circulation P 9 P String,331524 10/30/2010 NOTE:View Schematic w/Alaska Schematic9.0 1 5/21/2011 NOTE:UNABLE TO WORK PAST OBSTRUCTION @ 1500'SLM. 4/14/2012 ;NOTE:TAGGED TOC @ 1362'SLM GAS LIFT, 1,553 I IL CEMENT,35 _ PACKER,1,599 I I I NIPPLE,1,641 li IPERF, 1,976-1,989 . • N 0 W m a' Ln' oo ee Z LLI O -p d. ca UT ch U0LI Nw o 3 N v-r O UEO U O w Z Q c a w ° aJLJZoc.' wLE pJctQ o acr o ° 0 ° o 0 121 V) -=v ai ai z o a N ct m N °o*°' p w w c°'a a w a P X < ce =OZ O,-- 8 W 0 41 ® ►. 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Phone: 659-7043 Location Verified? Yes Oper.Email: n1878@conocophillips.com_ If Verified, How? LAT/LONG Onshore/Offshore: Onshore Suspension Date: 05/21/12 Date AOGCC Notified: 08/03/15 - Sundry No.: 312-097 Type of Inspection: Initial Wellbore Diagram Avail.? No Well Pressures(psi): Tubing 0 Photos Taken? Yes IA 0 OA 0 Condition of WANED SEP 0 6 2015. Wellhead: good Condition of Surrounding Surface Location: good gravel Follow Up Actions Needed: none Comments: well was verified by pad well location map - Attachments: Photos(2) REVIEWED BY: Insp.Supry J CIL U I16l s Comm PLB 06/2014 2015-0808_Suspend_KRU_2M-23jh.xlsx • • Suspended Well Inspection—KRU 2M-23 PTD 1910340 Photos by AOGCC Inspector J. Hill 8/8/2015 ."rte.17' - + � z4 < p sr- s • a a 4M t, ConocoPhillips Rlt�ska ell Name: 218-23 PI Number. E :°;: 11.11 E Sur.Lecatien: Sec. 27,111N,RBE,at ! \ , 1 VIP • • 1116. a '441 ....„ el c:u:.1 \r s.77.7*--,ipmilir, Tr, --- r .-7-_---_ _ ., C n-. .. maw , 2015-0808_Suspend_KRU_2M-23photosJj h.docx · XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. Iff 1'" ~ ~ File Number of Well History File PAGES TO DELETE RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts.- Pages: Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA Diskettes, No. Other, No/Type OVERSIZED Logs.of vadous kinds . [] Other Complete COMMENTS: Scanned by: Dianna Vincent Nathan Lowell .. Date: ¢ o)... ¢ ~.ls/~ TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: /si UNSCANNED, OVERSIZED MATERIALS AVAILABLE: FILE # . , ~~ To request any/all of the above information, please contact: Alaska Oil & Gas Conservation Commission j 333 W. 7th Ave., Ste. 100 k Anchorage, Alaska 99501 Voice (907) 279-1433 -Fax (907) 276-7542 . STATE OF ALASKA AL. OIL AND GAS CONSERVATION COMIlt SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Rug Perforations r Perforate r Other ,, suspended inspection Alter Casing r Pull Tubing r Stimulate - Frac r Waiver r Time Extension r Change Approved Program rOperat. Shutdow n r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: u' 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 191 -034 3. Address: 6. API Number: V P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service 50- 103 - 20155 -00 7. Property Designation (Lease Number): ✓ 8. Well Name and Number: V' ADL 25586 2M -23 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): Kuparuk River Field / Cretaceous U Disp 11. Present Well Condition Summary: Total Depth measured 3535 feet Plugs (measured) 30, 1400, 2214 true vertical 2853 feet Junk (measured) None Effective Depth measured Surface feet Packer (measured) 30, 1338, 1400, 1599, 2214 true vertical Surface feet (true vertical) 30, 1319, 1376, 1551, 2005 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 115 115 PRODUCTION 1491 7 1524 1486 RECEIVEED SURFACE 3480 12 3515 2810 MAY 0 6 2013 L SCANNED JUL 1 G 2 °13 Perforation depth: Measured depth: Cemented to surface True Vertical Depth: Cemeneted to surface Tubing (size, grade, MD, and TVD) 2.875, J -55, 1641 MD, 1586 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER 'D' PACKER @ 1599 MD and 1551 TVD No SSSV 12. Stimulation or cement squeeze summary: NA Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service W Stratigraphic r 16. Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations X GSTOR r WIND r WAG r GINJ r SUSP W SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact MJ Loveland /Martin Walters Email n1878 ci7i conocophillips.com Printed Name MJ Loveland Titi4 Well Integrity Project Supervisor Signature / / Phone: 659 -7043 Date ©6.--Ma y/� VL-F RBDMS MAY - 9 20 • 22T� Form 10 -404 Revised 10/2012 �, /� U Su mit Orig l y • • ConocoPh MAY 0 7 2.0 i Alaska 40GCC P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 May 4, 2013 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Re: Suspended Well Inspection 10 -404 Sundry Kuparuk River Unit 2M -23 (PTD 191 -034) Dear Commissioner Seamount: Enclosed please find the first of the required quinquennial suspended well inspection documentation as required by 20 AAC 25.110 for ConocoPhillips Alaska, Inc. Kuparuk River Unit well 2M-23 (PTD 191 -034). This well was suspended with cement to surface May 21, 2012. The following documents are attached: - 10 -404 Sundry - Suspended Well Site Inspection Form - Wellbore Schematic - Location Plot Plan - Photographs - Waived witness notification from Inspector Please call Martin Walters or me at 659 -7043 if you have any questions. / , Sincerely, 7/ _ :vt____y MJ Lov and ConocoPhillips Well Integrity Projects Supervisor CAUTION IS f or / //////////////////////// / / / / / / / / 2 SPACES / / / / / / / / / / / / / / / / / / /�' —,Oe —� IDE DRILL BE D. 21 Acmes Rd 4 SPACES O 12.5-25' ES ' 1 o15' - 6 0' 8 SPAC //.:.'.'.'; . , O. 2 0 12.5' -75' 6 SPACES 25 I 25' 10 SPACES 25'25' 45' 45' 25' 25' I O 25' -150' 15' TO 2 —, KI lo N 99 98 � fl � j 3435 20 22 24 I 2g 27 2 5 7 8 x xxx xx xxx x x x —TAUS —xx x A Id 000 0 00 000 0 o 0c Ili) @A - ` � " x XX XX X x0XX XX Of xgxx � '• >' 1 : I 32 3 : 2: I 4 6 :I s 1 1 ' 0 1 c 1 1. 1. 171 19 2 23 2) 26 r m i � � . Y M. ] CT Sao —1 ■ • PROD .. ' ••,, MCD BEC CTRL •. Y RESERVE PIT LAUNCHER :. �Y METH TANK i S O. �(T�) GUARDRAIL Now PROD HEA ,• CTRL •.. \ C'ULVERT � PIG �r ' PIT i 1 TARN 2111 PIPELINES PIPELINES POWERLINES ■+ wm. FEATURE LOCATIONS LEGEND ® EXISTING PRODUCER • • EXISTING INJECTOR LEGEND ® CONVERTED FROM PRODUCER TO INJECTOR r A - CLEAN SNOW DUMP AREA, ALL EQUIPMENT. IN RESCUE EQUIPMENT I ABANDONED CONDUCTOR * ems - ENVIRONMENTAL AREA -NO SNOW DUMPING. SCBA LOCATIONS NOTE X EXISTING CONDUCTOR POWERLINE -WATCH CLEARANCE!!, KODIAK 1 1 1 DESIGNATED SAFE AREA (PRIMARY) Tj map - ® PARTIAL TREE BLOWERS MAY HIT LINES WITH DISCHARGE. 1 1 DESIGNATED SAFE AREA (SECONDARY) NO SNOW IS TO BE PLACED IN ,> ∎j��•, >-) - KODIAK BLOWERS MAY DISCHARGE OVER EVACUATION ROUTES DEPENDING ON WIND ANY RESERVE PIT OR LINED PIT. PIPELINES. R 1 MOM — NO SNOW DUMPING AREA. WINDSOCK ® BARRICADE /ESCAPE ROUTE Ca AREA: 2M MODULE:XXXX UNIT: D2 / LOUNSBURY, INC I „P FIRE EXTINGUISHER I APPROVAL: DS2M FACILITY EXPANSION 4 5/30/01 Add Tarn Pipeline,Update Title elk, Rev Per K01039ACS ROL MR1 DATE 10/26/96 CADD FILE: LK621311 FEATURE LOCATION 3 8/01/98 Rev Per K98058ACS, Add DS2L Access Rd. MRT JB DRAWING NO. Z SHEET: REV: NO APP DATE REVISIONS BY CHK JOB PPR uC, __L1L,,,, -3322 001 4 v ,. KUP 2M -23 ConocoPhillips Well Attributes Max Angle & MD TD Ak3S ( 11C Wellbore API /UWI Field Name Well Status Ind ( °) MD (ftKB) Act Btrn (MB) corbcnPllrnp: 501032015500 KUPARUK RIVER UNIT DISP . 51.30 2,675.00 3,535.0 " Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date SSSV: NONE Last WO: 4/7/1991 Well Coniiq: - 2M -23, 10/8/2012 2:48'.13 PM - - -- Schematic- Actual Annotation Depth (ftKB) End Date Annotation Last MOtl ... Entl Date Last Tag: 1,501.0 6/20/1998 Rev Reason: ADD CEMENT ninam 10/8/2012 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.060 36.0 115.0 115.0 62.50 H WELDED 1. Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.921 35.0 3,514.9 36.00 J - 55 BTC I , Casing Description Stri 0... String ID ... Top ( ftKB ) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrtl PRODUCTION 7 6.276 33.0 1,524.4 1,486.1 26.00 J -55 BTC Circulation String Tubing Strings �," Tubing Description String 0... String ID .. Tap (ftKB) I Set Depth (f... I Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 27/8 2.441 30,3 I 1,642.7 1,587,4 6.50 J -55 EUE8rd Completion Details I Top Depth' (ND) Top Teel Need... Top (ftKB) (ftKB) ( °) Item Description Comment _ ID (in) t ' 30.3 30.3 5.89 HANGER FMC TUBING HANGER 3.400 1,598.6 1,549.7 32.03 LOCATOR BAKER LOCATOR 2.440 3.250 2.250 1,599.4 1,550.4 32.06 PACKER BAKER 'D' PACKER 1,641.2 1,586.1 33.61 NIPPLE CAMCO'D' NIPPLE - - Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) _ Top Depth (ND) Top Inc! I,. Top (ftKB) (ftKB) (°) Description Comment Run Date ID (in) 30 30.0 -5.89 CEMENT PUMPED 120 BBLS OF 15.7 PPG AS1 CEMENT DOWN 5/21/2012 6.276 THE IA TAKING RETURNS FROM THE OA UNTIL PURE CEMENT TO SURFACE. CONDUCTOR, 1,338 1,316.4 22.35 TBG PERFORATED TUBING w/ 1- 9/16" TITAN, 4 SPF, 0 DEG 4/19/2012 2.441 30 - PUNCHES PHASE, DECENTRALIZED CEMENT, 30 1, 400 1, 24 RETAINER INFLATABLE CEMENT RETAINER, PUMPED 34.4 BBLS 4/10/2012 0.000 OF 15.78 AS1 BELOW RETAINER TBG PUNCHES, 2,214 2,005.3 47.97 PLUG Baker BRIDGE PLUG 4/7/1991 0.000 1,339 Perforations & Slots Shot CEMENT, 33 Top (ND) Btm (ND) Dens Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date ( Type Comment 1,976 1,989 1,843.3 1,852.7 UGNU 2M -23 4/8/1991 2.0 IPERF Dyna Strip: UGNU Zone RETAINER, .e e ral & Safety 1400 End Date Annotation 9 292000 NOTE: PROD string acts as a circulation string for freeze protection I 9/29/2000 NOTE: IA 8 OA are in direct communication and provide a fluid flow path PRODUCTION 9/29/2000 oi Production Std P . n9 is 000 NOTE: Class 2 Dis sal well; 7" open-ended PRODUCTION P String 331524 10/30/2010 NOTE: View Schematic w/ Alaska Schematic9.0 1 5/21/2011 NOTE: UNABLE TO WORK PAST OBSTRUCTION @ 1500' SLM. I t 4/14/2012 NOTE: TAGGED TOC @ 1362' SLM GAS LIFT. 1,553 I CEMENT, 35 Vie: PACKER, 1,599 L I I NIPPLE, 1,641 11 IPERF, 1,976 -1.989 = -- Top Depth Top CEMENT, Port 1 362 (ND) Ind OD Valve Latch Size TRO Run PLUG, 2,214 Stn Top (ftKB) (ftKB) P) Make Model (In) Sery Type Type On) (PM) Run Date Com... 1 1,552.5 1,509.9 30.32 MERLA TGPD 1 12 GAS LIFT DMY RK 0.000 0.0 4/7/1991 SURFACE, 35- 3,515 TD, 3,535 • • • Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: Kuparuk Riv Unit 2M -23 Field /Pool: Kuparuk River /cretaceous U Dsp Permit # (PTD): 191 -034 Sundry 312 -097 API Number: 501032015500 Operator: ConocoPhillips Date Suspended: 10/11/2012 Surface Location: Section: 114' FSL, 529' FWL, Twsp: T11 N Range: R8E UM Nearest active pad or road: KRU DS2M Take to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Good no visible indication of leaks or wetness on tree or snow Pad or location surface: Snow covered - no discoloration Location cleanup needed: No Pits condition: NA Surrounding area condition: Good, Clean Active Pad Water /fluids on pad: No Discoloration, Sheens on pad, pits or water: No Samples taken: none Access road condition: Good Photographs taken (# and description): Yes 4 provided Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead /tree /valve description, condition: Good, All Valves functioned Cellar description, condition, fluids: Full of Snow Rat Hole: AN Wellhouse or protective barriers: No Well house, In a row of wells with houses on each side Well identification sign: Well Number Marked on Tubing Spool Adapter Tubing Pressure (or casing if no tubing): 0 psi Annulus pressures: IA = 0 psi, Could not get to OA due to Snow Wellhead Photos taken (# and description): Yes, Good Work Required: None Operator Rep (name and signature): Roger Winter, WI Fld Supervisor AOGCC Inspector: Jeff Turkington Waived witness Other Observers: None Inspection Date: 5/4/2013 AOGCC Notice Date: 5/1/2013 Time of arrival: 10:00 AM Time of Departure: 10:30 AM Site access method: Truck • , • __— ...... _sM ( , r it ir/ .., , 2M -23 191 -034 I ©ConocoPhillips Alaska, Inc This hoto is copyrighted b ConocoPhilli aska, Inc. p by P'' „ and cannot be released or published witho > press written consent of ConocoPhillips Alaska :�, x,. ...wwiww�F. +�.rrr��•wr.M�r siw wr 11111111111111111111111011 MR ow Lir Roe 1w s +• al, Si 1 • v n r i_ „ , • may( . ri! s / I , x 2M-23 2M-2319..034 ©ConocoPhillips Alaska, Inc lb This photo is copyrighted by ConocoPhillips Alaska, Inc. and cannot be released or published without express written consent of ConocoPhillips Alaska 2M -23 191 -034 ©ConocoPhillips Alaska, Inc � This photo is copyrighted by ConocoPhillips =. Alaska, Inc. and cannot be released or , published without express written consent u of ConocoPhillips Alaska • I 6 r 1 Ai • • , % Ilk e• - rir - • • i it .. .., ,.., „ .0:,.. :4.0. 1. ..,.. ,ri..4._ .. • 1 , _. , ili .. r .,.00.,„ v ,, .. Illik w 0 2M -23 191 -034 ©ConocoPhillips Alaska, Inc • This photo is copyrighted by ConocoPhillips Alaska, Inc. and cannot be released or published without express written consent of ConocoPhillips Alaska i { • NSK Well Integrity Proj From: Turkington, Jeff A (DOA) <jeff.turkington @alaska.gov> Sent: Thursday, May 02, 2013 5:08 PM To: NSK Well Integrity Proj; DOA AOGCC Prudhoe Bay Subject: [EXTERNAL]Re: AOGCC Test Witness Notification Request: Inspection, Kuparuk 2T -4, 5, 10, 11, 16 and 2M -23 Thanks for the notice. State witness is waived. Jeff Jeff Turkington Petroleum Inspector Alaska Oil and Gas Conservation Commission M 907 - 252 -1249 / 0 907 - 659 -2714 / F 907 - 659 -2717 jeff.turkingtonPalaska.gov From: MJ Loveland [ mailto :n1878@conocophillips.com] Sent: Wednesday, May 01, 2013 02:30 PM To: DOA AOGCC Prudhoe Bay Subject: AOGCC Test Witness Notification Request: Inspection, Kuparuk 2T -4, 5, 10, 11, 16 and 2M -23 Jotform Question Answer Type of Test Requested: Inspection Requested Time for 05 -04 -2013 10:00 AM Inspection Location Kuparuk 2T -4, 5, 10, 11, 16 and 2M -23 Name MJ Loveland E -mail n1878@conocophillips.com Phone Number (907) 659 -7043 Company CPAI Suspended Well Inspections on wells In field Kuparuk wells. Other Information: 2T -04, 2T -05, 2T -10, 2T -11, 2T -16, & 2M -23. Inspection date can be somewhat flexible. Submission ID: 233256628621333753 1 III STATE OF ALASKA • , ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended El • 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Service El' Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband.: May 21, 2012 191 - 034 / 312 - 097 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 April 2, 1991 50 103 - 20155 - 00' 4a. Location of Well (Govemmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 114' FSL, 529' FWL, Sec. 27, T11 N, RO8E, UM • April 3, 1991 2M - 23 • Top of Productive Horizon: 8. KB (ft above MSL): 140' RKB 15. Field /Pool(s): not applicable GL (ft above MSL): 105' AMSL /l Kuparuk River Field ?IL Total Depth: 9. Plug Back Depth (MD + TVD): Crkrad W - , (�. 6,51 AIM fr - - -3 1310' FSL, 1744' FWL, Sec. 27, T11 N, RO8E, UM surface 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 488369 y 5948986 Zone 4• • 3535' MD / 2853' TVD ADL 25586 • TPI: x - na y- na Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 489584 y 5950179 Zone 4 none 2672 18. Directional Survey: Yes ❑ No 111 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) • 1400' MD / 1392' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re drill /Lateral Top Window MD/TVD none not applicable 43 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 36' 115' 36' 115' 24" 230 sx AS III 9.625" 36# J -55 35' 3515' 35' 2840' 12.25" 1150 sx AS III, 985 sx Class G, 120 sx AS I 7" 26# J -55 33' 1524' 33' 1486' 8.5" not applicable 24. Open to production or injection? Yes ❑ No Q If Yes, list each 25. TUBING RECORD Interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET ( MD/TVD) 2.875" 1643' 1599' MD / 1550' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. RECEIVED hydraulic fracturing used during completion? Yes ❑ No Q DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED OCT 12 2012 1362' - 1984' 35 bbls of 15.7# AS 1 ` //�� °� ( ('"� 0 -1338' 120 bbls 15.7# AS I A OGCC 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) suspended Date of Test Hours Tested Production for OIL -BBL GAS -MCF WATER -BBL CHOKE SIZE GAS - OIL RATIO Test Period - -> Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL ., QUARAVITY - API (corr) Press. psi 24 -Hour Rate -> 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No 0 Sidewall Cores Acquired? Yes ❑ No Q If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. NONE SG NED MAR 0 6 2D13 AP' V3 OCT 15 2012 Form 10 - 407 Revised 10/2012 CONTINUED ON REVERSE ,4.1 :, ,j ' . only ,� ■12,- Submit 28. GEOLOGIC MARKERS (List all formations and mar cl —ers encountered): 29. • FORMATION TESTS NAME MD TVD Well tested? ❑ Yes El No If yes, list intervals and formations tested, Permafrost - Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom 1400' 1392' needed, and submit detailed test information per 20 AAC 25.071. not applicable N/A Formation at total depth: not applicable 30. LIST OF ATTACHMENTS — ctiertd 10 - -1 °h- Summary of Daily Operations, schematic tik 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tyson Wiese @ 263 - 4200 Email: Tyson.M.Wiese @conocophillips.com Printed Nam= r i / oward Gober Title: Wells Engineering Supervisor t �/ j� Signature o - etlt Phone 263 - 4220 Date ` 1 t J Z 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. 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. Item la: Classification of Service wells: Gas injection, water injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. 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 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level 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 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: 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 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and 1 analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 • 2M -23 Well Work Summary DATE SUMMARY • 3Y10/12 DRIFT WELL WITH 15' OF 2.25" DRIVE DN BAILER TO 1360' SLM. READY FOR E -LINE 4/2/12 RIH TO 1400' AND PERFORM 24 -ARM MIT CALIPER LOG TO SURFACE. DATA POSTED ON SERVER AND SENT TO ANCHORAGE FOR FURTHER PROCESSING. 4/5/12 ATTEMPTED TO SET RETAINER AND SQUEEZE CEMENT. WIND SPEED DISCONTINUED USE OF MANLIFT. FOUND MUTIPLE INTEGRITY ISSUES WHILE PRESSURE TESTING. RIGGED DOWN THE UNIT FOR THE NIGHT SO REPAIRS COULD BE MADE. JOB IN PROGRESS. 4/6/12 DELAYED START, WAITED ON VALVE SHOP AND ON WEATHER, PHASE 2 CALLED. RAN IN HOLE WITH INFLATABLE RETAINER TO 1420' CTMD. ATTEMPTED TO SET RETAINER. UNABLE TO GET VERIFICATION THAT BALL SEATED OR THAT DOV SHEARED. POOH TO INSPECT TOOLS AND FOUND THAT RETAIINER WAS LEFT IN WELL. CALLED FOR S/L TO FISH RETAINER. WELL FREEZE PROTECTED. JOB IN PROGRESS. 4/9/12 GAUGED AND BRUSHED TIGHT SPOTS @ 33' & 105' SLM TO 2.33, FISHED CEMENT RETAINER @ 1447' SLM ALL ELEMENTS AND STIFNER RING INTACT. JOB COMPLETE 4/10/12 DELAYED START DUE TO BOT & CEMENTERS STUCK BEHIND A RIG MOVE. RIG UP CMT RETAINER, RIH TO 1400' CTMD SET RETAINER, PUMPED 34.4 BBLS OF 15.7# AS1 CEMENT. RFLOW RETAINER, UNSTUNG FROM RETAINER AND LAYED IN .6 BBLS CMT HOLDING 1:1 RETURNS TO 1300' CTMD. F/P TUBING TO 1300' JOB IN PROGRESS, READY FOR SLICKLINE 4/14/12 TAG TOC @ 1362' SLM, CONDUCTED PASSING MITT & PASSING CMIT (IAxOA), READY FOR E -LINE. TAG AND BOTH MIT'S WERE STATE WITNESSED. 4/19/12 PERFORATED TUBING AT A DEPTH OF 1338'- 1343' USING 1- 9/16" GUN LOADED WITH 4 SPF, 0 DEG PHASING, TUBING PUNCH CHARGES. TUBING AND IA PRESSURES EQUALIZED AFTER SHOT WAS FIRED. LRS WILL VERIFY IF DESIRED CIRCULATION RATE WAS ACHIEVED. RIG DOWN AND TURN WELL OVER TO DSO. 4/20/12 Pumped 20 bbls diesel to tubing at 2 bpm at a max pressure of 1200 psi. Took returns from IA jumpered to 2M -24 flowline. 5/21/12 PUMPED 120 BBLS OF 15.7 PPG AS1 CEMENT DOWN IA TAKING RETURNS FROM THE OA UNTIL PURE CEMENT TO SURFACE. TAKE RETURNS FROM TBG UNTIL PURE CEMENT TO SURFACE. FLUSH TREE WITH .2 BBLS OF DIESEL PUMPED DOWN THE TBG. PUMPED .5 BBLS DOWN IA & OA TO FLUSH TREE VALVES. CEMENT CAN BE TESTED TO 1500 PSI AFTER 24 HOURS. 5/26/12 Performed MIT -T to 1460 -psi (PASS). Performed MIT -IA to 1600 -psi (FAIL). Performed MIT -OA to 1550 -psi (FAIL). 5/31/12 Performed MIT -IA to 1500 -psi (FAIL). Performed MIT -OA to 1500 -psi (FAIL). 9/11/12 BLED T, IA & OA TO 0 PSI. 9/20/12 BLEED IA AND OA TO 0 PSI FOR 60 MINUTE BUR (BOTH PASSED), STRAPPED TOC IN IA @ 14', TOC IN OA @ 14.5', BLEED T TO 0 PSI FOR 30 MINUTE BUR (PASSED) 1.--- ,q3 KUP 2M -23 , ConocoPhillips *ii.: = S Well Attributes Max Angle & MD TD A Wellbore API /UWI Field Name Well Status Inc! 0) MD (ftKB) Act Btm (ftKB) car,ocwt0hps 501032015500 KUPARUK RIVER UNIT DISP 51.30 2,675.00 3,535.0 Comment H2S (ppm) Date Annotation End Date KB -Grd (R) Rig Release Date - -- SSSV NONE Last WO: 4/7/1991 Well Conk' - 2M , 018!2012 2'.48:13 PM Schem 1 -Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag 1,501.0 6/20/1998 Rev Reason: ADD CEMENT ninam 10/8/2012 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.060 36.0 115.0 115.0 62.50 H WELDED Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.921 35.0 3,514.9 36.00 J - 55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (L.. Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 33.0 1,524.4 1,486.1 26.00 J -55 BTC Circulation String Tubing Strings Tubing Description String 0... String ID ... Top (RKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 27/8 2.441 30.3 1,642.7 1,587.4 6.50 J -55 EUE8rd Completion Details \ Top Depth (TVD) Top Intl Nomi... Top (ftKB) (RKB) 0) Item Description Comment ID (in) ' 30.3 30.3 -5.89 HANGER FMC TUBING HANGER 3.400 1,598.6 1,549.7 32.03 LOCATOR BAKER LOCATOR 2.440 1599.4 1,550.4 32.06 PACKER BAKER D' PACKER 3.250 1,641.2 1,586.1 33.61 NIPPLE CAMCO 1Y NIPPLE 2.250 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top Inc! Top (RKB) (ftKB) ( °) Deseription Comment Run Date ID (In) 30 30.0 -5.89 CEMENT PUMPED 120 BBLS OF 15.7 PPG AS1 CEMENT DOWN 5/21/2012 6.276 THE IA TAKING RETURNS FROM THE OA UNTIL PURE - CEMENT TO SURFACE. CONDUCTOR, 1,338 1,316.4 22.35 TBG PERFORATED TUBING w/ 1-9/16" TITAN, 4 SPF, 0 DEG 4/19/2012 2.441 38 - 115 PUNCHES PHASE, DECENTRALIZED CEMENT. 30 1,400 1,374.9 24.65 RETAINER INFLATABLE CEMENT RETAINER, PUMPED 34.4 BBLS 4/10/2012 0.000 OF 15.7# AS1 BELOW RETAINER TBG PUNCHES, y 2,214 2,005.3 47.97 PLUG Baker BRIDGE PLUG 4/7/1991 0.000 1,338 ° Perforations & Slots Shot CEMENT. 33 Top (TVD) Btm (TVD) Dens �= Top (ftKB) Btm (RKB) (566) (ftKB) Zone Date ( -• Type Comment 1,976 1,989 1,843.3 1,852.7 UGNU, 2M -23 4/8/1991 2.0 IPERF Dyna Strip; UGNU Zone Notes: General & Safety RETAINER, 1.400 End Date Annotation 9/29/2000 g NOTE: NOTE: IA 8 PROD OA are string in acts direct as communication circulation and strinfor provi freeze a protection fluid flow PRODUCTION 9/29/2000 path i 929!2000 NOTE: Class 2 Dis sal well; 7' Production Stri is open-ended Circulation Pa n9 P Suing, 33 - 1,524 10/3012010 NOTE: View Schematic w /Alaska a Schematic 5/21/2011 NOTE: UNABLE TO WORK PAST OBSTRUCTION © 1500' SLM. 4/14/2012 NOTE: TAGGED TOC @ 136Z SLM GAS LIFT, 1,553 I CEMENT.35 ::....--- PACKER, 1,599 NIPPLE. 1.641 it IPERF, -- 1,978- 1,989 - - -- - Mandrel Details Top Depth Top Port CEMENT, 1,382 (TVD) Inc! OD Valve Latch Size TRO Run PLUG, 2.214 Stn Top (RKB) (RKB) ( °) Make Model (in) Rent Type Type (in) (psi) Run Date Com... 1 1,552.5 1,509.9 30.32 MERLA TGPD 1 12 GAS LIFT DMY RK 0.000 0.0 4/7/1991 I SURFACE. 35 -3,515 TD, 3,835 • 191- 031- x`521 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. April 3, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multifinger Imaging Tool (MIT) : 2M -23 Run Date: 4/2/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2M -23 Digital Data (LAS), Digital Log file, Casing Inspectintrinfport, 3D Viewer 1 CD Rom 50- 103 - 20155 -00 , NNED JU `LU1'L PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: 5 Signed: 2k 5 p4i WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. April 20, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforation Record: 2M -23 Run Date: 4/19/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2M -23 Digital Data (LAS), Digital Log file 1 CD Rom 50- 103 - 20155 -00 WNEDJUN PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: b17[0_ Signed: (""71 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, April 17, 2012 TO: Jim Regg q? A ' Z4 ( z< P.I. Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2M -23 FROM: John Crisp KUPARUK RIV UNIT 2M -23 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2M - 23 API Well Number 50 103 - 20155 - 00 - 00 Inspector Name: John Crisp Permit Number: 191 - 034 - Inspection Date: 4/14/2012 Insp Num: mitJCrl20415062230 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2M -23 Type Inj N TVD 1551 - IA 43 1700 1536 PTD 1910340 Type Test SPT Test psi 1500 OA 24 1650 - 1514' Interval OTHER P/F F Tubing 0 50 _ 50 Notes: CMITIA x OA. The IA & OA are in communication with circulation string of 7" casing inside the single string of 9 5/8" casing where the packer is set. 3.9 bbls pumped for test. This is pressure test for P &A, not for continued injection. 6 ( JUN o i aria Tuesday, April 17, 2012 Page 1 of 1 . • I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, April 17, 2012 TO: I Jim Regg P.I. Supervisor L.. 4(Z 4 1 - SUBJECT: Mechanical Integrity Tests ( l CONOCOPHILLIPS ALASKA INC 2M -23 FROM: John Crisp KUPARUK RIV UNIT 2M -23 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry :142— NON CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2M - 23 API Well Number 50 103 - 20155 - 00 - 00 Inspector Name: John Crisp Permit Number: 191 - 034 - Inspection Date: 4/14/2012 Insp Num: mitJCr120415062923 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2M -23 Type Inj N TVD 1551 IA 1536 ' 1706 1624 _ 1580 - 1544 _ PTD 1910340 Type Test SPT Test psi 1500 OA 1514 - 1673 1602 - 1560 _ 1526 - Interval °THER P/F F Tubing 50 50 50 50 50 Notes: CMITIA x OA. This is a repressure of failed MIT. The IA & OA are in communication with 7" circulating string inside 9 5/8" casing where the packer is set. .2 bbls pumped for re -test. This MIT is for P &A not for continued injection. 6, id-- SLANNEDJuN o 1 2012 Tuesday, April 17, 2012 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: �7 DATE: Tuesday, April 17, 2012 Jim Regg I P.I. Superv ( �N � 1 Z4 '(2 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2M -23 FROM: John Crisp KUPARUK RIV UNIT 2M -23 Petroleum Inspector Src: Inspector Reviewed By: P.I. SuprvJ - NON - CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2M - 23 API Well Number 50 103 - 20155 - 00 - 00 Inspector Name: John Crisp Permit Number: 191 - 034 - Inspection Date: 4/14/2012 Insp Num: mitJCr120415054804 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2M-23 - Type Inj N 'TVD 1551 IA 225 225 - 225 225 - PTD 1910340 - Type Test SPT Test psi 1500 OA 275 275 - 275 275 - Interval OTHER P/F P -, Tubing 150 1700 - 1600 - 1575 - Notes: MITT for plug & abandonment of this class 2 disposal well. MITT passed. After we pressure tested the tubing slick line RIFT with 1 3/4" bailer with 2.17" stabilizer to tag cement. Estimated depth of cement in tubing was 1300', cement found at 1362'. Cement top was confirmed by tagging cement three times @ 1362'. Contaminated cement found in bailer. I took photos of bailer & cement. L () 5i0ANED JUN t 1 2012 Tuesday, April 17, 2012 Page 1 of 1 • • Plug Verification - KRU 2M -23 (PTD 1910340) Photos by AOGCC Inspector J. Crisp AOGCC Inspection # mitJCr120415054804 4/14/2012 Photos of wireline cement bailer I_ r ..„ 1 } • • Irr 11 • 1 tr , II?, p (.A .•• [ ; SEAN PARNELL, GOVERNOR Q.JZ) U LI Li L L:7 Lru ALASKA OIL AND GrAS / 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION / ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Tyson Wiese Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 -- 1,714 AR 9 1 - 0 31- Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2M-23 Sundry Number: 312-097 Dear Mr. Wiese: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy •. Foerster Chair DATED this (--f"' day of March, 2012. Encl. • • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 - r ° . • March 12th, 2012 Commissioner Dan Seamount � r s'. ;7�Tgi a9:�6i a "a State of Alaska �u Alaska Oil & Gas Conservation Commission 333 West 7 Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to suspend the Class II Disposal Well 2M -23 (PTD #: 191 -034) due to a failing C -MIT IAxOA, which was found to be a two way packer leak. The well has not been used for injection since 1997. 2M -23 is a Class II Disposal well completed in the UGNU sands. The well has a single 9 -5/8" production casing to 3515' KB with a 7" circulation string to 1524' KB. There is 2 -7/8" tubing with a packer at 1599' KB. There is a bridge plug set in 9 5/8" casing at 2,214' KB, and the injection perfs are located from 1,976'- 1,989' KB. On 10/24/10, the well failed a CMIT IAxOA. Troubleshooting this failed test using lift gas, we were able to push the annulus fluid down to the packer depth, indicting that we most likely have a compromised packer. The objective of this well suspend is to isolate the Class II disposal perfs, before continued tubing damage prevents access to the wellbore. The current estimate for SBHP is 896 psi @ 1,860' TVD. The attached well suspend proposal illustrates the current plan forward. In order to proceed, a variance to Section 20 AAC 25.112 (c) (1) (D) will be required. This section states that by the down squeeze method, the cement retainer must be set no less than 50 ft but no more than 500 ft above the perforated interval. ConocoPhillips requests the following variances: 1.) The cement retainer will be approx. 586' above the top perforation. ConocoPhillips requests a variance to the 500' max footage above the top perforation. If you have any question or require any further information, please contact me at 1- 907 -263- 4250. Sincerely, Tyson Wiese Wells Engineer CPAI Drilling and Wells STATE OF ALASKA 0 .- 7 -- L?/e 2 /rte A OIL AND GAS CONSERVATION COMM� ` i APPLICATION FOR SUNDRY APPROVALS 3#2:11-1 2---- 20 AAC 25.280 1. Type of Request: Abandon r Flug for Redrill r Perforate New Pool r Repair well r Change Approved Program r Suspend PT • Rug Perforations r Perforate r Rill Tubing r Time Extension r Operational Shutdown r Re -enter Susp. Well r Stimulate r Alter casing Other: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 191 -034 3. Address: Stratigraphic r Service P' P. 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20155 -00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No J 2M -23 • 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25586 • Kuparuk River Field / Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 3535 • 2853 • 3435' 2789' 2214' Casing Length Size MD TVD ---- -. - - -. — Burst... . , Collapse CONDUCTOR 79 16 115' 115' A. SURFACE a ; ,. ° I 3480' 9.625 3515' 2840' PRODUCTION 1491' 7 1524' 1486' i MAR, k ,,,,,,. AIaaic i CM tk Gds Cc ns Lorprnissiet, 1 Anchorage j Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tuttrng mu (Jq. 1976' -1989' 1843' -1853' 2.875 J - 1643 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER 'D' PACKER MD= 1599 TVD= 1551 NO SSSV 12. Attachments: Description Surrmary of Proposal r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development r Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/28/2012 Oil r Gas r WDSPL r Suspended I✓ • ' 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the egoing is true and correct to the best of my knowledge. Contact: Tyson Wiese @ 263 -4250 Printed Name A:111.._ T V son iese Title: Wells Engineer Signature Phone: 263 -4250 Date CPj - V " 12 ) Commission Use Only Sundry Number:5 Z` C Conditions of approval: Notify Commission so that a representative may witness Plug Integrity /BOP Test r Mechanical Integrity Test r Location Clearance r Other: /1/1 : 1.74. c., Pi. Pici. c. a i,.v, - er /Thd 2 , A-4( 4(_ L.S, 1l ) Subsequent Form Required: / 0 — L I ? Y APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 3 jZ S, /�'Z P ' ," 0„ S 2010 ` ^� 3/ `� 0RIGINALlop,,, / � Submit in Duplicate 'r .I !! �F.�JSj �l 5. • • 2M -23 P &A Permit to Drill #: 191 -034 The objective of the proposed 2M -23 P&A is to isolate the Class II disposal perfs by . pumping cement through a cement retainer @ approx. 1,400' KB, squeezing cement into the perfs, and laying in cement on top of the retainer. Holes will be shot in the tubing, and cement will be pumped down the IA, and up the OA and tubing, bringing cement to surface . in each. Proposed P &A: (suspend) Coil Tubing and Pumping Services: 1. Ensure an approved Sundry has been received from AOGCC. 2. Set cement retainer @ approx. 1,400' KB. 3. Pump 30 bbls diesel to confirm injectivity. 4. Pump 35 bbls of AS1 cement to squeeze perfs, and lay in cement to 1,300' KB. Slick Line / Little Red: 1. WOC for 24 hours. Notify the AOGCC Inspector (659 -2714; 659 -3607 pager) to witness the tag and pressure test of the cement plug. 2. RIH and tag TOC at approx. 1,300' KB. Record Results 3. Perform MIT -T w/ diesel to 1,500 psi. Record Results 4. Perform C -MIT of IA/OA w/ diesel to 1,500 psi. Record Results E -Line / Little Red: 1. RIH and punch holes in tubing @ 1,250' KB or as close to TOC as possible. 2. Pump 20 bbls diesel through tubing holes, to ensure circulation. Pumping Services: 1. RU to take returns from both OA and tubing. 2. Pump 124 bbls of AS1 cement to fill the OA, IA, and Tubing to surface. 3. When good cement is seen at surface in both OA and tubing, Shut down. Little Red: 1. WOC 24 hours. 2. MIT -T with Diesel to 1,500 psi. Record Results 3. MIT -IA with Diesel to 1,500 psi. Record Results. 4. MIT -OA with Diesel to 1.500 psi. Record Results. TW ii • • 2M -23 Class II Disposal Well Plug & Abandonment (Suspend Well) Current Completion Proposed P &A TOC (171/0) © Surface Punch Holes Co? 1,250 KB First Plug TOO 1.300' KB Last Tag t 1,390' KB (15' of 2.25" Bailer) Cement Retainer ,a) 1 400' KB T 26# J Circulation String 1,524' KB All Cement to be IS 7# AS 1 Permafrost Blend GLV (Dummy) {! 1.5E3 KB Baker 1) Packer © 1,599' KB t ( way packer leak at 3 bpm) 2 7/8 Tubing Tail vg Camco'0 Nipple a 1,641' KB Ugnu Perfs: 1,976' KB — 1,989' KB Last TD tag .0 1,977' KB (01 %08/94) Baker Bridge Plug r 2,214' KB 9 &I6' 364J-55 Prod. Casing TD 3,515' KB TW 03 -12 -12 TW Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Saturday, August 13, 2011 8:13 PM To: NSK Problem Well Supv Subject: RE: 2M -23 (PTS 191 -034) class 2 disposal well injectivity test for P&A 08 -13 -11 KeIIy, Used diesel certainly makes things easier. I will have a look at the file on Monday. I will message back then. Tom Maunder, PE AOGCC From: NSK Problem Well Supv [mailto:n1617 @conocophillips.com] Sent: Sat 8/13/2011 9:43 AM To: Maunder, Thomas E (DOA) Subject: 2M -23 (PTS 191 -034) class 2 disposal well injectivity test for P&A 08 -13 -11 Tom, As per our discussion on the phone, ConocoPhillips intends to perform an injectivity test on 2M -23 in preparation for the upcoming P &A. As you suggest, we will be using used diesel to perform the test. We expect to use approximately 30 bbls of diesel. Please let us know if there is anything more that needs to be done before we proceed. We expect this work to be completed in the coming days/weeks (as diesel becomes available). Thanks in advance Brent Rogers / KeIIy Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr 909 4 ,1444,W A U Z O L 8/30/2011 From: Maunder, Thomas E (DOA) Sent: Tuesday, May 17, 2011 2:43 PM To: Rogers, Brent A Cc: NSK Problem Well Supv; NSK Well Integrity Proj; NSK Env Coord Spills Waste Land & Other; NSK FId DrIg Supv; Herrmann, Daniel D; CPF2 Prod Engrs Subject: RE: 2M -23 (PTD 191 -034) Report of failed CMIT IAxOA Brent, Thanks for the message. I don't believe anything other than keeping track of the fluids as you normally do is needed. Tom Maunder, PE AOGCC From: Rogers, Brent A [mailto:Brent.A.Rogers @conocophillips.com] Sent: Monday, May 16, 2011 4:48 PM To: Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj; NSK Env Coord Spills Waste Land & Other; NSK FId Drlg Supv; Herrmann, Daniel D; CPF2 Prod Engrs Subject: RE: 2M -23 (PTD 191 -034) Report of failed CMIT IAxOA Tom, As per our discussion on the phone, ConocoPhillips intends to perform further diagnostic work with slickline. The plan is to drift the well in order to find a tool configuration that may get down the well. A 10 -403 is in the process of being written and submitted for a rigless P & A. The drift is to ensure we will be able to carry on with that plan. Currently there is no plan during the drift to pump any fluids down hole, however if there are problems, some fluids may need to be pumped. Are there any reporting requirements for fluids used during diagnostic work? Thank you in advance. Brent Rogers /Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 From: . : = omas E (DOA) [mailto:tom.maund - • a.gov] Sent: Wednesday, Nove ■ 010 2:2 • To: Rogers, Brent A Cc: NSK Problem We .. SK Well Integrity Proj; N ' - • • d Mahan&McCullough; NSK • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. November 30, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Down Hole Video: 2M -23 Run Date: 11/25/2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2M -23 Digital Video File (AVI) 1 DVD Rom 50 -103- 20155 -00 FEB 4 1 MI PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. 05e till- 034 Anchorage, Alaska 99518 Office: 907 - 273 -3527 0( 5� Fax: 907 - 273 -3535 Vinton wood alliburton co_ r Signed: Date: ��, Page 1 of a • Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Wednesday, November 24, 2010 9:19 AM To: Maunder, Thomas E (DOA) Subject: RE: 2M -23 (PTD 191 -034) Report of failed CMIT IAxOA They drifted to 1456' SLM with a full bore drift. Brent Rogers /Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 - 7224 � [) Pager (907) 659 -7000 pgr. 909 "y'` From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Wednesday, November 24, 2010 9:14 AM To: NSK Problem Well Supv Subject: RE: 2M -23 (PTD 191 -034) Report of failed CMIT IAxOA How deep did the slickline mentioned in your message of October 30? Tom From: NSK Problem Well Supv [mailto:n1617 @conocophillips.com] Sent: Wednesday, November 24, 2010 9:12 AM To: Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv Subject: RE: 2M -23 (PTD 191 -034) Report of failed CMIT IAxOA We pumped 5 bbls and did not gain any pressure. We had a limited amount of test fluids so that is all we could pump during the initial test. Plans forward for further diagnostics are ongoing. We are awaiting the availability of the video log and other diagnostics will be performed pending the results of what we see. Brent Rogers /Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 From: Maunder, Thomas E (DOA) [mailto:tom.maunder @ alaska.gov] Sent: Wednesday, November 24, 2010 8:38 AM To: NSK Problem Well Supv Cc: NSK Well Integrity Proj Subject: RE: 2M -23 (PTD 191 -034) Report of failed CMIT IAxOA Thanks Brent. How did the pressures behave during the attempted CMIT? Tom 8/15/2011 Page 2 of it • • From: NSK Problem Well Supv [mailto:n1617 @conocophillips.com] Sent: Wednesday, November 24, 2010 8:37 AM To: Maunder, Thomas E (DOA) Cc: NSK Well Integrity Proj Subject: RE: 2M -23 (PTD 191 -034) Report of failed CMIT IAxOA Tom, The testing was done proactively in order to keep the three Class 2 wells current on the MIT's. The intent was to test all three at the same time in order to align the testing dates and insure they were all current. Brent Rogers /Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Tuesday, November 23, 2010 3:43 PM To: Rogers, Brent A Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: RE: 2M -23 (PTD 191 -034) Report of failed CMIT IAxOA All, Please disregard question 1; long day. But I am still curious what prompted the testing? Tom From: Maunder, Thomas E (DOA) Sent: Tuesday, November 23, 2010 3:08 PM To: 'Rogers, Brent A' Cc: 'NSK Problem Well Supv'; 'NSK Well Integrity Proj' Subject: RE: 2M -23 (PTD 191 -034) Report of failed CMIT IAxOA Well Integrity Folks, I am looking into this well and I have a question or two: 1. By virtue of the construction, IA x OA is a given. Is there some other communication issue here that I am missing? 2. What prompted the initial testing? Thanks in advance, Tom Maunder, PE AOGCC • uaunder, Thomas E (DOA) Sent: Wei n- . - November 03, 2010 2:25 PM To: 'Rogers, Brent A' Cc: NSK Problem Well Supv; NS itegrity Proj; NSK En . • • Mahan&McCullough; NSK Fld Drlg Supv Subject: RE: 2M -23 (PTD 191 -034) Report • - • IAxOA Perry, et al, Sorry for the delay in r- - g. It is appropriate to perform diagnostics to de - - ' • - the obstruction in the well. You have in • • - - • that Expro is at Kuparuk and the intent is to employ their downho e - - a. In other to do this ' ecessary to pump clear fluid to allow pictures to be taken. I don't see an issue with thi . • 403 is 8/15/2011 • • From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Wednesday, November 03, 2010 2:25 PM To: Rogers, Brent A Cc: NSK Problem Well Supv; NSK Well Integrity Proj; NSK Env Coord Mahan&McCullough; NSK FId Dr Ig Supv Subject: RE: 2M -23 (PTD 191 -034) Report of failed CMIT IAxOA Perry, et al, Sorry for the delay in replying. It is appropriate to perform diagnostics to determine the obstruction in the well. You have indicated that Expro is at Kuparuk and the intent is to employ their downhole camera. In other to do this, it is necessary to pump clear fluid to allow pictures to be taken. I don't see an issue with this. No 403 is necessary. I do appreciate Brent and yourself keeping us in the loop here. I look forward to hearing what might be determined. Call or message with any questions. Tom Maunder, PE AOGCC From: Rogers, Brent A [mailto:Brent.A.Rogers @conocophillips.com] Sent: Saturday, October 30, 2010 5:20 PM To: Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj; NSK Env Coord Mahan&McCullough; NSK FId DrIg Supv Subject: FW: 2M -23 (PTD 191 -034) Report of failed CMIT IAxOA Tom, As per our discussion on the phone, diagnostics need to be performed on 2M -23. Diagnostics so far have included Slickline attempting to set a plug in the tubing without success. They were unable to get down to set the plug. The obstruction in the tubing has not been determined. Further diagnostics may include, but not be limited to, performing an injectivity test down the tubing with diesel. The test will include stipulations not to exceed 1500 psi or 6 bbl /min and a maximum of 300 bbls. If necessary, another request would be submitted if more fluid is needed. This may be followed with nitrogen injection to displace the fluid below the obstruction in order to perform a video log. Additional diagnostics will include a blowdown with nitrogen or gas lift gas on the OA and or IA, in an attempt to displace fluid to identify the leak depth. 2M -23 is one of ConocoPhillips Class 2 disposal wells. Are there any reporting requirements for any of the fluids that may be used or needed for the diagnostic work? Please respond with some guidance. Brent Rogers /Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 From: NSK Problem Well Supv Sent: Monday, October 25, 2010 4:25 PM To: Maunder, Thomas E (DOA); 'Regg, James B (DOA)'; Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv Subject: 2M -23 (PTD 191 -034) Report of failed CMIT IAxOA • • Tom, Jim, Guy Inactive Class 2 disposal well 2M -23 (PTD 191 -034) failed a diagnostic CMIT IAxOA. The production casing is open ended on this well and acts as a circulating string between the production and surface casings. The well was SI at the time of testing and the TIO was 0/150/40. Currently there is no flowline connected to this well and it has been inactive. Additional diagnostics will be performed with Slickline and DHD. This well is currently on the LTSI well list, therefore it is ConocoPhillips intention to not add it to the monthly injector report also. Please let us know if this plan is unacceptable. Attached is a schematic. Please let me know if you have any questions. Brent Rogers /Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 ~® ~~~~ Toy Jim Regg '7 u, P.LSupervisor ~~ "~1~~' ~L FROM: Jeff Jones Petroleum Inspector State ®f Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, Ju]y 18, 2008 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2M-23 KUPARUK RIV UNIT 2M-23 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ,j ~~ Comm Well Name: KUPARUK RN UNIT 2M-23 Insp Num: mitJJ0807i7123052 Rel Insp Num: API Well Number: 50-103-201ss-00-00 Permit Number: 191-034-0 Inspector Name: Jeff Jones Inspection Date: 7/14/2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I' 2M-23 Type Inj. ( N , TVD lssl ~ IA i 0 1810 ~ 1770 ~ 1740 P.I. ! 1910340 TypeTest i SPT Test psi I 1500 QA 0 ~ 177s 1700 i 1690 ~ Interval REQVAR P/F P Tubing ~ 0 7s so ! so NOtes' Well has known lA x OA communication. 1.7 BBLS glycol pumped; no exceptions noted. / ~~ANNE€~ AUG ~ ~ 2Q08 Friday, July 18, 2008 Page I of 1 2M-23 (PTD 1910340) MITIA for Class II disposal well Page 1 of 1 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] J ~(~ 2 (~P~ Sent: Tuesday, July 15, 2008 8:25 PM <~ ~~( To: Maunder, Thomas E (DOA); Regg, James B (DOA); Fleckenstein, Robert J (DOA); DOA AOGCC Prudhoe Bay Cc: NSK Problem Well Supv Subject: 2M-23 (PTD 1910340) MITIA for Class II disposal well Attachments: MIT KRU 2M-23 07-14 08.x1s; 2M-23 schematic.pdf Tom, Jim, and Bob Attached is a copy of the MITIA for 2M-23 that was performed for compliance testing on a Class II disposal well. I have also included a schematic of the wellbore due to the IA and OA are in communication for use as a circulating string. Please let me know if you have any questions. «MIT KRU 2M-23 07-14-08.x1s» «2M-23 schematic.pdf» Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 ~~~ JUL ~ ~ 2Q08 ~i1~i2oog • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska, Inc. ~~~ ~(j ^j (f~~ Kuparuk / KRU / 2M-23 07/14/08 Greenwood /Bates /Phillips - AES Jeff Jones Packer De th Pretest Initial 15 Min. 30 Min. Well 2M-23 Type Inj. N TVD -551' Tubing 0 75 50 50 Interval V P.T.D. 1910340 Type test P Test psi 1500 Casing 0 ~ 1,810 1,770 1,740 P/F P Notes: AIO 26 -Class II Disposal well OA 0 /1775 1700 1690 IA and OA are common due to circulation string Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D =Drilling Waste M =Annulus Monitoring I =Initial Test G =Gas P =Standard Pressure Test 4 =Four Year Cycle I =Industrial Wastewater R =Internal Radioactive Tracer Survey V =Required by Variance N =Not Injecting A =Temperature Anomaly Survey T =Test during Workover W =Water D =Differential Temperature Test O =Other (describe in notes) MIT Report Form BFL 11!27/07 2008-0714_MIT_KRU_2M-23Jj.xls ~~~~~~~~• ~ KR~ i, -~,-t.~PHILLIPS Alaska, Inc. ~,. A Subsidiary of PHILLIPS PETROLEUM COMPANY 2M-23 2M-23 API: 501032015500 Well T e: DISP An le TS: de SSSV T e: Ori Com Itn: 4/7/91 An le TD: 50 de 3535 Gas Lift Mandrel/Dummy ,_, Annular Fluid: Last W/O: Rev Reason: Add General Notes Valve 1 (1554-1555, Reference Ref Log Date: Last Update: 10/18/00 TUBING (0-1645 Last Ta : 1501 TD: 3515 ftKB , OD:2.875, ID:2.441) Last Tag Date: 6/20/98 Max Hole An le: 51 deg @ 2675 Casing Strin gs -All Descri tion Size To Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 115 115 62.50 H-40 PKR (1601-1602, OD:8.765) PROD. CSG - CIRCULATION STRING 7.000 0 1524 1485 26.00 J-55 SUR CASING SUR. CASING 9.625 0 3515 3515 36.00 J-55 . (0-3515 OD:9.625 Tubin Strin s -All , , Wt:36.00) Descri tion Size To Bottom TVD Wt Grade Thread TUBING 2.875 0 1645 1589 6.50 J-55 EUE 8RD PerForations Summa Interval TVD Zone Status Ft SPF Date T e Comment 1976 - 1989 1842 - 1852 13 2 4/8/91 IPERF D na Stri ; UGNU Zone Gas Lift MandrelsNalves NO GO (1643-1644, St MD TVD Man Mfr Man T e V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt OD:2.875) 1 1554 1511 Merla 2 7/8 X 1 1/2 Merla DV 0.0 RK? 0.000 0 4/7/91 Other l u s, a 'ui ., etc. -JE WELRY De th TVD T e Descri tion ID 1601 1551 PKR Baker'D' 3.250 1643 1587 NO GO Camco'D' Ni le 2.250 i 1645 1589 TUBING TAIL 2.441 2214 2005 BRIDGE PLUG Baker 0.000 Genera l Not es Date Note TUBING TAIL 5/7/98 Ta ed 1510 ELM, tubin stick MJ (1645-1646, OD:2.875) I 9/29/00 NOTE: This is a Class 2 Dispoisal well; the 7" Production String is open-ended, and acts as a circulation string for freeze protection. The IA & OA are indirect communication and rovide a fluid flow ath. `; 10/18/00 Schematic u dated b J.Peirce. Perf (1976-1989) BRIDGE PLUG (2214-2215, OD:8.765) - - Maunder, Thomas E (DOA) From: Thomas Maunder [tom_maunder @admin.state.ak.us] Sent: Wednesday, July 12, 2006 8:27 AM To: Regg, James B (DOA) Subject: Re: [Fwd: Emailing: MIT KRU 2M -23 07- 09- 06.xls] I have looked at the file and this appears to be a shallow, single casing disposal well. Disposal was originally planned as a temporary activity and then the well would be drilled to TD in the Kuparuk. It does not appear that the well was ever drilled deeper. According to RBDMS, nothing has been injected since March 1997. I will do the MIT II on the well, I cannot find any sheet in the book. So far as the MIT schedule, 2 years may be appropriate but due to the well being a slurry injector. I don't see that the well has a MIT failure. Since the 7" is a circulating string, it really doesn't exist. It was not placed in the well for any pressure isolation ability. Might be appropriate to ask Jerry and MJ if they know of any intent to use the well. Tom James Regg wrote, On 7/11/2006 1:36 PM: > Class II -D well; has a circulating string such that IA and OA are > common (not obvious from their report; pulled this from well record). > According to well records, this well is being handled no different > than a well that has complete well integrity (4 yr MIT). Seems like > there should be a waiver for the well with limits imposed like any > other well with IAxOA communication. (monthly rpt of TIO pressures; > MITT and CMIT TxIA every -- yrs) > Jim > Original Message > Subject: Emailing: MIT KRU 2M -23 07- 09- 06.xls > Date: Tue, 11 Jul 2006 11:27:10 -0800 > From: NSK Problem Well Supv <n1617 @conocophillips.com> > To: Thomas Maunder <tom maunder @admin.state.ak.us >, James Regg > <jim_regg @admin.state.ak.us >, bob_fleckenstein @admin.state.ak.us > > Please find the enclosed witnessed mit > > Perry Klein > Problem Wells Supervisor > ConocoPhillips Alaska Inc. > Office 907- 659 -7224 A1JG p 0 ZQ 11 > Cell 907 - 943 -1244 ti: > «MIT KRU 2M -23 07- 09- 06.xls» 1 MEMORANDUM e TO: Jim Regg '7JK" / I (JAC,'- '_ P.L Supervisor" f7 7 z~ í{.;, FROM: Jeff Jones Petroleum Inspector Well Name: KUPARUK RIV UNIT 2M-23 Insp Num: mitJJ060711172353 Rei Insp Num Packer Well: 2M-23 IType Inj. I N i TVD ¡ P.T. i 1910340 ITypeTest i SPT i Test psi !/ J' Interval 4YRTST P/F P State of Alaska e Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 12,2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2M-23 KUPARUK RIV UNIT 2M-23 \ q \ ,03y.- Src: Inspector Reviewed By: P.L Suprv <TBí2-- Comm NON-CONFIDENTIAL API Well Number 50-103-20155-00-00 Permit Number: 191-034-0 Inspector Name: Jeff Jones Inspection Date: 7/9/2006 Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. I I 1 , 1551 i IA 0 1650 I 1600 1580 1 I I I I I I ! 1500 ! OA 0 1650 1600 1580 [ , I I I Tubing [ 0 I 50 60 60 I I , i , I I Notes lA & OA communication. 0.2 bbls glycol pumped. 1 well house inspected; no exceptions noted. C."l.:r:r J1\. '.>( 0:\ - ~ e v....'€fLe s£;.iw'^"v-hc. ~+-..i-clc kC?,) ) :.J:A - CiA- è.¿'''ytILµ..;,¡, V, ,t C i i"C"cL-;..4..-~ C", 1_ , cj ."'~-'~ Wednesday, July 12,2006 "~"?' 7/z~--¡. rq" JtJ 1.. ;~.J J .L Page I of 1 , e ~PHILLIPS Alaska, Inc. ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY 2M-23 Gas Lift Mandrel/Dummy Valve 1 (1554-1555, 00:5.460) TUBING (0-1645, 00:2.875, 10:2.441) PKR (1601-1602, 00:8.765) SUR. CASING (0-3515, 00:9.625, Wt:36.00) NO GO (1643-1644, 00:2.875) TUBING TAIL (1645-1646, 00:2.875) Perf (1976-1989) BRIDGE PLUG (2214-2215, 00:8.765) KR' 2M-23 Ref Log Date: TO: 3515 ftKB Max Hole 51 deg @ 2675 An Ie: s-AII Size 16.000 7.000 To Bottom o 115 o 1524 TVD Wt 115 62.50 1485 26.00 Grade H-40 J-55 Thread V Mfr V Type V OD Latch Port TRO Merla OV 0.0 RK? 0.000 0 Date Run 4/7/91 Vlv Cmnt Descri tion ID 3.250 2.250 2.441 Baker '0' Cameo '0' Ni Ie Baker 0.000 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test ~t/; l-1/1 ?{ 04 Email to.Tom_Maunder@adminstateak.us;Bob_Fleckenstein@admln.state.ak.us; and Jim_Regg@admm state.b .us OPERATOR: ConocoPhillips Alaska Inc. FIELD I UNIT I PAD: KRU 2M DATE: 06/28/04 OPERATOR REP: Sauvageau 1 Arend - APC AOGCC REP: Waived Packer Depth Pretest Initial 15 Min. 30 Min. Well 2M-03 Type Inj S TV.D. 5939 Tubing 2400 2400 2400 2400 Interval 4 P.TD.1911410 Type Test P Test psi 1500 Casing 1250 1800 1770 1760 P/F P Notes: Well 2M-14 Type Inj G T.V.D. 6025 Tubing 3550 3550 3550 3550 Interval 4 P.T.D. 1920630 Type Test P Test psi 1506 Casing 550 1920 1910 1910 P/F P Notes: Well 2M-16 Type Inj S T.V.D. 5845 Tubing 2300 2300 2300 2300 Interval 4 P.TD. 1910320 Type Test P Test psi 1500 Casing 900 2910 2850 2840 P/F P Notes: Well 2M-17 Type Inj G TV.D. 6005 Tubing 3580 3580 3580 3580 Interval 4 P.T.D. 1910180 Type Test P Test psi 1501 Casing 2800 1600 1620 1620 P/F P Notes: Drawdown test due to high IA initial pressure Well 2M-19 Type Inj S TV.D. 5856 Tubing 2000 2000 2000 2000 Interval 4 P.T.D. 1911320 Type Test P Test psi 1500 Casing 135 2600 2600 2600 P/F P Notes: Well 2M-23 Type Inj N TV.D. 1551 Tubing 100 100 100 100 Interval 4 P.T.D. 1910340 Type Test P Test psi 1500 Casing 0 1800 1750 1720 P/F P Notes: Class 2 disposal well. IA & OA common via circ string Well 2M-26 Type Inj G TV.D. 5971 Tubing 3100 3100 3100 3100 Interval 4 P.TD. 1920550 Type Test P Test psi 1500 Casing 1550 2320 2300 2300 P/F P Notes: Well Type Inj TV.D. Tubing Interval P.T.D. Type Test Test psi 1500 Casing P/F 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 Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T est during Workover 0 = Other (describe in notes) MIT Report Form Revised: 05/19/02 2004-0628_MIT _KRU_2M-26.xls 7/13/2004 T ON OR BEFORE C:LO~M.DOC STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL r-~ GAS ['-'] SUSPENDED r'~ ABANDONED O SERVICE ~ DISPOSAL WELL 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 91-34 3 Address P.O. Box 100360, Anchorage, AK 99510-0360 4 Location of well at surface 114' FSL, 529' FWL, SEC 27, T11N, R8E, UM At Top Producing Interval NA At Total Depth 1310' FSL, 1744' FWL, SEC 27, T11N, R8E, UM 5 Elevation in feet (indicate KB, DF, etc.) RKB 140', PAD 105' GL 12 Date Spudded 04/02/91. 17 Total Depth (MD+TVD) 3535' MD, 2853' TVD 13 Date T.D. Reached 04/03/91. 6 Lease Designation and Serial No. ADL 25586, ALK 2672 14 Date Comp., Susp. orAband, 04/07/91. 19 Directional Survey 18 Plug Back Depth (MD+TVD) 3435' MD, 2789' TVD 8 APl Number 50-103-20155 9 Unit or Lease Name KUPARUK RIVER 10 Well Number 2M-23 11 Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL POOL J 15 Water Depth, if offshore 116 No. of Completions NA feet MSLJ 1 None feat MD 1400' APPROX 22 Type Electric or Other Logs Run HRI/DFL/SDL/GR/SP/CAL/DSN II/CBL 23 CASING, LINER AND CEMENTING RECORD SE'FI'lNG DEPTH MD I GRADE CASING SIZE WT. PER FT. TOP 16' 62.5# H-40 SURF 9-5/8" 36# J-55 SURF 26# J-55 24 Perlorations open to Production (MD+TVD of interval, size and number) SURF BO'I-rOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 115' 24" 230 SX ASII 3515' 12-1/4" 1150 SX AS III , 985 SX CLASS G 1525' and Bottom and Perforated Ugnu f/1976'-1988' MD 1842'-1851' TVD 8-1/2" 120 SX AS I (TOP JOB) Not cemented, circulatincj string SIZE 26 2-7/8" TUBING RECORD DEPTH SET (MD)i 645' ]~;~1?R sET (MD) ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Date First Production Started disposal October 29, 1991 Date of Test Hours Tested Flow Tubing Press. Casing Pressure IPRODUCTION FOR TEST PERIOD CALCULATED 24-HOUR RATE OIL-BBL WATER-BBL IGAS-MCF GAS-MCF OIL-BBL 28 CORE DATA WATER-BBL ICHOKE SIZE I GAS-OIL RATIO OIL GRAVITY-APl (corr) ~ ~ Brief description of lithoiogy, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Alaska 0ii & Gas Cons. Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate GECLOGIC ~ FORMATION 1ESTS NAIVE Include interval tested, pressure data, all fluid= recoverd and gravi~, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Ugnu Sands Top 1629'(ELM) 1575' NA i31. LISTOF ATTACHMENTS MWD, REPORT OF OPERATIONS '32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of ServiCe Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate:whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27~' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT APPROVAL: 2M-23 NORTH SLOPE KUPARUK RIVER UNIT KUPARUK RIVER FIELD ADL 25586 ALK 2672 50-029-20155 91-34 ACCEPT: 04/01/91 SPUD: 04/02/91 RELEASE: 04/07/91 OPERATION: DRILLING RIG: DOYON 14' AFE: AK5725 WI: 55.252072 04/02/91 ( 1) TD: 532' ( 532) SUPV:PDW DRILLING AT 532' MW: 8.7 VIS: 60 ACCEPT RIG ON 2M-23 AT 20:00 HRS 4/1/91. NU DIVERTER, FINISH RIGGING UP GLOBAL SOLIDS PROCESSING UNIT. SPUD AT 02:00 HRS 4/2/91, DRILL TO 532'. DAILY:S39,120 CUM:$39,120 ETD:S39,120 EFC:$1,620,000 04/03/91 ( 2) TD: 2380' (1848) SUPV:PDW DRILLING AT 2380' MW: 9.2 VIS: 51 DRILL TO 1165', UNABLE TO BUILD ANGLE, CHANGE BHA TO 2-1/2 DEGREE BENT SUB. DRILL WITH BENT SUB TO BUILD ANGLE, CHANGE BACK TO BENT HOUSING MOTOR, CONTINUE DRILLING TO 2380' DAILY:S74,134 CUM:$113,254 ETD:S113,254 EFC:$1,~20,000 04/04/91 (3) TD: 3532'(1152) SUPV:JCP LOGGING 9-5/8"@ 3515' MW: 9.6 VIS: 50 DRILL TO CASING POINT AT 3532'. SHOTR TRIP AND POOH. LOG SURFACE HOLE WITH HLS TRIPLE COMBO. DAILY:S63,687 CUM:$176,941 ETD:S176,941 EFC:$1,620,000 04/05/91 ( 4) TD: 3535'( SUPV:JCP 3) NU BOPE 9-5/8"@ 3515' MW: 9.7 VIS: 43 RD LOGGERS, RIH FOR WIPER TRIP, POOH. RUN 85 JTS 9-5/8" CASING, CIRC FOR 1 HR CEMENT WITH 80 BBL WATER SPACER, 1150 SX ASIII LEAD CEMENT WITH 1/4 PPS CELLO FLAKE AT 12.1 PPG, 985 SX TAIL CEMENT WITH 2% CACL AND 1/4 PPS CELLOFLAKE AT 15.8 PPG. DISPLACE WITH 10.0 PPG BRINE. LOST RETURNS AFTER 175 BBL DISPLACED 10.5 PPG CEMENT RETURNS TO SURFACE, BUMPED PLUG TO 2500 PSI, FLOATS OK. CIP AT 21:15 HRS 4/4/91. PERFORM 120 SX TOP JOB. NU CASINGHEAD AND BOPE. DAILY:S243,028 CUM:$419,969 ETD:S419,969 EFC:$1,620,000 04/06/91 (5) TD: 3535'( SUPV:JCP o) LDDP 9-5/8"@ 3515' MW: 0.0 VIS: 0 RU AND TEST BOPS. RIH WITH SCRAPER, TAG FLOAT COLLAR, CIRC 120 DEGREE BRINE TO CURE CEMENT. POOH WITH SCRAPER, RUN HLS CBL/PET LOG. CEMENT OK ACROSS PROPOSED PERF INTERVAL. LDDP. DAILY:S57,527 CUM:$477,496 ETD:S477,596 EFC:$1,619,900 04/07/91 ( 6) TD: 3535'( 0) SUPV:JCP NU TREE 9-5/8"@ 3515' MW: 0.0 VIS: 0 RU HLS E-LINE UNIT, RUN 8.375" GR TO 2500' MD, SET BP AT 2212' MD, SET BAKER MODEL D PERM PACKER WITH TUBING TAIL AT 1600'. RUN 37 JTS 7" CASING WITH BOTTOM AT 1525'. INSTALL SLIPS AND TUBING HEAD. NU AND TEST BOPE. RUN 47 JTS 2-7/8" TUBING, STING INTO PACKER, SPACE OUT AND LAND TUBING. TEST ANNULUS TO 1500 PSI, OK, WITNESSED BY AOGCC REPRESENTATIVE. ND BOPE, NU TREE. DAILY:S113,446 CUM:$590,942 ETD:S590,942 EFC:$1,620,000 04/08/91 ( 7) TD: 3535'( 0) SUPV:JCP SIGNATURE: RELEASE RIG @10:00 4/7 9-5/8"@ 3515' MW: 0.0 VIS: 0 TEST TREE TO 250 AND 3000 PSI. TEST ANNULUS TO 1500 PSI. DISPLACE 10.0 PPG BRINE WITH DIESEL IN 7"X9-5/8" AND 2-7/8"X7" ANNULI. RELEASE RIG AT 10:00 AM 4/7/91. MOVE TO 2M-16 ~J~ DATE- ~ ~" ':' ..... "' D.s, Ii'"":'"'":':"~. M - ' H.T.S, $.. ¢OO~D/#,dT£$ SHOWN 4/i'E ~$.,o.. ~'ONff ~**N. AD. ~. 4. LOC,4TEO WITHIN PNOTRACTEO TWR !1/V,~ RSg, B ~,, UMIAT MEt~IDI4N~ _"1 / ~, 94~, D~8. ~ 4 ~Y~ 7~,61 ?0o 1~' 1~,~76" ~ ~,94~,9~.93 4~7, ?79.~ ?Oe16' I~.~??" ~ ~,9e~,985.9 I 4~7,804,5~ YO~16'/~,578" 4 ~,gdE,~E~.9 I dBX, 8~.~ 4 ?0016' ~ ~,~ ~.9~ ~7, ~. 4/ 7~/~' I0 5,94O,0O5. e4 4EX;~XD.~I ~Oel6'lE.~80 ~ la 5, 940, ~05.9R 400, I ~q. 4~ ?Oel~' 10.~3" /~ ~,94~,~9~ 4~,/6~.02 ~0~/6'/~.~'' 16 ~,94~,9~4 4~, 1~4.04 ~0~1~' t? ~, ~4~, OO~.Q6 40~, ~19./~ ?0~/~' /O. ~06" I0 ~,940,90~90 400, ~44.~1 ?0~t6'1~.~'' 19 5, D40,~5~ 40~,R~./~ 70°1~18.~05' ~1 ~,~40,~5.00 488; 31~.t~ ?0~1~'10.~05'' 23 ~, 9~i 90~.~5 40~, ~0.01 70~16' t~.~lO" I ,:::) I".',",".L / /I \ I -,,_ I. t_.l q ._-r:~, If ~ il I/ ~J,,,.~, · 'T" ¢/1,.::. h: 1 "_ ~ ( ?-~r',~,., If I~ 1,,, V". .... L..' VIC/NIT Y MAP SCALE I"= P_ MILES L OlVe. F, ~. Lo F.E./-. 0~. PAD · I~0e0,5'~',2~?'' /14 ' tll ' 101.0' IOd.9 I ~0° 0~' ~, ~ ' I I 4 ' ~ ' I01.0' 104. I ~0° 0~' ~. &09 " I/4 ' 6t ' I01.0' 104.~ /~0e OE'~.~30 ' //4' /~ ' I~.~' tO~. l /~0e0~'~./78" //4' $~' 100.8' 105.~ /~0°0~'~0.~0' I/~' //4' I00,?' 105.~ /50°~5'4~,~4' //~ ' /~' t00.6' /50e 0~'4~.~4 ' //4 ' /~' I00.~' 105.5 180e08'4~5~4 " /I4 ' 109' 1~.5' 105,~ /~0a0~'4~.9t9 " 114 ' R?9' 100.3' 105.6 /~OeO~,4~' /~, //4 ' ~0~ ' ~,2' 105.6 I ~0e05'43. 74~" I I 4 ' 5~4' I~.1' 105.6 150eOS'4~.E?~" 114 ' 404' 99.9' /~0°0~'4/.~E4'' //4' 4~' 99,9' 105,6 I~0e0~'40.~31" 114 ' 4~4' 99,8' 105,d: 1~0°0~"40.0~" 114' 479' 99,7' ;05.5 /50e0~'~9.~4" //~ ' ~0~' 99.7' I~OeO~'~.$~O" il4' ~' 99.6' t04.9 /~0°05'~//' //~' 55~' 99,5' /04.9 suRvzYoR~ C~Rrm, C~_~' I'HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND ~URVEYtN~ IN THE SI'ATE OF ALASKA ~ OF A/_ .',~ ~"~ ' ,'t . , '; t · AND THAT THIS PLAT REPRESENTS I SURVEY ~",'.'.',' . . ,~5~.~ · 'MADE BY ME OR UNDER MY DIRECT SURERVIglON, ;~'~.'.e,,',, AND THAT .AL& OmEN$~ON$ ,4#0 OTHER % ~,, le ,. ~ /. ,e p .,, . .____ __ D~ f e De ~ cr/~tion ARCO ALASKA, INC. OWG m NSOK. t MO0,C ~A 'ORMX' 6g I$ O 7 ka, Inc. Dr/Il SHe Conducfor$ As-Built OCS Oo~e,'R- It-g/I No. Illll I I Ill I I I UI(IblNA[ / ARCO Alaaka, Inc. Kuparuk River Field AFE: AK-5725 WELL: 2M-23 North Slope Borouqh Alaska Sperry-Sun Drilling Services MWD Completion Report Anchorage, Alaska RECEIVED (907) 563-3256 Blaine Baertmch sea=or D~.e~ti~l ~WD ~ngineer. I~A9 101~92 · AJaska Oil & Gas Cons. Commisslor~ Anchorage TABLE OF CONTENTS SECTION I ......................................... RESULTS SECTION II .................................... WELL SUMMARY SECTION III ...................... COMPLETION SUMMARY OF RUNS SECTION IV ................................ BHA AND BIT DATA SECTION V ........................... DRILLING AND MUD DATA SECTION VI ................................... SURVEY REPORT SERVICE ~£SULTS RUN A: Drilled to 442' and began Kick off. Built to 13.8 degrees with a direction of N 47.3 E with a depth of 1165'. POOH to change BHA to 2 1/2 degree bent sub for more build. RUN B: Finnished ~ick off at 2127' and POOH for 1 1/4 degree bent housing Navi-Drili. Angle built to 47.2 degrees with a direction of N 48.4 E. RUN C: Finnish surface hole with TD of 3532', maintaining angle and direction as needed. Final angle was 50. I degrees with a direction of N 41.9 E. SECTION I WELL SUMMARY JOB NUMBER AK-MW-10037 RIG / PLATFORM KB ELEVATION Doyon 14 140' KB REFERENCE Mean Sea Level SURFACE LOCATION MAGNETIC PARAMETERS 114' FSL~ 529' FWL Sec. 27, T liN, R 8E NORTH REFERENCE True GRID TYPE Universal Transverse Mercator DECLINATION GRID CORRECTION TOTAL CORRECTION START AND ENDING IN-HOLE DAYS 29.20 Degrees 0.00 Degrees 29.20 Degrees 4-1-91 to 4-3-91 START AND ENDING M. D. 115' to 3532' START COORDINATES (Offset) ( N / S ) : ( E / W ) : 0.00' North 0.00' East TARGET LOCATION (From Wellhead) MUD MOTOR SIZE / TYPE MWD PULSER SUB O.D. 4116' North, 3721' East North 42 deg 7 min East 8" Navidrill Mach II, 1.25 deg. 8" Navidrill Mach II, 2 1/2 deg. 8.00" ~#017) ENGINEERS ON LOCATION Blaine Baertsch Tony La Belle SECTION II CONPLET~DN ~,INt~RY OF RUNS ~TE/T~ ~TE/TZNE RUN RUN MODE END B~T NND ~ERVI?..,E OPE'R~T~N6~T~RT END FOOTP~..~' ~VB 9URVEY9 TOOLFP~ES HOURS HD ND DRILLED BPN DETECTED DETECTED 7,6 115 1165 150 4~ 7,7 1165 2127 96~ 450 ~4.-~/14~38 04-~3/01~3~ IRR B ~4-~/~3~ 04-~4/gi:5~ g C §~tee~ I1,8 2127 5 1194 5 1768 7 497 ~ECTION III BI~ ~D B~T D~TA ~O ~UN ~ B]T/N~V]DR]LL(I ~/a ~)/XO/FL~T NI~IOC/N~T~B/NMI)CIXOI~R~/~&~ BIT BIT BIT NO, SIZE TYPE 1 IE JET FOOT~aE ffrART END 115 1165 TOT~ BIT/Nf4VIDRILL/I~/FL~T/MaLCINMDC HC~/NMDC/NI~T~B/NMDC/NM~T~B/NMDC iRR 114" Saith 1165 E127 MWD RUN C BHA: BIT/NAUIDRIL(I 114 BH)/XOIFL~T N~LCtN~TA~/NMI)CIHO~tN~/NM~TAB NMDC/~AB/N~DC/XO/3MHWDP/$AR$ E IE 114" ~ecu~ity lxg, ~x14, s ~1~ 353~ ~ECTION IV DRILL.[N~ ~D MUD ~T~q i~0 I~UN ¢ ~ SP~D SOLID5 PV YP 8. ? TI~qCE 3 ~ I$ 34 9, a I/4 S 6 % 17 Ii) 9.6 1/4 % 8 ~ 18 18 CI~.OIUDES PROI~E TEM 1~,1 16,4 21, I ~CTI~ V · .~PERRY-.~UN ~NTERNATIC]NA!~ SURVEY DATA ~¥ON 14 04-APR-1991 2M-23 12: 40: 37 MEASURED ANGLE DIRECTION VERTICAL LATITUDE DEPARTURE VERTICAL DOG DEPTH DEG DEG DEPTH FEET FEET SECTION LEG 0.00 0.00 N 0.00 E 0.00 0.00 0.00 0.00 0.00 372.00 0.00 N 0.00 E 372.00 0.00 0.00 0.00 0.00 552.00 3.10 N 60.30 E 551.91 2.41 N 4.23 E 4.63 1.72 731.00 7.40 N 50.50 E 730.12 12.15 N 17.33 E 20.64 2.45 911.00 11.30 N 42.40 E 907.70 32.55 N 38.18 E 49.75 2.28 1095.00 13.80 N 47.30 E 1087.30 60.75 N 66.47 E 89.64 1.48 12~7.00 19.90 N 46.10 E 1270.97 98.97 N 106.88 E 145.10 3.18 1474.00 27.40 N 42.70 E 1442.15 152.74 N 159.07 E 219.98 4.07 1657.00 34.20 N 44.70 E 1599.25 220.33 N 223.88 E 313.58 3.76 1847.00 40.90 N 49.10 E 1749.83 299.11 N 308.56 E 428.81 3.80 2030.00 47.20 N 48.40 E 1881.29 383.00 N 404.15 E 555.14 3.45 2249.00 48.20 N 47.30 E 2028.68 491.70 N 524.22 E 716.31 0.59 2431.00 49.40 N 45.50 E 2148.57 586.14 N 623.37 E 852.85 0.99 2675.00 51.30 N 47.80 E 2304.27 715.05 N 760.00 E 1040.10 1.06 2959.00 50.30 N 43.10 E 2480.66 866.60 N 914.04 E 1255.83 1.35 3171.00 50.20 N 42.60 E 2619.42 988.92 N 1027.50 E 1422.65 0.18 3462.00 50.10 N 41.90 E 2805.89 1154.28 N 1177.72 E 1646.06 0.19 THE DOGLEG SEVERITY IS IN DEGREES PER 100 FEET THE VERTICAL SECTION WAS COMPUTED ALONG N 42.12 E BASED UPON MINIMUM CURVATURE TYPE CALCULATIONS. THE BOTTOM HOLE DISPLACEMENT IS 1649.05 FEET IN THE DIRECTION OF N 45.58 E COORDINATE VALUES ARE GIVEN RELATIVE TO THE WELLHEAD AOGCC GEOLOGICAL MATERIALS INVENTORY LIST PERMIT # ~ ~ - ,~q WELL NAME ~i~ c~--~.~ COMPLETION DATE L~ /.. ~ /, c~{ CO. CONTACT ~(~ check Off Or list data as !t,,' !S reCeiv'~d-*,I ist received date for 407. ifnot required list as NR cored intewals core analysis ~¢ d~ ditch intewals digital data i ii iii ii i i i i ii i i i ii i i i ii i iii j i ii ii ii i i J ~ ii ii i L I I lUlll III ~ II IIII I I II I I I I LOG TYPE RUN INTERVALS · SCALE NO. ,{to the nearest footJ linqh!l' 00~] ....... I i i i i I _ _ ii i ij i i i i i i I II tLII L II I I I I I I IIII Ill I , L I I III II ~ I I I I I I AOGCC GEOLOGICAL MATERIALS INVENTORY LIST CO. CONTACT & NO. fo'rm ' received ,eceiYed doie' comments 407 ~.~s~_..._~ '~ no ~)/~ ~ c"~iction re.o. ' 403 yes no .... ' 'su'nd~ application 404 yes no 'repo~ of sund~ application ii I I I II I II I --'~p-~'~- ~e'q~iii;e'd-' -r~iVed .... ~ased-~'~q~li~:l~i'-' -re-ce'i~,~-~i' ~r~'~i0r'~equired received . hole log hole log .!0g MUD GCT TEMP DI~SFL " CNL PROD DLL , , , BHCISL ~ CET SPINNER .... ~ .... , ..... ~r ~ ............. BHCIAC E~ OTHER DATA LSS PERF Saucy 'SSS PACKEn ........ Digital '' Data FDc- FDC '' RwD ,equhed'[received SAMPLES' 'r&quiredreceived MWD LDT/cNL " 1~ '~ ~ ~ d~ ditch , ............ ¢/ CYBER core LOOK , , Analysis .... FMS , ,, , ,, , , , .... ,,, , , .... ~ , , , , ,, ..... , , , , ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 January 15, 1992 Mr. L. C. Smith Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ENG ASST I GEOL ASSTi!'' ' ,~TAT TECH, Dear Mr. Smith' SUBJECT' Tarn #1 and Fiord #1 ?/- .2/~ Exploration Wells Drill Cuttings and Drilling Mud Disposal at KRU Well #2M-23 ARCO Alaska, Inc. as operator of the exploration wells Tarn #1 and Fiord #1, would like to inform the AOGCC that all drill cuttings and excess drilling mud generated by drilling operations on these two wells will be hauled to Kuparuk River Unit 2M pad and injected in KRU Well #2M-23. A ball mill is located at 2M-23 which will grind the cuttings to allow injection into this disposal well. This disposal plan was verbally discussed with the Commission but no formal mention was made of this plan in the application for permit to drill for these two wells. (Tarn #1 approved permit #91-151 and Fiord approved permit #91-147). If ARCO can furnish any further information, contact me at 263-4962 or Tim Billingsley at 265-6575. Sincerely, A. W. McBride Area Drilling Engineer CC: T. A. Billingsley W. J. Penrose Tarn #1 General Wellfile Fiord #1 General Wellfile RECEIVED dAN 1 7 1992 Alaska 0il & Gas Cons. Comm[ss[o~ Anchorage ARCO Alaska, Inc. Date: June 7, 1991 Transmittal #: 8126 RETURN TO: ARCO Alaska, Inc. ATTN: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Cased Hole items. return one signed copy of this transmittal. Acoustic Cement Bond Log Acoustic Cement Bond Log Acoustic Cement Bond Log Pulse Echo Cement Evaluation Log Pulse Echo Cement Evaluation Log Pulse Echo Cement Evaluation Log Pulse Echo Cement Evaluation Log After Squeeze Please acknowledge receipt and 4-8-91 4-5-91 1-19-91 4-6-91 4-8-91 1-19-91 4-24-91 4529-7334 72-3430 5700-8140 27-3431 4424-7333 5700-8116 7000-8375 Receipt Drilling Acknowledge' · State. o[Naska(+sepia) ARCO Alaska, Inc. Date: April 25, 1991 Transmittal #: 8076 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Open hole items. and return one signed copy of this transmittal. Dual Induction-SFL 5" Phasor Dual Induction-SFL 2" Phasor Litho Density-CNL-GR 2" & 5" Porosity Litho Density-CNL-GR 2" & 5" Density Dipole Sonic Log 2" & 5" Delta Time Dipole Sonic Log Coherance Log Cyberlook Compensated Dual Resistivity Compensated Density Neutron Gamma Ray High Resolution Induction DFL 2"/100' High Resolution Induction DFL 5"/100' Spectral Density Dual Spaced Neutron Raw Data Spectral Density Dual Spaced Neutron High Resolution Pass Spectral Density Dual Spaced Neutron Porosity Please acknowledge receipt 4-13-91 2928-6810 4-13-91 2928-6810 4-13-91 3000-6795 4-13-91 3000-6795 4-13-91 2928-6795 4-13-91 2928-6795 4-13-91 3000-6795 4-7-9-91 4565-8700 4-7-9-91 4565-8700 4-3-91 114-3519 .4-3-91 114-3519 4-3-91 1400-3529 4-3-91 1400-3585 4-~3-91 1400-3585 pp, 2 5 1991 Alaska 0il & Gas Cons. ARCO Alaska, Inc. Date: April 25, 1991 Transmittal #: 8077 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. one signed copy of this transmittal. 2M-23 Receipt Please acknowledge receipt and return LIS Tape and Listing(Colville) 4 - 3 - 9 1 Acknowledged: ~~----~-- 93.5-3550 Date' - ......... DISTRIBUTION: Lynn Goettinger State of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION March 29, 1991 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 A. W. McBride Area Drilling Engineer ARCO Alska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 2M-23 ARCO Alaska, Inc. Permit No. 91-34 Revised Sur Loc 114'FSL, 529'FWL, Sec. 27, T11N, RSE, UM Btmhole Loc1358'FSL, 1653'FWL, Sec. 27, T11N, RSE, UM Dear Mr. McBride: Enclosed is the approved revised application for permit to drill the above referenced well. The provisions of the cover letter dated March 5, 1991 accompanying the original approved permit are in effect for this revision. rely, //-) Commissioner Alaska Oil and Gas Conservation Commission dlf EnclosUres CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ARCO Alaska, Inc. Post Office B~^ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 29, 1991 Mr. Lonnie Smith Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith: SUBJECT: Application for Revised Permit to Drill KRU Field Well 2M-23 (Temporary Disposal) Attached is a revised application for Permit to Drill for the above referenced well. The surface casing portion of this well will be used for temporary disposal of drilling fluids and other fluids incidental to the drilling of wells on Drill Site 2M in the Kuparuk River Field. The plan for handling these fluids utilizes a solids processing module to eliminate the need for a reserve pit at Drill Site 2M. Most, if not all, of the drilling fluid waste would be pumped down this well instead of the annulus of the previously drilled well. The exact injection interval will be selected from open hole logs of the well. After log analysis of the well, the 9-5/8" casing would be run to 3460' MD or 2790' TVD. A CBL would be run to ensure cement integrity, the well perforated, and a packer and tubing run for the completion assembly. After all of the other wells on the pad have been drilled, the injection interval in this well would be squeezed off and this surface casing utilized to complete the drilling of 2M-23 as a normal producing oil well. We have reviewed the likelihood of formations in this well having recoverable hydrocarbons, and anticipate that the Ugnu is water wet in this area of the Kuparuk River Field. A final decision on 2M-23 will have to be made after review of the open hole logs. ARCO Alaska, inc. is a Subsidiary of AtlanticRichfieldCompany RECEIVED · .,' ,.2 j '..~'~,,,~, 0fl ~ flas Cons. Commiss~a~ Mr. Lonnie ,nith Application for Permit to Drill Well 2M-16 (Temporary Disposal) January 17, 1991 Page 2 If for any reason that this method of disposal is impractical, ARCO would utilize annular pumping that has been standard procedure in the past. Mark Prestridge of this office has had general conversations with Blair Wondzell of your office about this concept. Either Mark or myself would be happy to visit with you further if you need more information regarding the project. Thank you for your assistance in this matter. Sincerely, Area Drilling Engineer AWM/TAB/MLP attachment STATE OF ALASKA · ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.OO5 ! la. Type of Work Drill X Redrill I lb. Type of Well Exploratory Stratigraphic Test Development Oil_ Re-Entry DeepenI Service X Development Gas__ Single Zone ~ Multiple Zone 2.. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska. Inc. RKB 140', Pad 105' GL Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25586 ALK 2672 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 114' FSL, 529' FWL, Sec. 27, T11N, R8E, UM Ku_oaruk River Ur}it Statewide At top of productive interval (TARGET) 8. Well number Number 1,358' FSL, 1,653' FWL, Sec. 27, T11N, R8E, UM 2M-23 #U630610 At total depth 9. Approximate spud date Amount 1,358' FSL, 1,653' FWL, Sec. 27, T11N, R8E, UM 04-01-91 $200~000 12. Distance to nearest 13. Distance to nearest well 14. Nmber of acres in property 15. Proposed depth (MD and TVD) property line 2M-24 (Proposed) 3,460' MD 3,627' @ TD feet 25' at SURFACE feet 2560 2,790' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 500 feet Maximum hole an~lle 50° Maximum surface 1,150 psl~l At total depth (TVD) 2,790' 1,451 psig 18. Casing program Setting Depth size Specification T~=p Bottom Quantity of cement Hole Casin~l Wei~lht Grade Couplin~l Len~lth IVD TVD bO TVD (include sta~le dataI 24" 16.0" 62.5# H-40 Weld 80' 35' 35' 115' 115' +200 CF 12.25" 9.625" 36.0# J-55 BTC 3,460' 35' 35' 3,460' 2,790' 485 SxAS III & HF-ERW 650 Sx Class G 19. To be completed tot Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured leer Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical ,,, 20. Attachments Filing fee_ Property plot __ BOP Sketch_ Diverter Sketch ~ Drilling program Drilling fluid program ~ Time vs depth plot __ Refraction analysis__ Seabed report __ 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Si~ned '~/~~~¢,~,'¢:V~ Title Area Drilling Engineer Date-~/~/~/ Commission Use Only ~ermit N~:~er~ I APl number I Approval date I See cover letter for - 50- ,/O 3 ' ~ O/,.,~ 0 3 / 0 ~ / ~) ~ other requirements Conditions of approval Samples required __Ye s ~ N o Mud log required __ Yes ;~ N o Hydrogen sulfide measures__ Yes ~ N o Directional survey required ~;~Yes __ N o Required working pressure for BOPE ~2M; ~M; ~ 5M; ~ I OM; ~ I 5 M Other: " .Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-~1~' Submit in IriDlicate GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 2M-23 (Temporary Disposal) 1. Move in and rig up Doyon Rig 14. 2. Install diverter system. 3. Drill 12-1/4" straight hole to 9-5/8" surface casing point (3,460'). 4. Log well with open hole wireline logs from TD to surface. 5. Run and cement 9-5/8" casing. Pressure test to 2,000 psi. ' 6. ND diverter and install 11" 3,000 psi casing head. 7. Run cased hole cement evaluation logs. 8. Install and test BOPE. 9. Run CIBP to just below designated injection zone. 10. Displace hole with diesel. 11. Perforate and run completion assembly, set and test packer. 12. Pressure test tubing casing annulus to 1,500 psi for 30 minutes. No more than a 10% leakoff is acceptable in 30 minutes. A State of Alaska representative must be notified to witness this test. 13. ND BOPE and install injection tree. 14. Shut in, secure well and release rig. N 4.2 DEG 7 MINE 554.9' (TO TARGET) Scale ! · 200.00 .oo,0, // 3300 / uo~ ~ ~=,~ ~.,~ ~-2s~ ' I~Lt' rSL. ~, ' [~C. 27, r11N, ~ 3g.~ · ~ ~:~,':, Oil & 6as Cons. Commiss~m'~ , ~ ~n~horaga AVERAGE ANGLE ~o OEG 1~ ~IN ! , , , , ! , i , , , i i , , ! ~ i i ! i ! 1 Vertical Section o~ 42.11 azimuth with reference 0.00 N, 0.00 C from slof j~23 30O 250 I 200 150 . I I I00 I I I I 0 . I I I I00 . 200 250 I I , I % '~3700 % % 300 350 400 450 I I 9O0 I I I I I I ,I I ZOO I I I I I 1500 300 \'q 900 \ \ \ \ 500 1 \ \ I I I 200 250 300 I I 350 400 I 450 ~,$oo %'3300 · 300 550 t 600 I 650 ! ! / 900 ! ! /' ?oo 300 ',~3oo I 500 / / / / /I I00 / / · 300 \ \ % ~soo 550 600 ! ! -. / / l 700 I I I I I '1 ~ "900 I' '1 650 700 300 .250 200 Ii50 . I00 5O 5O . I00 DRILLING FLUID PROGRAM (2M-23 Disposal) Spud to 9-5/8" surface casin~] Density 8.6-10.0 PV 15-35 YP 15-35 Viscosity 50-100' Initial Gel 5-15 10 Minute Gel 15-40 APl Fluid Loss 10-12 pH 9-10 % Solids 10% + Drillina Fluid System: - Tandem Brandt Shale Shakers Tandem Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuge,Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators N~te$: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. The nearest well to 2M-23 is 2M-24 (proposed). As designed, the minimum distance between the two wells would be 25' at surface. The wells would diverge from that point. Excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be hauled to the nearest Kuparuk Field disposal well. *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds. KJPARUK RIVER UNI'~ 20" DIVERTER SCHEMATIC 5 HCR ] , CI I 5 4 3 2 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTENANCE & OPERATION . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUEST S APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(B) 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16"- 2000 PSI BALL VALVES 4. 20" - 2000 PSI DRILLING SPOOL WITH TWO 1(7' OUTLETS. 5. 1(7' HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20" - 2000 PSI ANNULAR PREVENTER SRE 2/6,'90 ALASKA OIL AND GAS CONSERVATION COMMISSION March 5, 1991 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 A. W. McBride Drilling Engineer ARCO Alaska, Inc. "~P~' O. Box I00360 Anchorage, AK 99510-0360 re: Kuparuk River Unit 2M-23 ARCO Alaska, Inc. Permit No. 91-34 Sur. Loc. ll4'FSL,. 529'FWL, Sec. 27, TllN, R8E, UM Btmhole Loc. 805'FNL, 808'FEL, Sec.'27, TllN, RSE, UM Dear Mr. McBride: 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. The Commission will advise you of those BOPE tests that it wishes to witness. Sincerely, David W. ~ohns~on, Chairman Alaska Oil~,q~Gas Conservation Commission BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill -- I lb. Type of Well Exploratory__ Stratigraphic Test _ Development Oil .~X Re-Entry _ Deepen --I Service _ Development Gas __ Single Zone X Multiple Zone _ 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 140', Pad 105' Gl,. feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25586 ALK 2672 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 114' FSL, 529' FWL, Sec. 27, T11N, R8E, UM Kuparuk River Unit Statewide At top of productive interval (TARGET) 8. Well number Number 1050' FNL, 1030' FEL, Sec. 27, T11N, RSE, UM 2M-23 #U630610 At total depth 9. Approximate spud date Amount 805' FNL, 808' FEL, Sec 27, T11N, R8E, UM 29-MAR-91 $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 2M-24 (proposed) 8926' MD 805' @ TD feet 25' at surface feet 2560 6285' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 500' feet Maximum hole angle 50° Maximum surface 1660 psi~ At totaldepth (TVD) 3470psi~1 @ 6285 18. Casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casin~l Weight Grade Coupling Length IVD TVD IVD TVD {include stage dataI 24 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' +200 Cu.Ft. 12.25 9.625 36.0# J-55 BTC 3425 35' 35' 3460' 2790' 1110 Cu. Ft. AS III & HF-ERW 660 Cu. Ft. Class G 8.5 7" 26.0# J-55 BTC 8891 35' 35' 8926' 6285' Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen OperatiOns. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true verticaltrue vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Cu. Ft. RECEIVED Intermediate Production Liner F[~B 2 8 1991 Perforation depth: measured true vertical ~bS~.~. Gas Cons, ~0. Attachments Filing fee ~ Property plat ~ BOP Sketch ~ Diverter Sketch ~ Drilling program _~.' " Drilling fluid program ~ Time vs depth plot ~ Refraction analysis _ Seabed report _20 AAC 25.050 requirements ~ 21. I hereby certify that the foregoing is true and correct to the best el my knowledge Signed Title Area Drillincj Engineer Date Commission Use Only Permit Number I ^P, number I ^ppro. va, d. te I See cover 'e,ter 'or ~/~-,.~ ~ $0-/e 2 -..~o / 5'~ 0.3 / 0 5 / cfi I other recluirements Conditions of approval Samples required ~Yes ~ N o Mud log required__ Yes ~ N o Hydrogen sulfide measures__ Yes .~ N o Directional survey required ,,Y,.. Yes __ N o Required working pressure for BOPE ~2M; .,~ 3 M; __ 5M' ~ 1 0M' __ 1 5 M Other: Form 10-401 Rev. 7-24-89 " " Su~ in triplicate ARCO A ASKA Structure · Pad 2M Well ' 23 Field · Kuparuk River Unit Location · North Slope, Alaska Iireat. ed by : jones For] TIM BILLINGSLEY ate plotted ] 7-Feb-91 Plot Reference is 23 version ~2. oordinates are in feet reference clot t23. rue Vertical Depths are reference wellhead FT)]~ EAST MAN IZ//JLIIIC H R ISTE N S E N N 42 DEG 7 MINE 5549' (TO TARGET) East --> 0 400 800 1200 1600 2000 2400 2800 3200 I I t I I I I I I I I I I I I I I TD LOCATION: 805' FNL, 808' FEL SEC. 27, T11N, RBE I TARGET LOCATION:I 1050' FNL, 1030' FEL SEC. 27, T11N, RSE TAROET IVD=6010 TMD=8496 DEP=5549 NORTH 4-116 EAST 3721 400 800 1200 _ 20OO- - 2400- - 2800- - 3200- - - 40OO- _ 44~- - 4800- _ 5200 - 5~ - _ 60~ - _ ~4~ - Stole 1 ' 200.00 RKB ELEVATION; 140' KOP TVD=500 TMD:500 DEP=O 3.00 g.o0 15.00 21.00 BUILD 3 DEG/IO0 FT ~ 27.00 B/ PERMAFROST 7VD=1390 TMD=1426 DEP=220 33.00 T/ UGNU SNDS ]1/D=1460 TMD=1506 DEP:259 39,00 45.00 EOC 'fVD=1968 TMD:2175 DEP=689 T/ W SAK SNDS'rVD=2025 TMD=2264 DEP=757 B/ W SAKSNDS TVD=2590 TMD=3147 DEP=14.36 9 5/8"CS(3 PT 1VD=2790 'fMD=3460 DEP=1677 K-lO 1VB=2870 'fMD=3585 TMD=1773 Surface Location 114' FSL, 529' F-WL SEC. 27, T11N, RSE K-5 '[VD=4360 TMD:5915 DEP:3565 AVERAGE ANGLE 50 DEG 1,.5 MIN i 1200 TARGET - T/ ZONE C TVD=6010 TMD=8496 DEP=5549 T/ ZONE A 'r,/D=6027 TMD=8523 DEP=5569 B/ KUP SNDS 'fVD=6157 TMD=8726 DEP=5725 ~ TD / LOGGING PT TVD=6285 TMD=8926 BEP=5879 i i i i i i i i i I i i i i i i i i i i i 1 i i i 1600 2000 2400 2800 3200 5600 4000 4400 4800 5200 5600 6000 Vertical Section on 42.11 azimuth with reference 0.00 N, 0.00 E from slot #23 3600 II -4400 _ -4000 _ -3600 _ - 3200 _ -2800 _ - 2400 _ -2000 _ -1600 _ -1200 80O A I I Z O :300 . 250 200 250 ~00 ~$0 400 I I I I I 200 ~ '~ I 1 50 _ 100 . 50 . O . 50 1 O0 '~'~?00 "~,$oo ~"'G300 · 300 450 ,I 1900 I I I I I I I ~ I ?00 I I I I I t' ~soo I ! r ! 3oo 'q}O ;o OO \ Xoq 000 \ \ \ \ 500 I 55O I 600 I ! / /' 900 ! ," 700 * 300 ! * 300 ! / / / / ~'! 100 "2300 \ \ \ \ \ "~.soo 650 I ' /"'1300 ~ ~ ='go0 I I I I I I I 200 250 :300 :350 400 450 500 1 I 550 \ 600 I I 650 700 700 25O 2OO 150 _ 100 .5O _0 5O 100 DRILLING FLUID PROGRAM (2M-23) Spud to 9-5/8" Drill out to Weight up surface casing weight uo to TD Density 8.6-10.0 8.6-9.6 10.6 PV 15-35 5-15 10-18 YP 15-35 5-8 8-12 Viscosity 50-100' 30-40 35-50 Initial Gel 5-15 2-4 2-4 10 Minute Gel 15-40 4-8 4-8 APl Filtrate 10-12 8-10 4-5 pH 9- 1 0 8.5-9 9.0-9.5 % Solids 10 +/- 4-7 10-12 Drilling Fluid System: - Triple Tandem Shale Shaker - (2) Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual and Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: - Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. - Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 1660 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 2M-23 will be 2M-24 (proposed). As designed, the minimum distance between the two wells would be 25' at surface. The wells would diverge from that point. Excess non-hazardous fluids developed from well operations will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shut down in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. * Spud mud should be adjusted to a funnel viscosity between 100-120 to drill gravel beds. 7 6 5 4 I3 13 5/8" 5000 P,.,I BOP STACK ACCUMUI,,ATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC 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 ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 6. TESTTO 250 PSI AND 3000 PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS 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. 9. OPEN PIPE RAMS. BACKOFF RUNNING JTAND PULL OUTOF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" -2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR SRE 8/22/89 DOYON 14 KJPARUK RIVER UNI'I 20" DIVERTER SCHEMATIC ! HCR 3 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTENANCE & OPERATION UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUEST S APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(B) 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16"- 2000 PSI BALL VALVES 4. 20" - 2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20"- 2000 PSI ANNULAR PREVENTER SRE 2/6/90 GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 2M PAD , . , . . . , . . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. Move in and rig up Doyon 14. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test. Drill 8-1/2" hole to logging point according to directional plan. Run open hole evaluation logs or RLL as needed. Run and cement 7" casing. (Isolation of the Colville sands will be performed if there is hydrocarbon presence.) Pressure test to 3500 psi. ND BOPE and install temporary production tree. Secure well and release rig. Run cased hole cement evaluation and gyro logs Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Change over to diesel Shut in and secure well. Clean location and release rig. · :~ CHECK LIST FOR NEW WELL PERMITS Company /~r~ ' ITEM APPROVE DATE <~ ~,~ ~', ,~~ ~. ~ t~. ~i~ ~. ~=~ .......................... ,...... . 2. poo .................. i ' 4. Is well located proper distance from other wells ......... 5. Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is wellbore plat included .... 7. Is operator the only affected party ...................... · ~,~,~,./'~L 3-2/-9/ 8. Ca: pemit be approved before fiftee~-da~ wait .......... (3) (9 thru 10. (10 and 13) 12. 13. (4) Casg ~..~:.~. ~.. ~-~- ~/ (14 thru 22) 14. 15. (5) BOPE (23 thru 28) 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number ......................... Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground, source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ P Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequately, Are necessary diagrams and descriptions of diverter and BOPE attached..~ Does BOPE have sufficient pressure rating - Test to ~ooo psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence :of H2S gas probable ................................. ~O th~u 31)' (6) Add: Geology: DWJ EngSneering: ~cs ~ ~ ~__ rev: 01/30/89 6.011 For 29. 30. 31. 32. ' ' INITIAL' ' GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE ,,, exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. . Are seismic analysis data presented on shallow gas zones ............ .. If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. Additional Ke'mhrks: ~' CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (1) Fee ~ ~,//~//~/ 1. (2) Loc " (2- ~-hr~ 8) ,.. (3> Admin Z£L '('9 thru (10 and 13) (4) Casg (14 thru 22) (23 thru 28) Company Is the permit fee attached .......................................... Lease & Well No. YES NO 2. Is well to be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... e 10. 11. 12. 13. Does operator have a bond in force .................................. ~. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ......................................~ Does the well have a unique name and number ......................... ~ 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... ~ Is the drilling fluid program schematic and list of equipment adequate,~ Are necessary diagrams and descriptions of diverter and BOPE attached. ~ Does BOPE have sufficient pressure rating - Test to ~~ psig .. ~ Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. ( 6 ) OTHER ~_~/~ 2_//~/,,~ '(29- thru 31) (6) Add: Geology: DWJ ~ En~ineerin~: LCS i BEW ~ rev: 11/30/90 6.011 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Additional Remarks: o ~o 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. DIRECT DIGITAL LOGGING COI'IPUTER PROCESSED ANALYSIS ..LLLLLLLLL .LLLLLLLLL DDDDDDDDD UU UU DDDDDDDDDD UU UU DD DD UU UU DD DD UU UU DD DD UU UU DD DD UU UU DD DD UU UU DD DD UU UU DD DD UU UU DO DD UU UU DDDDDDDDDD UUUUUUUUUUUU DDDDDDDDD UUUUUUUUUU MM MM HHM HHH HHHH HHHH HH MM MM NH NM HHHH HH HH HH HH HH HH HH NH HH HH HH HH HH HH MM MH PPPPPPPPPPP PPPPPPPPPPP PP P: PP P PP P PPPPPPPPPPP, PPPPPPPPPPP PP PP PP PP PP ~22222222 :222222222 22 22 22 22 22 22 22 :222222222 1222222222 2222222222 222222222222 22 22 22 22 22 22 22 22 22 222222222222 222222222222 III AA ~A A~ ~A AA AA AA AA AAAAAAAAAAAA AAAAAAAAAAAA AA AA AA AA AA AA AA AA 444 4444 44 44 44 44 44 44 44444444444 444444444444 44 44 44 44 44 PPPPPPPPPPP PPPPPPPPPPPP PP PP PP PP PP PP PPPPPPPPPPPP PPPPPPPPPPPP PP PP PP PP PP 555555555555 555555555555 55 55 55 555555555 5555555555 55 55 55 555555555555 55555555555 RRRRRRRRRRR RRRRRRRRRRRR RR RR RR RR RR RR RRRRRRRRRRRR RRRRRRRRRRR RR RR RR RR RR RR RR RR RR RR PPPPPPPPPPP PPPPPPPPPPPP PP PP PP PP PP PP PPPPPPPPPPPP PPPPPPPPPPPP PP PP PP PP PP 9999999999 999999999999 99 99 99 99 99 99 999999999999 999999999999 99 99 99 99 999999999999 9999999999 MM H HMH MM HHHH MMH MM MM MM H HH HHHH H HH MM MM H HH H HH H HH H: HH H: MM Hi 11 111 11 11 11 11 11 11 11 lililillll 1111i11111 REEL HEADER **** .Service n~m¢~ &GSF01 Previouz reel: Date: 91/04/22 Comment~: HEADER Origin: RECORDS Reel name Page: Continuation #: 01 Smr. vicm name: &GSF01 Previous .tape: 'Date: 91/04/22 Comments Origin: Tape 666072 Continuation #: O1 FILE HEADER **** File name: .001 Service namm: Version Maximum lmngth: 1.024 Fila typm: LO Previous {'Jim: MNEM WN FH COUN BTAT OTRY APIN LATI LONG SECT TOWN RANG EKB £DF PD LHF RUN TIME DATE LCC SON LUN FL LUL ENGI WITN DL CBDI CBL1 TLI BLI TCS TLAB BHT MRT ~T DFD ~VIS DFPH DFL RM R~F MFST MFS$ I HFORMAT I OH CONTENTS ARCO ALASKA INC. 2M-23 KUPARUK NORTH SLOPE ALASKA USA ~0155.000 .......... 0 Deg. 0 Min. 0 0 Deg. 0 Min. 0 27 ............ I IN ........... O@E ........... 140.000 ....... ~J~.O00 1~5.000 ....... MS. ...... , .... 138.000 3/ 4/~1 ....... 30 5~g39 ..... NORTH SLOPE NORTH SLOPE HcKAY SANBORN/VICKER$ J5~7.000 ......... 1~5.000 .......... 114.000 .......... 114.000 .......... ~S19.000 ......... 20~8.~00 ......... ~38.000 88.000 ........... 88.000 ........... SPUD CIRCULATED 9.400 .......... 5~.000 9.000 .......... 1~.000 ......... 6~770 .......... 8.170 68.000 MEAS 4.560 API NUM: 50-103'-20155 DATE LOGGED: 04-03-91 Sec , Illlll I1111 IIIII I II I I! I IIII I 11 I II I II 11 II I It I II 11 I RECORDS . . . . UNIT TYPE CATG SIZE CODE 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 FT 0 3 FT 0 3 FT 0 3 0 3 0 3 0 3 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 FT 0 3 FT 0 3 FT 0 3 FT 0 3 FT 0 3 FT 0 3 HR 0 2 HR 0 4 DEGF 0 1 DEGF 0 1 LB/G 0 2 CP 0 2 0 2 0 2 OHMM 0 2 OHHM 0 2 DEGF 0 2 0 2 OHMH 0 2 40 40 40 20 20 20 4 34 34 2 3 3 4 4 4 2 2 2 2 4 2 10 20 2O 20 20 4 4 4 4 4 4 4 4 4 4 20 20 4 4 4 4 4 4 4 12 4 65 65 65 6,5 6,5 6,5 65 65 6,5 ,6,8 6,8 68 65 65 65 79 6,5 79 65 6,5 65 65 6,5 65 68 68 68 68 68 68 68 6,8 68 6,5 65 6,8 68 68 68 68 65 6,8 Page ERROR MNEH HCST B$ I NFORMAT 1 ON RECORDS CONTENTS UNIT 69,000 HEAS ............................................. 16.000 .................................. ................ 12,250 .................................................. DEGF TYPE CATG SIZE 4 12 4 4 CODE 68 68 68 page ERROR COMMENT RECORDS Well Location Comment l: SURFACE: Well Location Comment 2: Well Location Comment 3: Well Location Comment 4: Well File Comment l: HRI-SDL?DSN RUN Well File Comment 2: Well File Comment 3: Well File Comment 4: 114' FSL & 529' FWL IN COMBINATION, CHLORIDES = 350 PPM, SHIFTED SP BETWEEN REEPRT & MAIN PASSES. TENSION CURVES 46.25 FEET TO TOOL ZERO, DSN RUN WITH BOWSPRING DECENTRALIZER, LIS tap~ written by: ANCHORAGE COMPUTING CENTER All curve and tool mnemonics used are those which most clos~lp match Halliburton curve and tool mnemonics. HALLIBURTON TO $CHLUHBEROER TOP BOTTOH MNEN SERVICE UNIT MNEM SERVICE UNIT DEPTH DEPTH DEPTH FT DEPT FT GR SCL GAPI GR SCL GRPI FDSN DSN2 CPS FDSN DSN2 CPS NDSH DSN2 CPS NDSN DSN2 CPS NPHI DSN2 DECP NPHI DSN2 DECP NRAT DSH2 C/C NRAT DSN2 C/C DPHI SDL DECP DPHI SDL DECP DRHO SCL G?C3 DRHO SCL G?C3 FSDL SCL CPS FSDL SDL CPS NSDL SCL CPS NSDL SCL CPS 80 O0 93 50 93 50 9,3 50 93 50 93 50 93 50 93 50 93 50 93.50 3560.00 3550.00 3550,00 3550,00 3550,00 3550.00 3550,00 3550,00 3550,00 3550,00 Pag~ PE PELC QL QS RHOB CALI HDR HDX HMR HDR$ HHR$ HDCN HMCN OFL SP TENS DLOD SDL SDL SDL SDL SDL SDL HRI HRI HRI HRI HRI HRI HRI HRI HRI HRI SI)L IN OHMH OHHH HHHO NNHO OHHH NV LB LB PE PELC QL RHOB CRLI HDR HDX HHR HMX HDRS HHRS HDCN HNCH DFL 8P TENS DLOD SDL SDL SDL SDL SDL SDL HRI HRI HRI HRI HRI HR I HRI HRI HRI SDL SDL G?CJ IN OHMM OHMM MHHO MHHO OHMH LB LB 93.50 93,50 93,50 93,50 93,50 93.50 9J,50 93,50 93.50 93.50 93,5O 93.50 93,50 93.50 93,50 93,50 3550..00 3550,00 3550,00 3550,00 3550.00 3550.00 3550,00 3550.00 3550,00 3550,00 3550,00 3550.00 3550 O0 3550 O0 3550 O0 3550 O0 3550 O0 3550 O0 DATA FORMAT SPEC I F I CAT IONS ENTRY BLOCKS ENTRY ENTRY BLOCK LEGEND TYPE DESCRIPTION 16 Datum sp~ci¢ication block zub-t~pe 0 T~rminator ( no mor~ ~ntriez TYPE 16 0 SIZE CODE 66 Page DATA FORMAT SPECIFICATIONS ************************************* ~** DATUH SPECIFICATION BLOCKS **** MNEH SERVICE SERVICE API API API APl FILE ID ORDER # UNIT LOC~ TYPE CLASS HOD ~ DEPT 666072 FT 0 0 0 0 I GE SDL 666072 C~API 94 0 0 i 13 FDSN DSN2 666 072 CPS 94 0 0 1 0 NDSN DSt42 666 072 CPS 94 0 0 I 0 NPH i DSN2 666 072 DECP 94 0 0 1 0 HEAT DSN2 666072 C?C 94 0 0 I 0 DPHI SDL 666 072 DECP 94 O 0 1 0 DRHO SDL 666072 G?C3 94 0 0 1 0 FSDL 'SDL 666072 CPS 94 0 0 1 0 NSDL SDL 66607;2 CPS 94 0 0 t 0 PE SDL 666072 94 0 0 1 0 PELC SDL 666072 94 0 0 1 0 QL SDL 666072 94 0 0 1 8 QS SDL 6660;'2 94 0 O 1 0 RHOB SDL 666072 G/C3 94 O 0 1 O CALI SDL 666072 IN 94 0 0 1 0 HDR H. RI 666072 94 0 0 t 0 HDX HRI 666072 94 0 0 I 0 HHR HRI ' 666072 94 0 0 1 13 HHX HRI 666072 94 0 0 I 0 HDRS HRI 666072 OHHH 94 0 0 1 0 HMRS HRI 666072 OHHH 94 0 0 1 0 HDCN HRI 666072 MHHO 94 0 0 I 0 HMCN HRI 666072 HHHO 94 0 0 1 0 DFL HRI 666072 OHHH 94 0 0 1 13 8P HRI 666072 HV 94 0 0 i 8 TENS SDL 666.072 . LB 94 0 t3 1 0 DLOD SDL 666072 LB 94 0 0 1 0 PRC # SIZE LVL SMPL RC 4 0 1 68 4 0 i 68 4 0 1 68 4 0 1 68 4 0 i 68 4 0 i 68 4 0 1 68 4 0 1 68 4 0 i 68 4 0 t 68 4 0 i 68 4 0 I 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 i 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 t 68 4 O I 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 PROCESS INDICATORS 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000'000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 O00000 000000 000000 000000 O0000O 000000 000000 000000 Page DEPT FSDL HDR DFL 3550 '11391 3 3588 '11983 169 3400 '10629 ii7 5 3300 10979 eo 7 3200 11098 72 3100 10658 104 4 3000 11113 4 2900 12035 146 2 ,000 .674 .980 ,636 ,000 ,674 ,279 ,155 ,000 ,875 .606 ,304 ,000 ,273 ,510 ,615 ,OOO .475 ,363 ,677 ,000 ,475 ,859 ,.095 ,000 ,875 ,817 ,647 ,000 ,475 ,112 ,976 GR NSDL HDX SP FDSN PE HMR TENS 107. 18413. --I, -999. 107, 18373, 20, 492. 87, 18138, 15. 489, 79. 18235. 10, 483, 63, 18125. 12. 476, 86. 18001 , 7. 49,3, 78, 18167, 8, 492, 88. 18528, 26, 494, 026 055 089 250 026 055 746 235 569 199 263 785 581 055 723 158 517 340 170 552 777 484 433 723 827 770 788 845 398 910 089 590 1377,644 2,571 7,826 2861,229 1377,644 2,063 i95,029 2746,780 1415,531 2,563 132.207 2932.617 1494,283 2,569 87,448 2861,229 1392,466 2.523 71,789 2746,780 1301,753 2,771 139,478 2816,311 1316,963 2,587 127,1 03 2675,250 I ! 91. 728 2,732 184. 929 2618,025 DATA NDSN PELC HMX DLOD 13664,148 2,637 -.208 1 057.3 i 3 13664,148 3,642 4,393 990,679 1391 0,250 2,670 10.000 1 073.140 14274.740 2,834 18..483 1115,619 13747,766 2,653 11,699 1069,808 13445.697 2,980 4,862 1140,607 13569.707 2,795 4,497 1072,307 12968,135 2.765 33.240 1053,i49 RECORDS HPH I QL HDRS .465 ,039 110,237 ,465 -.429 4.762 ,463 ,037 7,889 ,438 ,012 10.905 ,461 ,004 14,436 .487 -,019 7,376 .486 -,000 7,283 ,528 -,125 5,244 NRAT QS HHRS DPHI RH08 HDCN DRHO CALl HHCN 1 0.530 -,015 i 59,085 ,302 2,152 9,071 ,054 12.250 6.286 10,530 -,500 4.647 ,329 2,106 209.979 ,037 12.250 215.209 433 -.001 7,475 .281 2,186 126',756 .048 12,305 133,782 10.142 -,OOi 10,750 .289 2,173 91 .702 .050 12.928 93, O20 1 O, 482 .08;8 13,985 ,304 2.148 69,271 ,037 12.470 71 ,504 0. 966 ,022 6,532 .288 2,175 i35.583 ,039 12,492 153,081 1 0,940 ,023 6.546 ,302 2,152 137.301 ,040 12,590 152.765 11,553 .002 4,788 ,326 2.112 190,702 ,048 12,337 208.837 Page DATA DEPT ~R FDSN NDSN FSDL NSDL PE PELC HDR HD~ HHR HHX DFL SP TENS DLOD 2800. 000 70.746 1412.441 14083.408 '10929.475 18482.770 2.836 3.016 63.9! 8 9.400 62. 240 16. 929 11 . 924 488.175 2532. i88 1 057.313 2700. 000 68.214 1484.793 14140.367 0269. 074 17957. 770 2. 800 2. 876 75 . 828 2 . 83i 77.211 19. 656 10.657 491 .338 2346.208 969.855 2600. 000 70. 057 1381 .555 13906.576 0499. 674 18054. 770 3. 026 2. 994 7;3. 222 16. 722 72. 898 39.219 1 O. Ol 0 489..385 2317. 596 965. 690 2500 . oo 0 72.. 293 13! 1 . 413 13660. 492 0580. :375 113180. 625 2. 721 3. 030 55. 163 3.394 60.761 13.926 1 I . 426 481 . 797 2718. 168 1273. 878 2400. 000 87.227 1307.302 13574.820 0506. 873 17889. 199 2.85'9 3. 094 65. i 45 9. 315 77. 485 28.99! S. 53t:3 488. 274 2761 . 08~; 1358. 838 2300.000 65.974 1459.220 14201.967 11844.674 18613.484 2.697 2.680 56.050 2.506 66.113 1.483 10.184 475.448 2546.494 1257.219 22.00. 000 70.398 1272. 169 13458.230 1 0503. 475 18334. 340 2. 951 3. 222 66.483 i8.915 80.01 0 61 .603 7.885 479.799 2675.250 1338.015 2100.000 79.753 1292.917 13523.572 10724.875 18723.055 2.873 3.045 72.407 4.403 86.448 17.279 7.547 486.764 2532.188 1298.866 RECORDS NPHI NRAT DPHI DRHO QL QS RHOB ChLI HDRS HMRS HDCN HNCN Page 8 .472 10.586 .282 .067 .012 .0i6 2.185 11.877 15.i30 15.754 66.094 63.475 440 1 Of 111 .270 , 045 025 -. 017 2.205 12.918 970 13.704 71.582 72.969 . 467 1 0 . 687 . 277 . 047 . 027 -. 048 2. i 93 i3. 096 i i . 789 i2.17r~ 84'.:925 82. i28 .491 ! 1 . 059 . 27,5 . 055 -. O00 -. 006 2. i 94 12. 592 15.198 14 . 929 65 . 796 66 . 982 .486 11 . 025 . 287 . 033 . 002 -. 032 2.176 13. 200 13. 068 i2. 034 76. 524 83.1 o o .452 10.333 .313 .060 -.033 .039 2.134 12.719 16.259 i4.785 61.505 67.636 .501 11.232 .263 .070 -. 012 . 032 2.216 13. 183 12. 419 11 .313 80. 524 @~. 394 ,494 11 , 105 ,258 .091 .060 -. Ol 5 2. 224 1 S. 251 12.184 1 I . 03i 82. 077 90. 651 DEPT FSDL HDR DFL NSDL HDX SP FDSN PE HHR TENS DATA NDSN PELC HHX DLOD RECORDS NPHI QL HDRS NRAT QS HHRS DPHI RH08 HDCN DRHO CALI HHCN Pag~ 2000,000 i 2027. 273 60.759 9. 029 1900.000 2489. 074 50,33i 14,338 1800,000 11945. 875 34.219 19,998 1700,000 I 116 O. 074 56,052 9.104 1600,000 1:3654.674 51 .501 Ii.Of5 15.00,000 5979. O74 28.266 26,509 1400.000 15921.074 33.944 13.351 1300.000 15093.8?5 20.188 34.I67 60,691 18809,340 -.300 468.685 41.819 18586.484 ,988 472.091 54. 087 18391 , 484 ,718 4'80,41'8 77,564 19055.91 0 ,004 409.201 02,079 19096,055 1.140 466.63? 47.727 10678.195 -4.271 471.060 62,333 18962.340 -1,582 471.161 59.441 19592.199 -.206 462.057 1277.715 3.ili 70.747 2374..820 1278.947 2.509 54,662 2446.351 1405.850 2. 855 36.908 23'89.126 I 130. 666 3,216 72.437 22 03,146 I 1 47.051 2.210 63.357 2217,453 I 066,408 2,290 35.86.3 2045.779 075.2 03: 2.200 43.781 888,411 1101,392 2.588 26.220 1759,656 14015. 3. 4, i 24.8. 13574. 2. 1. 1340. 14183. 2. , 1357. 12903. 3. --1, 1307, 12.870. 2, --I, 1340. 12566. 2'° 1298, 13172. 2. 1265. 12992. 2, 1. 1240, 020 069 787 890 090 536 040 513 199 900 351 172 479 635 171 195 170 000 754 513 035 553 i24 866 152 235 933 549 402 766 199 561 ,537 -, 125 i4,467 .512 -.012 21 .307 .478 -.001 26,961 ,573 .005 13,859 ,555 ,069 16,847 .524 -. 095 90. 173 .620 .037 23.484 ,408 ,032 45,913 11 . 646 .017 i3.299 1 I. 268 ,047 19,241 10,711 ,008 26,180 12,116 ,021 12.610 11 ,913 .039 15. 006 12.511 .043 49.52;3 13. 007 .04.8 21 .395 12.524 -.011 42. 155 .311 2,136 69,i25 .3,42 2.086 46.933 .327 2.110 37.091 .268 2.208 72.156 .360 2. 056 59.358 .467 1 I1 .090 ,448 1,911 42.582 ,396 1,996 21,7'80 ,070 11.436 75.192 .041 i2.01'8 51.972 .038 11.565 38,197 .106 11.984 79.304 .058 12.706 66,638 -.012 17.433 20.192 .007 13.684 46.741 ,064 23,073 23,722 D'ATA 'RECORDS DEPT GR FDSN NDSN NPHI NRAT DPHI DRHO FBDL HSDL PE PELC QL Q~ RHO8 CALl HDR HDX HHR HMX HDRS HMRS HDCN HHCN DFL SP TENS DLOD 12190.000 15163,674 21 ,953 21 ,217 1100,000 -999.250 5.640 134.367 1000,000 -999,2519 32.002 16.487 900.000 -999,250 12.919 41,644 800.000 -999.250 7,282 132,235 700.000 -999.250 1,459 391.141 600.000 -999.250 13.492 40.327 500.000 -999.250 10.06~ 98.921 58,590 1076,635 12509,312 ,383 12,336 .366 20345.199 2.729 3,232 .076 -.015 2.046 ,075 29,084 1,989 32.567 30.436 30,706 477.450 i83t.187 1291,370 50.536 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999,250 -999.250 -999.250 -999.250 -999.250 -3.535 6,077 -3,864 240.982 172,514 4,150 453,9i4 1845,493 1340,513 61,363 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -,720 39,732 ,023 25,945 23,447 38',544 466,136 1702,432 1265.549 ~ 61,830 -999.250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999.250 -999,250 -999,250 -999,258 -2,125 18,153 -,769 69,912 63.327 14.304 463,465 1645,207 1248,890 24.396 -999.250 -999.250 -999.250 -999.250 -999.250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -2.115 10.182 -2.8i8 20000,000 568.940 .050 451.215 1645,207 1273,878 32.350 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -,976 1,289 -i.922 2366,042 20000,000 ,423 41'2.29e 1516,452 1232,23i 65,912 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,258 -1.412 18.080 -,919 65,136 54,470 15,353 448,467 1430.615 1197.664 55.099 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -6,033 13,588 -2,448 94,385 71,843 10,595 456.900 1387.697 1223,901 .117 24,121 32,856 -999.250 23,316 5.797 -999.250 20.630 42.650 -999,250 23,282 15.791 -999,250 16,244 1,758 -999,250 23.625 .050 -999,250 18.679 18.359 -999.250 20. 058 13.919 10 DA TA RECORDS DEPT GR FDSN NDSN NPHI NRAT DPHI FSDL NSDL PE PELt OL OS RHOB HDR HDX HHR HHX HDRS HHRS HDCN DFL SP TENS DLOD -999 -999 -4 124e .250 ,250 .084 40'0.000 63.585 -999 -999,250 -999,250 -999 35,746 -5,185 57 38,542 439,i63 i359 3.00,000 35. 274 -999,250 -999 -999,250 -999. 250 -999,250 -999 16. 397 -2,306 30,843 -3 30,8i2 391 ,296 I30i ,860 1244 200,000 36 , 802 -999,250 -999 -999 , 250 -999. 250 -999,250 -999 6,613 -7.433 14,577 -2 11 O, 650 .380. 803 1344,778 1315 100,000 -999,250 4,099 ,779 ,25'0 ,250 .725 ,890 -999,250 -999,250 296,247 1473,533 21,730 -999,250 -22,3S5 389.105 DRHO CALl HHCN .250 ,250 ,806 .725 ,250 .250 .328 ,525 -999,250 -999.250 8828,162 1483,778 -999,250 -999.250 25,655 -999.258 -999,250 283,574 -999.250 -999.250 i67.204 -999,250 -999,250 215,857 -999,250 -999,250 15.925 -999.258 -999,250 44.120 -999.250 -999.250 65.320 -999.250 -999.250 3.019 -999,250 -999,250 38,979 -999.250 -999,250 3.526 -999,250 -999.250 5'.981 -999.250 -999,250 4.633 -999,250 14,543 62,793 -999,250 i5,i44 22.666 -999,250 18.421 i5.309 -999,258 15,33i 331.185 11 FILE TRAILER File name: ~GSFO!.O0! Maximum length: I024 TRAILER RECORDS Servic~ n~me) Film type: LO Version #: Next ¢ile: Date: Page 12 FILE HEADER File name: .0{)2 Servicm name: Maximum length: 1024 File type: LO Version #: Previous ~ile: Date: NNEM CN WN FN COUH STAT CTRY AP{N LATI LONG ,SECT .TOWN RANG PD RUN TIME DATE LCC SON LUN FL LUL ENGI WITH DD DL CBDI CaLl TLI BLI TCS TLAB BHT MRT MT MSS DFD MVIS DFPH DFL RN RMF MFST MFSS INFORMATION CONTENTS ARCO ALASKA INC. 2M-23 AP1 NUN: KUPARUK NORTH SLOPE ....... ALASKA ....... USA ....... 20i55.000 ................. O'Deg. 0 Hin, O, 0 Sec 0 Deg, 0 Min, O, 0 Sec lin .......... 0SE .......... 140. 000 ...... 139. 000 ...... 105. 000 ...... lis 1:38o 000 ...... :3/ 4/91 ...... :30 ........... 666'072 . 51936 NORTH SLOP~ NORTH SLOPE McKAY SANBORH/VICKERS :353-"-'. 000 ...... :352-7. 000 ...... 115,000 ....... 114,000 ....... 114,000 ....... :351g. 000 ...... ~038,000 ...... 138. 000 ....... 88. 000 ........ 88. 000 ........ SPUD CIRCULATED 9.400 ........ 5~ .000 ....... g. O00 ........ 1~.000 ....... ~.770 ........ 68. 000 ....... M~S. 4.5~0 ........ ii°III lam°ii m m · ii°aim m m i m m m m m m m m m I m a iimiiI iiimll IIIlll ! I I a im m m I I I I i m I I I m I · I m I m I m ! I i ii a I I a i · i I I I DATE LOGGED: mmm ! · ° o o I o 50-1 03-20155 ....... i m mm i m mm $I mm me mm lmm mmm a mmm m ama i ama a mae mm ! mm III mm 04-03-91 m m · m m · m ° m m a m m ~ m I m m m m m m m m m · · ° RECORDS UNIT TYPE CATG 0 0 0 0 0 0 0 0 0 0 0 0 O 0 0 0 0 0 0 0 :0 0 0 0 FT 0 FT 0 FT 0 ' 0 3 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 FT 0 3 FT 0 FT 0 FT 0 FT 0 3 FT 0 3 HR 0 2 HR 0 4 DEGF 0 1 DEGF 0 1 0 0 LB/G 0 2 CP 0 2 0 2 0 2 OHI'IM 0 2 OHMM 0 2 DEGF 0 2 0 OHlil'l 0 2 SIZE 40 40 40 20 20 20 4 34 34 2 3 3 4 4 4 2 2 2 2 4 8 2 10 10 20 20 20 20 4 4 4 4 4 4 4 4 4 4 20 2O 4 4 4 4 4 4 ,4 12 4 CODE 65 65 65 65 68 65 65 68 68 68 65 65 76 68 65 7~ 68 68 68 68 68 68 68 68 68 68 65 68 Pag~ ERROR 13 I~FORM~TIO~ RECORDS Page i4 MNEH MCST MCSS CS CONTENTS 69,00'0 .................................................. ME~S ............................................. 16,000 ..... ............................................. ~2,250 .................................................. UNIT DEGF TYPE CATG SIZE 4 4 4 CODE 68 68 ERROR COMMENT RECORDS Well Location Comment I: SURFACE: 114' FSL & 529~ FWL Well Location Comment 2: Well Location Comment 3: Well Location Comment 4: W~ll File Comment t: HRI-SDL/DSN RUN IN COMBINATION, CHLORIDES = 350 PPN. Well File Comment 2: SHIFTED SP BETWEEN REEPAT & MAIN PASSES. Well File Comment 3: TENSION CURVES 46.25 FEET TO TOOL ZERO. W~ll File Comment 4: DSN RUN WITH BOWSPRING DECENTRALIZER, · ~ LIS tape written b~: ANCHORAGE COMPUTING CENTER · ~ All curve and tool mnemonics used are those which most closely, match · ~ Halliburton curve and tool mnemonics. HALLIBURTON TO SCHLUMBERGER TOP BOTTOM MNEM SERVICE UNIT MNEM SERVICE UNIT DEPTH DEPTH DEPTH FT DEPT FT GR! SDL GAPI GR SDL GAPI FDSN! DSN2 CPS FDSN DSN2 CPS NDSN1 DSN2 CPS NDSH DSH2 CPS NPHI1 DSN2 DECP NPHI DSN2 DECP NRAT1 DSH2 C?C NRAT DSN2 C/C DPHI! SDL DECP DPHI SDL DECP DRHO! SDL G/C3 DRHO SDL G/C3 FSDLI SDL CPS FSDL SDL CPS NSDL1 SDL CPS NSDL SDL CPS 80.00 1393.50 1393 50 1393 50 1393 50 1393 50 1393 50 356'0 O0 3550 O0 3550 O0 3550 O0 3550 O0 3550 O0 3550 O0 3550 O0 3550 O0 3550 O0 Pag~ 15 PE1 PELCl QL1 RHOB1 CAl_.Ii HDR1 HDX1 HHR1 HNX1 HDRS1 H~RSl HDCNI HMCN1 DFLi SP1 TENS1 DLOD1 8DL SDL ~DL SDL SDL SDL. HRI HR! HRI HRI HRI HRI HRI HRI HRI SDL G?C3 IN OHHN OHMH MMHO. HMHO OHHM LB LB PE PELC QL QS RHOB CAL. I HDR HDX HMR HMX HDRS HHRS HDCN HMCN DFL SP TENS DLOD SDL SDL SDL SDL 'SDL SDL HRI HRI HR! HRI HRI HRI HRI HRI HRI HRI SDL SDL G?C3 IN OHHM OHHH HMHO HHHO OHHH LB LB 1393.50 1393.50 1393.50 1393,50 1393.50 1393,50 1393,50 1393.50 1393.50 1393.50 1393 50 1393 50 1393 50 1393 50 1393 5O 3550.00 3550,00 3550,00 3550.00 3550.00 3550,00 3550.00 3550.00 3550.00 3550.00 3550.00 3550 O0 3550 O0 3550 '00 3550 ,00 3550 O0 3550 O0 3550.00 DATA FORMA ENTRY BLOCKS ENTRY TYPE T SPEC I F I CA T IONS ENTRY BLOCK LEC, END ~ TYPE DESCRIPTION 16 Datum zp¢ciPication block zub-tpp~ 0 Terminator ( no more ~ntriaz ) SIZE CODE Page 16 DATA FORMA DATUM SPECIFICATION BLOCKS ~.~.~******~******~***************~, T SPECIFICATIONS Pag~ 17 SERVICE SERVICE API API APl APl FILE MNEM ID ORDER # UNIT LOG TYPE CLASS ~OD PRC # SIZE LYL SMPL RC PROCESS INDICATORS DEPT 666072 GR SDL 666072 FDSN DSN2 666072 NDSN DSN2 666072 NPNI DSH2 666072 NEAT DSN2 666 072 DPHi SDL 666072 DRHO SDL 666072 FSDL SDL 666072 NSDL SDL 66607;2 PE SDL 666072. PELC SDL 666072 QL SDL 666072 RHOB SDL 666072 CALI SDL ~66072 HDR HRI 666,072 HDX HRI 666072 HMR HRI 666072 HH× HRI ,666072 HDRS HRI 666072 HMRS HRI 6660?2 HDCH HRI 666072 HMCN HRI ' 666 072 DFL HRI i 666 072 SP HRI ' 666072 TENS SDL 666072 DLOD SDL 666072 FT 0 0 0 0 2 GAPI 94 0 0 3 CPS 94 0 0 3 i CPS 94 0 0 3 1 DECP 94 0 0 3 C/C 94 0 0 3 DECP 94 O 0 3 G/C3 94 0 0 3 1 CPS 94 0 0 3 1 CPS 94 0 O 3 1 94 0 0 3 1 94 0 0 3 1 94 O O 3 t 94 0 0 3 i G?C3 94 0 0 3 1 IN 94 0 0 3 1 94 0 0 3 i 94 .O 0 3 i 94 0 0 3 i 94 0 0 3 1 OHHM 94 0 0 3 OHHH 94 0 0 3 1 HHHO 94 0 0 3 1 MHHO 94 0 0 3 1 OHHH 94 0 0 3 NV 94 O 0 3 i LB 94 0 0 3 1 LB 94 0 0 3 I 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 i 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 i 68 4 0 1 68 4 0 1 68 4 0 i 68 4 0 1 68 4 0 1 68 4 0 1 6B 4 0 I 68 4 0 I 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 I 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 000000 000000 000000 O0000O 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 DEPT FSDL HDR DFL 3550,000 1372,674 161 ,805 2345.00 0 GR t,i~BDL HDX SP 98.253 18350.055 29.516 -999,250 DATA FDSN NDSN PE PELC HMR HHX TENS DLOD 1381.760 13569.414 2,552 2.491 183.714 22.314 2675.250 990.679 3500.000 98.253 1381.760 13569.414 11523,674 17973.055 2.162 2.592 169.569 19.560 194,417 5,509 3.237 558,509 2575,106 935.7.04 3400,000 83,633 14t3,265 13954,518 1 0669,273 18068. 770 2,582 2.7t 9 ! 17,357 15. 136 131 , 972 10. 277 5,428 550. 435 2718. 168 1057.3i 3 3300,000 9'0.67'5 1494.490 14189.701 -I 0885,074 181 05,77 0 2,624 2. 669 80.49! 7,98! 87,354 16 . 389 7,930 542,056 3004.291 1245.975 3200,000 66,428 1406.880 13807,447 1 I 002. 475 1805! . 91 0 2. 541 2. 642 74. 453 I I . 403 74. 364 I ! . 013 8,403 541 , 559 2532,188 978. t 85 3100.000 85.360 1337.729 13514.377 1 0577. 674 17765. 855 2. 776 2. 993 1 04. 092 7. 562 139. 083 5. 057 4,223 546,901 276! . 086 1172,676 3000. 000 83. 363 1339. 992 13556,564 1 0959. 674 18062.484 2,591 2,771 1 00,847 9,840 126,892 6,063 4,775 542,566 2532,188 1 073,973 2900.000 91.459 1201,961 13037.934 12110.674 18449,625 2.746 2,845 145.605 26.332 184.547 34.053 3.046 537.828 2446,351 1007.337 RECORDS NPHI QL HDRS .459 .082 -12345.000 NRAT HHES 10.426 .094 -12345.000 DPHI RHOB HDCN .304 2.148 -12345.000 DRHO CALl HHCN ,049 12,250 -12345.088 .459 ,333 4,759 10.426 .OOO 4.676 .329 2.107 210,148 .015 12.250 213,836 .461 .020 7.887 10.483 -.005 7,492 ,285 2.181 126,790 . O44 12.546 133.480 .433 .005 10.895 10.081 -.014 10.774 .291 2,171 91 .788 ,043 13,113 92,81~. .456 -,039 13,498 10,420 .000 12.960 .303 2.151 74.084 ,034 12.663 77,159 .476 · 032 7.377 10. 726 ,004 6.550 .296 2.161 135.551 · 021 12.483 152,674 ,475 .033 7.263 10.741 .009 6.529 .300 2.155 137,685 .034 12.633 153.171 ,524 ,OOO 5.267 11.516 -.012 4.796 .332 2.102 189,848 ,040 12.337 208.524 Pag~ 18 DEPT FSDL DFL GR NSDL HDX SP FDSN PE HHR TENS DATA NDSN PELC HHX DLOD RECORDS HPHI QI. HDRS NRAT -- -- HHRS DPHI RHOB HDCN DRHO CALl HHCN Pag~ 19 2800,000 0755,273 64. OG6 12,315 2700. O0 0 0394,475 75.163. 11,41t 2600, O0 0 I 0415. 873 73,528 1 0,327 2500,000 10354,674 55,446 11,836 2400.000 10500.$73 65.370 8,721 2300,000 i 1 432,074 55. 985 I 0.387 2200, O0 0 0492,475 66,983 8,039 2100.000 093. 074 73,04 i 7,742 68,172 18272,625 10,284 529,863 76,152 17996,055 1,269 533.323 70.018 17882.770 16,456 531,615 74,864 17982.055 8,049 512.470 86,544 17859,484 10.451 514,033 6.0,020 18225.055 2,735 488,476 77.474 18132.340 18.306 517.479 75.885 18925.055 6.195 508.060 1387,.319 2,814 61,799 2246.065 1490,363 2,867 76,041 2317,596 1407. 086 2. 869 72,690 2246. 065 1345.340 2.754 61,292 2489.270 1347,602 2,884 77,655 2789,699 1465,4,06 2.609 65,4?4 2446,35i 1266,624 2,971 80.055 2546.494 1252.867 2.974 87,008 2546,494 13898,932 2,989 20,094 951,947 14119,996 2,844 13,870 995.676 14000.145 2.981 39,717 973,604 13471 .643 3. 055 19.741 1191 . 000 13456.336 3,181 33,062 1431 ,304 14435.723 2.767 2.202 1248.474 13361,244 3.180 61,429 1316.357 13281,574 3.148 23.634 I357.589 ,470 .032 15. 127 .436 .003 14.568 ,460 -.037 11.819 ,468 .001 15.060 ,466 ,003 12,965 .459 -,039 16,258 ,502 .044 12.385 ,506 .011 11 , 868 1 0. 637 .008 15.951 1 0 059 -.012 14.293 1 0. 564 -. 005 12,224 10,631 .02~3 14,680 10.602 ,011 1 i. 964 1 0,459 -,015 14,953 11 .200 -,010 11,328 11 , 255 .031 10,901 .281 2.186 66, I 09 ,273 2,200 68,644 .28o 2.i87 84',613 ,274 2,198 66.403 ,288 2,174 77. 131 .314 2,132 61 ,509 .272 2.202 80.745 .265 2,213 84,257 ,058 12,08i 62.692 ,046 12,877 69,964 ,036 13,023 81,805 ,047 12,677 68.121 ,031 13.120 83.581 .038 12.697 66,878 · 053 i3,169 88,279 ,099 13,113 91 .736 DATA RECORDS DEPT GR FDSN NDSN NPHI NRAT DPHI DRHO FSDL NSDL PE PELC QL QS RHOB CALi HDR HDX HHR HHX HDRS HHRS HDCH HHCN DFL SP TENS DLOD 2000,000 59. 325 ! 395 115~5. 475 1820i . 055 2 61 , 059 -,38! ?0 9, i i 2 499. 477 233t 1900,000 41.558 1370 12257,475 i8355,055 2 50,769 1,702 55 14.702 501,283 2389 1800.000 52,574 1352 11649,475 18390.910 3 34.375 ,627 36 20,172 494,234 2274 1700.000 81,053 1130 11005,475 18634,199 3 56,098 ,657 72 9,318 500.690 2188 1600,000 13577.875 52,499 10.991 1500.000 16091,676 2S.I14 28,575 81,089 1 9021,625 1 ,143 501,775 42,630 18319,340 -4,356 479,409 1103 2 63 2360 1 020 2 34 2031 ,760 143i6."199 ,492 10.890 ,322 ,031 .846 2.907 ,003 -,016 2,i19 11,650 ,854 5,169 14,445 13,337 69:229 74,978 ,902 1291,786 Page 20 ,440 13859,559 .482 i0,737 ,344 .028 ,498 2.59i -,031 ,047 2,083 i2,08i ,005 1.893 21,662 19,671 46,165 50.837 .i26 1364.668 ,128 13980.857 ,495 i0,978 ,314 ,045 ,142 2.881 ,013 ,025 2,132 11,614 . 746 -,842 26. 766 25,841 37; 360 38.697 ,677 1338.848 , 052 12835,297 , 564 12, .059 . 280 , 080 .045 3,639 -, 045 -, 005 2.188 12,149 , 744 - , 842 14,001 i 2. 645 71 , 422 79 . 083 .$40 I307,612 . 029 12002,463 . 576 12. 323 , 360 , 054 , 235 2. 039 , 029 - . 002 2. 055 12 , 706 , 371 -1 , 980 16,501 14,993 60 , 602 66,696 , 514 1490. 858 ,026 12505,590 ,552 13.006 .477 -.026 ,220 2.560 ,039 ,017 1.862 17,494 ,367 -5.200 94,602 56.584 10,562 17,673 ,473 1312.193 1400.000 61,561 1177,992 13320,086 ,552 12,005 ,444 -.012 '15274.074 18438,199 2,086 2,150 ,024 -,029 1.918 13.675 33,970 -1,967 43,544 -4,092 24,029 22,032 41.617 45.388 13.949 486,456 1059.799 1265.549 FILE TRAILER File name: ~GSF01.'002 ~erv~c~ n&me~ TRAILER RECORDS Maximum length; i024 File type: LO Version #: H~xt file: Date: Page 2.1 FILE HEADER File name: .003 Service name: Version #: Date: Maximum length: 1024 File type: LO Previous file: MNEM CN WN FN COUN ST~T OTRY APIN LATI LONG SECT TOWN RANG £K8 EDF E.GL PD RUN TIME DATE LCC SON LUN FL LUL ENGI WITN DD DL CBDt CBLt TLI BLI TCS TLAB BHT MRT MT MSS DFD MVIS DFPH DFL RM RMF MFST MFSS AMC I NFORMAT I ON CONTENTS ARCO ALASKA 2M-23 KUPARUK NORTH SLOPE ALASKA USA 20155 0Deg 0 Deg 11N ......... 0SE., ...... 139. '000 ...... 105. OOO ...... KB ........... 111111111111 138.000 ...... 3/ 4/91 ...... 30 ........... 666072 ... 51939 NORTH SLOP~'' NORTH SLOPE SANBORH/VICKERS 3532.000 ..... 3527.000 ..... 115.000 ...... 114.000 ...... 114.000 ...... 3519.000 ..... 2038.000 ..... i38.000 ...... 88.000 ....... 88.000 ....... SPUD CIRCULATED 9.400 ........ 5l.OOO ....... 9.000 ........ 12.000 ....... 6.770 ........ 8,170 ........ 68.000 ....... MEAS. , 4.560 ........ 000 .................. O Min, O, 0 Sec 0 Min, O, 0 Sec · ., Il. INC. ... APl tlUM: 50-103-20155... 04-03-91 .. DATE LOGGED: 4. , ii W i , , · RECORDS UNIT TYPE CRTG SIZE CODE .0 0 40 65 0 0 40 65 0 0 40 65 0 0 .20 65 O 0 20 65 0 0 20 ~5 0 0 4 68 0 0 34 65 0 0 34 65 0 0 2 65 0 0 3 65 0 0 3 65 FT 0 3 4 68 FT 0 3 4 68 FT O' 3 4 68 0 3 2 65 0 3 2 65 0 3 2 65 0 0 2 79 O 0 4 68 0 0 8 65 0 0 2 79 0 0 10 65 0 0 10 65 0 0 20 65 0 0 20 65 0 0 20 65 0 0 20 65 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 FT O 3 4 68 FT O 3 4 68 FT 0 3 4 68 HR 0 2 4 68 HR 0 4 4 68 DEGF 0 I 4 68 DEGF O 1 4 68 0 2 20 65 0 2 20 65 LB/G 0 2 4 68 CP O 2 4 68 0 2 4 68 0 2 4 68 OHHM 0 2 4 68 OHMH 0 2 4 G8 DEGF 0 2 4 68 0 2 12 65 OHMM 0 2 4 68 Page ERROR 22 MNEM MCST CS I NFORMAT I ON RECORDS CONTEHTS ' IlEA ............................................ 16 000 12,250 .................................................. UNIT DEGF TYPE CATG SIZE 4 i2 4 4 CODE 65 68 68 Page ERROR 23 COMMENT RECORDS Well Well Well Well Well Well File Comment Well File Comment Location Comment 1: SURFACE: Location Comment 2: Location Comment 3: Location Comment 4: File Comment 1: HRI-SDL/DSN RUN 114' FSL & 529' FWL IN COMBINATION. CHLORIDES = 350 PPM, SHIFTED SP BETWEEN REEPAT & MAIN PASSES. TENSION CURVES 46.25 FEET TO TOOL ZERO, Well File Comment 4: DSN RUN WITH BOWSPRING DECENTRALIZER. ** LIS tape written by: ANCHORAGE COMPUTING CENTER ~m All curve and tool. mnemonics used are those which most closely match *$ Halliburton curve and tool mnemonics. HALLIBURTOH TO SCHLUMBERGER TOP BOTTOM MNEM SERVICE UNIT MNEM SERVICE UNIT DEPTH FT DEPT FT GA2 SDL GAPI GR SDL GAPI FDSN2 DSN2 CPS FDSN DSN2 CPS NDSN2 DSN2 CPS NDSN DSN2 CPS NPHI2 DSN2 DECP NPHI DSN2 DECP HRAT2 DSN2 C?C NRAT DSN2 C?C DPHI2 SDL DECP DPHI SDL DECP DRH02 SDL G?C3 DRHO SDL G?C3 FSDL2 SDL CPS FSDL SDL CPS NSDL2 SDL CPS NSDL SDL CPS DEPTH DEPTH 80 O0 1393 50 1393 50 1393 50 1393 50 1393 50 1393 50 1393 50 1393 50 1393 50 3560 O0 3550 O0 3550 O0 3550 O0 3550 O0 3550 O0 3550.00 3550.00 3550,00 3550,00 Pagm 24 PE2 PELC2 QL2 Q$2 RHOB2 CALI2 TENS2 DLOD2 SDL SDL SDL SDL SOL SDL SDL SDL G?C3 IH LB LB PE PELC QL RHOB CALI TENS DLOD SDL SDL SDL SDL SDL SDL SDL SDL G/C3 IN LB LB 1393,50 1393,50 1393.50 1393,50 1393,50 1393.50 1393.50 3550.~00 3550.00 3550,00 3550.00 3550.O0 3550.00 3550,~00 DATA FORMAT SPEC I F I CAT IONS ENTRY BLOCKS ENTRY TYPE 16 0 ***************************** ~** ENTRY BLOCK LEGEND TYPE DESCRIPTION 16 Datum spaci~ication block zub-t~pe 0 T~rminator ( no mor~ mntriaz ) SIZE CODE Page 25 DATA FORMAT SPEC I F I CAT IONS ~mm DATUH'SPECIFICATION BLOCKS **** Page 26 MNEM SERVICE SERVICE APl AP1 AP1 APl FILE ID ORDER # UNIT LOQ TYPE CLASS HOD PRC # SIZE LVL SHPL RC PROCESS INDICATORS DEPT 666072 FT 0 0 GR SDL 666072 GAPI 94 0 · FDSN DSN2 666 072 CPS 94 0 NDSN DSH2 666072 CPS 94 0 NPHi DSH2 666 072 DECP 94 0 NRAT DSH2 666 072 C/C 94 0 DPHI SQL. 666072 DECP 94 0 DRHO SDL 666072 G/C3 94 0 FSDL SDL 6660?2 CPS 94 0 NSDL SDL 666.072 CPS 94 0 PE SDL 666072 94 0 PELC SDL 6660?2 94 0 QL SDL 666072 94 0 QS SDL 666072 94 0 RHO8 SDL GGG:O?2 G/CJ 94 0 CALl SOL 6660?2 IN 94 0 TEHS SDL 666 072 LB 94 0 DLOD SDL 666072 LB 94 0 0 0 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 3 4 0 1 68 2 4 0 1 68 2 4 0 .i 68 2. 4 0 I 68 2 4 0 1 68 2 4 0 1 68 2 4 0 ! 68 2 4 0 1 68 2 4 0 i 68 2 4 0 1 68 2 4 O i 68 2 4 0 1 68 2 4 0 1 68 2 4 0 i 68 2 4 0 1 68 2 4 0 I 68 2 4 u I 68 2 4 0 i 68 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 DEPT FSDL TEHS ~R NSDL DLOD FDSN PE DAT NDSN PELC RECORDS NPHI QL NRAT QS DPHI DRHO CALI Page 27 3550, ii372, 2~75. ~500. 11523. 2575. 3400. 1 0600, 2718. 3300. 10792. 3004. 3200, 11029, 2532. 3100, I 06,93, 2761, 3000. 10779. 2532. 2900, 12089, 2446, 2800. 10535. 2246. 000 674 250 000 674 000 674 168 000 674 291 000 674 188 o00 674 086 000 674 188 000 674 351 000 674 065 98.253 1835'0,055 990.679 98,253 17973,055 935,704 83,633 18290.055 1057.313 90.675 18076,055 1245,975 66,428 17945,387 978,185 85.360 17696,387 1172,676 83.363 18095,055 1073.973 91.459 18488,055 1007,337 68.1 72 18215.723 951 .947 1381.760 2.552 1381.760 2.162 1437.371 2,681 1539.490 2,576 1443.554 2,543 1346,779 2.751 1361.180 2.576 1191,728 2.768 1370,440 2,833 13569.414 2,491 13569,414 2.592 13829,020 2,787 14256.094 2.622 13748.764 2,638 13499.525 2.986 13562.580 2.861 055,027 2,902 13840.91 0 3,207 .459 ,082 .459 ,333 .452 .011 ,424 -,103 .440 028 .469 057 .468 ,104 ,532 -, 065 ,473 -. 038 10.426 ,094 10.426 ,.000 10.215 ,012 9.832 -. 04,3 10.112 -.013 10,642 ,002 1 0. 579 -. 003 11,631 -.024 10,723 ,014 ,304 2,148 ,329 2.107 .273 2. 199 ,289 172 ,308 2,142 .302 2,152 ,293 2.166 ,328 2,109 ,275 2,197 ,049 12.250 .015 i2.250 .059 12.546 ,040 13,113 .028 i2.663 .016 12.48:3 ,039 12,633 .044 12.337 · 060 i2.081 DEPT FSDL TENS ~R NSDL DLOD FDSN PE DATA NDSN PELC RECORDS NPHI QL NRAT QS DPHI RHOB DRHO OALI Pag~ 2,9 2700. 000 i 0206. 674 2317.59/, 2600.000 10496.674 2246.065 2500.000 I0326.674 2489.270 2400. 000 i .0538. 674 2789.699 ~300.000 11366.674 2446.351 2200.000 10498.674 2546.494 2100.000 10892.674 2546.494 2000.000 11557.674 2331.902 1900.000 12269.674 2389.126 76.152 18083.387 995.676 70. O18 'i7857. 723 973.604 74,864 18025,055 1191,000 86.544 17867.055 1431.304 6.0. 020 18 066,055 1248,474 77.474 18093.387 1316.357 75.885 19129.387 1357.589 59.325 18093.723 1291.786 41.558 18262.387 1364.668 1512.649 2.915 1382.790 2.822 1387.936 2.790 1338.552 2.839 1433.249 2.601 1255,3;31 2.998 1250.199 3. 063 1400.290 2.772 1342,666 2.490 14181 .307 3.013 3931 . i O0 2,921 13501. 889 3.1 O0 13393.029 3.277 14554.412 2.674 13376,262 3,126 13284.654 3.23i 14273,141 2.867 13819,510 2,488 .428 ,045 ,469 -. 070 .457 .060 ,466 -,016 .471 -.018 .514 .079 ,512 -. 045 .486 -,018 .492 -,144 9.954 -,018 10,696 -,.028 10.328 .054 1 O. 623 .020 10.781 -. 039 11,313 .'009 11,282 -.007 1 0. 822 -. 030 1 0,928 -.010 .262 2.2i7 ,284 2.i81 .271 2.203 .29t 2; i70 .319 2. 123 ,274 2.198 .250 2.238 ,325 2,113 .343 2. 084 ,054 12,877 .033 1.3,023 .050 12.677 .029 13.120 ,030 12,697 .050 13, 169 .116 13,113 .026 il ,650 .024 12,08i DEPT GR FSDL NSDL TENS DLOD i8:00. 000 52. i 1604. 674 18:503. 2274.677' t338. i?O0.O00 81. 1 08:87. 674 18:734, 218:8.8:40 1307. 1600. 000 8:! . 137'01 .674 19165. 2360.514 J490. i500.000 42. i68i9.676 18:097. 2031.473 1312. 1400,000 15278.6?4 18278. DATA FDSN NDSH PE PELC RECORDS HPHI NRAT DPHI DRHO QL QS RHOB CALl Pag~ 29 574 t 3i O. 796 i 4015. 609 723 3. i64 2. 904 8:48: .515 ii.352 .3il .052 · 006 .Oil 2.i37 ii.6i4 053 1147.665 12755.668 055 2.976 3.62i 612 · 553 !1,800 .272 ,08:5 -, 090 -,.02';9 2,202 1 2, i 49 089 1 047. 394 12?,58. 875 387 2. 238: 2. 042 85.9 , 605 ! 2,943 , 361 , 060 ,080 -, 036 2,055 12,706 630 I 009,590 1 2463,148 38:7 2,044 2,443 193 · 553 1 3,1 06 , 497 - , 038 ,08:0 ,070 1 ;8:3'0 17,494 561 1141.§20 13514.758 387 2.029 2.075 549 ,58i i2,570 ,447 -,017 .064 ,036 i,9i2 13,675 ~** FILE TRAILER File name.: &GSF01.003 Service name: TRAILER RECORDS Maximum length: !024 File type: LO Verzion #: Hext f i 1 e: Date: Page 30 REEL TRAILER ************************ Service name: &G5F01 Next reel: Date: 91/04/22 Comments: Origin Reel name: 666072 Continuation #: 01 TAPE TRAILER Sepvice name: &GSFO! Next tape Date: 91/04/22 Comment~: Origin: Tape name: 666072 Continuation #: O1
