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Home My WebLink About187-123Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production Scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. / -~Y- ,Z ~-~ Well History File Identifier Organization (do.e) ~~Two-Sided RESCAN [] Color items: [],,~rayscale items: Poor Quality Originals: [] Other: DIGITAL DATA [] Diskettes, No. [] Other, No/Type TOTAL PAGES' NOTES: ORGANIZED BY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Project Proofing · ' PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) n Logs of various kinds [] Other /si [] Staff Proof By: Date: /si PAGES: /S,~at the time of scanning) SCANNED BY: BEVERLY BREN VlNCEN ST~HERY~L.~VIARIA LOWELL ReScanned (done) RESCANNED BY~~ BREN VINCENT SHERYL MARIA LOWELL /s/ General Notes or Comments about this file: PAGES:" Quality Checked (done) RevlNOTScanned.wpd __ Cpe.-'atcr sCa=us an~ ! ' c! - p: '' loc. .ear. ' Plugs .Harkar 'post: c= plata: Loca=icn Clearance: Conclusions: ~ i STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CON,,¢~ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil D Gas D Suspended D Abandoned [~] Service [~] 2. Name of Operator 7. Permit Number Phillips Alaska, Inc. 187-123 13. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 _. 50-103-20092 1155' FNL, 4997' FEL, Sec. 12, T12N, R8E, UM (asp's 498655, 6000500) Kuparuk Unit At Top Producing Interval 10. Well Number 3593' FNL, 1777' FEL, SEC. 1, T12N, R8E, UM (asp's 501875, 6003344) 3H-14 At Total Depth 11. Field and Pool 3338' FNL, 1560' FEL, Sec. 1, T12N, R8E, UM (asp's 502091, 6003597) Kuparuk Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB 76 feetI ADL 25531 / ALK 2657 Kuparuk Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions December 7, 1987 December 12, 1987 October 30, 2000 (P&A'd)I N/A feet USE 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 8250' MD / 6374' TVD 7685' MD / 5970' TVD ,YES ~] No DI 1797' feet MD 1900' (approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, CAL, GR, GCT, CET 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD I CASING SIZE WT. PER FT. GRADE TOP BO'FI'OM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 62.5# H-40 Surface 115' 24" 200 Sx AS I 9-5/8" 36.0# J-55 Surface 3455' 12-1/4" 1350 sx AS III & 400 Sx Class G 7" 26.0# J-55 Surface 8220' 8-1/2" 800 Sx Class G & 175 Sx AS I 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 7841' 7674' 2-7/8" 7859' 7832' * Plugged & Abandoned all open perforation intervals. 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED (See P&A Summary) 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) N/A Plugged & Abandoned Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I N/A Test Period > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) Press. 24-Hour Rate > 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. * This 10-407 is submitted as directed per the 10-403 form approved February 28, 2000 (Approval #300-046) RECEIVED FEB 0 ? 2001 Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE ORIGINAL Alaska Oil & Gas Cons. Commiss&Q~mit in duplicate Anchorage 29. -' GEOLOGIC MARKEH~. NAME Top of Kuparuk D Top of Kuparuk C Top of Kuparuk B Top of Kuparuk A MEAS. DEPTH 7756' 7766.5' 7789' 7863' TRUE VERT. DEPTH 6018' 6025' 6040' 6090' 31. LIST OF ATTACHMENTS Summary of 3H-14 Pre Coil Tubing Sidetrack Plug & Abandonment Operations. 30. f~ \ FORMATION TESTS Include Interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. N/A 32. I hereby certify that the following is tree and correct to the best of my knowledge. Dan Venhaus Title PAl Coiled Tub n,q Drilling En.qineer Date February 7, 2001 Prepared by Paul Rauf 564-5799. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21- Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28; If'no cores taken, indicate "none". RE CE IVE D Form 10-407 ORIGINAL FEB 0 ? ZOO1 Alaska Oil & Gas Cons. Commission Anchorage ~ ' 3H-14 ' DESCRIPTION OF WORK COMPLETED PRE COILED TUBING SIDETRACK PLUG & ABANDOMENT SUMMARY Date Event Summary 10/22/2000: 10/23/2000: 10/25/2000: 10/27/2000: 10/28/2000: 10/30/2000: 11/05/2000: 11/06/2000: 11/07/2000: RIH & dummied GLV's. Pulled GLV's f/2882', 5311', & 6753' MD. Set dummy valves @ 2882' & 5311 '. FP'd well. RIH & set dummy GLV's @ 6753' & 7710'. Pulled OV f/7629'. Displaced 7" casing w/Diesel. Set dummy valve @ 7629'. Tested casing to 3000 psi - held f/15 min RIH w/tubing puncher & tagged collapsed tubing @ 7742'. Punched circulated holes in the 3- 1/2" tubing f/7725' - 7729' & 7684' - 7688'. Logged SBHP @ 7727'. Performed injectivity test. MIRU CTU. PT'd equip to 4000 psi. RIH w/CT & tagged collapsed tubing. Pumped in 18 ppg mud & waited 5 hrs f/it to seep past the collapsed tubing & into the lower wellbore. The goal here was to displace any water in the lower wellbore w/mud so to mitigate future cement contamination during the P&A. Circulated hole clean & POOH. FP'd well. RD CTU unit. RIH w/LIB to collapsed tubing. A CTU Cement Plug was pumped to Plug & Abandon the lower wellbore prior to ST operations as follows: MIRU CTU & PT'd equipment. RIH w/CT & tagged 7742'. Fluid packed well w/130° F Seawater. Pumped 28 bbls of 15.8 ppg Class G Cement to abandon the perforation intervals located @: 7758'-7763' MD 7768'-7798' MD 7882'-7902' MD 7917'-7929' MD 7954'-7974' MD Layed in cement 1:1. Placed 5.2 bbls of cement behind pipe @ a squeeze press of 1250 psi. Contaminated cement w/Biozan & jetted contaminated Cement f/the wellbore to 7650' MD. POOH w/CT. Trapped 2300 psi WHP on well. RD CTU. WOC. RIH w/bi-centered bit & tagged TOC @ 7629' CTM. Milled cement to 7705' CTM. Circulated Biozan Sweep off BTM. RIH & tagged cement plug @ 7670' SLM. PT'd tubing to 1500 psi - held good. RIH & tagged PBTD @ 7730' ELM. Logged SCMT & POOH. Results indicated good cement in the IA f/7686' to 7692'. RIH & set Whipstock @ 7685' (top). Tagged Whipstock. Continued w/3H-14A Sidetracking Operations. \\ & GaS Co~S. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_X Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _X Time extension _ Stimulate _ Change approved program _ Pull tubing, Variance _ Perforate _ Other_ 2. Name of Operator ARGO Alaska, Inc. 3. Address P; O. Box, 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1155' FNL, 4997' FEL, Sec. 12, T12N, R8E, UM At top of productive interval 3593' FNL, 1777' FEL, SEC. 1, T12N, R8E, UM At effective depth At total depth 3338' FNL, 1560' FEL, Sec. 1, T12N, R8E, UM 5. Type of Well: Development ._X Exploratory _ Stratigraphic _ Service _ (asp's 498655, 6000500) (asp's 501875, 6003344) (asp's 502091, 6003597) 6. Datum elevation (DF or KB feet) RKB 76 feet 7. Unit or Property name Kuparuk Unit 8. Well number 3H-14 gl P~rmit number / approval number 187.123~'' 10. APl number 50-103-20092 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length CONDUCTOR 1 15' SUR. CASING 3379' PROD. CASING 8144' Size 16" 9-5/8" 7" 8250 6374 7752 6015 feet Plugs (measured) feet feet Junk (measured) feet Cemented 200 sx AS I 1350 Sx AS III & 400 Sx Class G 800 Sx Class G & 175 SxAS I Collapsed Tubing Tag @ 7752' MD on 7/14/1999. ORIGINAL Measured Depth TrueverticalDepth 115' 115' 3455' 3001' 8220' 6351' perforation depth: measured true vertical rubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 7758' - 7763'; 7768' - 7798'; 7882' - 7902'; 7917' - 7929'; 7954' - 7974'. 6018' - 6022'; 6025' - 6046'; 6103' - 6117'; 6128' - 6136'; 6154' - 6168'. 3-1/2", 9.3#, J-55 Tbg @ 7841' MD; 2-7/8", 6.5#, J-55 Tbg @ 7859' MD. BAKER FHL Packer @ 7674' MD; OTIS WD Packer @ 7832' MD. CAMCO TRDP-1A-ENC SSSV @ 1797' MD~ RECEIVED 25 2000 0il & asC s. n 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch __X 15. Status of well classification as: 14. Estimated date for commencing operation February 29, 2000 16. If p[oposal was verbally approved Name of approver Date approved Oil __X Service Gas _ Suspended __ 17. I hereby certihj that the loregoing is true and correct to the best of my knowledge. · Signed Br~..~~,~. ~), ~'~.~-~ }Title: AAI Coil TubingDrillingSupervisor ' '~/F¢O~ COMMISSION USE ONLY Conditions of approval: NOtify Commission so representative may witness Questions? Call Dan Kara @ 263-4837. Pre?arad by Paul Rauf £65-49~O IApproval no. Plug integrity BOP Test _~ Mechanical Integrily Test _ Location clearance_ Subsequent form required 10- ~_ ~_ Approved by order of the Commission Form 10-403 Rev 06/15/88 · ORIGINAL SIGNED BY . SUBMIT IN TRIPLICATE MICROFILMED 10/12/00 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE Objective: KRU 3H-14 Intended P&A Procedure P&A existing interval and mill window in preparation for CT sidetracking operations. Intended Procedure ' .RU slickline unit, drift tubing to 2.80" to collapsed pipe at 7752'. Pull valve from production mandrel at 7710', leaving pocket open for straddle communication. RU E-line unit. Install bridge plug in 3-1/2" tubing just above collapse at 7752'. Shoot circulation hole in 3-1/2" straddle interval at 7680'-7700' md for P&A cementing. Run in hole with mechanical whipstock on E-line. Set whipstock for a KOP at 7690' md.' RU CTU. Load and kill well. RIH with coil, bullhead 10 bbls Class 'G', 15.8 ppg cement into 3-1/2" x 7" straddle annulus. Squeeze up to 5 bbls cement into open perfs. Wash cement to upper circulation holes at 7685' md. RU CTU. Mill window in straddle interval through 3-1/2" tubing and 7" casing from mechanical whipstock in preparation for CTD sidetrack. February 17, 2000 JJO-i43¥d ]1gill NM31J ..g/I, IP lsd 000~ 'lP ':LN3Nd[no.t dog 3NJ l~alN $1FIV'd ~'V3HS ..g/I, t lsd QO0~ 'P Sd115 OtltlV,d(lXl. i ..g/I, t lsd 000~ 'C SlqY'd ]did ..$1./I, IP lsd 000~ '~, ]O.~VIJ HOL3]NHO~ (~'31d11],q~ ,,L lsd 000~ '1, .. LN3Nd [ ~0.t dog .g 000~ 8 ~ ~ KRU CT @ 1798' 9-5/8" Shoe @ 3455' 3-1/2",9.3#, J-55 Production Tubing to Surface Top of 2-3/8" Liner @ 7350' (proposed) 3-1/2" x 7" Baker FHL Packer @ 7674' Whipstock Collapsed Tubing @ 7752' Low Injectivity Past Collapse: 0.5 bpm @ 3000 psi Shoot Circulation holes 7680' - 7700' Top of P&A Cement @ 7685' 7" Liner & Perfs P&A'd with 15.8 ppg Cement Set Mechanical Whipstock in 3-1/2" tubing @ 7690' Mill Window through 3-1/2" tubing & 7" Casing. Install Bridge Plug @ 7750' 3-1/2" Production Mandrel @ 7710' 2,3/8" FL4$ 4.6# Liner Cemented & Perforated Blast Rings @ 7753' - 7803' 2-7/8" 6.5# J-55 Tubing Tail to 7859' 7" Shoe @ 8220' 3-1/2" x 7" Otis WD Packer @ 7832' 3" OPen hole TD @ 9751' PCR 2/16/2000 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate X Plugging _ Perforate _ Pul! tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elaVation (DF or KB feet): ARCO Alaska, Inc. Development ~ 76' RKE 3. Address: Exploratory ___, 7. Unit or Properly: P.O. Box 100360 Stratagrapic __~ Anchorage, AK 99510-0360 Service ___, Kuparuk River Unit 4. Location of well at surface: 8. Well number: 1157' FNL, 281' FWL, Sec 12, T12N, R8E, UM 3H-14 At top of productive interval: 9. Permit number/approval ~umber: 1684' FSL, 1777' FEL, Sec 1, T12N, R8E, UM 87-123 At effective depth: 10, APl number: 1878' FSL, 1616' FEL, Sec 1, T12N, R8E, UM 50-103-20092-00 At total depth: 11. Field/Pool: 1940' FSL, 1564' FEL, Sec 1, T12N, RSE, UM Kuparuk River Field / OII Pool , 12. Present well condition summary Total Depth: measured 8250 feet Plugs (measured) None true vertical 6374 feet Effective Deptt measured 8129 feet Junk (measured) . None true vertical 6284 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 220 Sx AS I 115' 115' . Surfaoe 3421' 9-5/8" 1350 Sx AS III & 3456' 3001' 400 Sx Class G Production 8187' 7" 800 Sx Class G & 8220' 6351' 175 Sx AS I Liner Perforation Depth measured 7758'-7763'; 7768'-7798'; 7882'-7902'; 7917'-7929'; 7954'-7974' true vertical 6018'-6022'; 6025'-6046'; 6103'-6117'; 6128'-6136'; 6154'-6168' ~~'~'Iv~.,'" Tubing (size, grade, and measured depth) 3.5", 9.3 Ib/ft, J-55 @ 7859' 4nchor~ Packers and SSSV (type and measured depth) '- Packer: Baker FHL @ 7674' & Otis WD @7832'; SSSV: Camco TRDP-1A-ENC @ 1797' 13. Stimulation or cement squeeze summary Fracture stimulate "A" sand on 6/12/98. Intervals treated (measured) 7882'-7902'; 7917'-7929'; 7954'-7974' Treatment description including volumes used and final pressure Pumped .126,691 lbs of 16/20, & 12/18 ceramic proppant into formation, fp was 6783 psi. 14. Representifive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 185 147 31 1145 171 Subsequent to operation 463 290 82 1189 179 15. Attachments MIT form 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations ~ Oil _X Gas _ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my' knowledge. Signed ~~8 Title: Production Engineering Supervisor Date ~//~)/~ Form 10-404 RevJ SUBMIT IN DUPUCATE\ ..~,~. KUPARUK RIVER UNIT .,fELL SERVICE REPORT l~li:j,~u ,~lasKa, Inc. '~1~' 3H-14(4-1)) WELL JOB SCOPE JOB NUMBER 3H-14 FRAC, FRAC SUPPORT 0608982250.13 UNIT NUMBER DATE 06/12/98 DAY 2 FIELD ESTIMATE DALLY WORK PUMP "A" SAND REFRAC OPERATION COMPLETE I SUCCESSFUL I KEY PERSON ~ Yes ~ No ('~ Yes ('~ No DS-YOKUM AFC# ICC# I DAILY COST ACCUM COST KD2424 230DS36HL $108,729 $124,729 Initial Tbg IFinal Tbg I Initial IA I Final IA, I Initial OA IFinal OA ITTL Size 1474PSII 500PSII 432PSll 400PSII 200PSII 200PSII 0.000" SUPERVISOR SCHWENDERMAN Signed IMin ID I Depth 0.000" 0 FT DALLY SUMMARY PUMPED "A" SAND REFRAC. W/4 BBLS FLUSHED SCREENED OUT EARLY. 126,691 LBS PROPPANT IN FORMATION AND 18,407 LBS LEFT IN PIPE. MAX PRESSURE 6783 PSI. [Frac-Refrac] TIME LOG ENTRY 06:00 MIRU DS FRAC UNIT(YOAKUM, LRS, APC) TGSM PT 10,800 PSI,OK. 08:00 PUMPED BREAKDOWN AND CONDITION STAGES ACCORDING TO PROCEDURE. STEPDOWN TEST AND SHUT ISIP 2967 PSI 09:10 PUMPED DATA FRAC, SHUT DOWN AND OBTAIN ISIP 3469. ADJUST PAD. 10:00 PUMPED MAIN FRAC PER PROCEDURE THROUGH 10 PPA. STARTED FLUSH 4 BBLS WATER AWAY SCREENE OUT. MAX PRESSURE 6783 PSI. TOTAL 145,098 LBS PROPPANT PUMPED. TOTAL 126,691 LBS IN FORMATION AND 18,407 LBS LEFT IN PIPE. 13:00 RDMO DS FRAC UNIT. REMOVED TREE SAVER AND LEFT 2 PIECES OF RUBBER IN TUBING. sERVICE COMPANY - SERVICE DAILY COST AccuM TOTAL' $0.00 $640.0~ APC $7,800.00 $8,500100 ARCO $300.00 $300.00 ~ , DN HL TOOLS SOLD $0.00 $200.00 DOWELL $96,469.00 $102,928.00 HALLIBURTON $0.00 $4,201.00 LITTLE RED $4,160.00 $7,960.00 TOTAL FIELD ESTIMATE $108,729.00 $124,729.00 ARCO Alaska, I cr,.G,.~ Post Offid ~-x 100360 Anchorage, .-,taska 99510-0360 Telephone 907 276 1215 October 7, 1993 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WE L..__...~L ACTION ~I--EE) __1A.03 Stimulate $~-~3~- -1G-12 Stimulate c/~.o~ .~1H-01 Perforate - 2C-09 Stimulate ~q- ~'7' ~ 3H-14 Stimulate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany RECEIVED OCT 3 1 1993 Alaska 0il & Gas Cons. Anchorage AR3B-6003-C 1. Type of Request: STATE OF ALASKA ALA~ OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown Pull tubing ~ Stimulate X Plugging Perforate Alter casing Repair well Pull tubing 2. Name of Operator ARCO Alaska. Ir~, 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 5. Type of Well: Development Exploratory Stratigraphic Service 1157' FNL, 281' FWL, SEC. 12, T12N, R8E, UM At top of productive interval 1684' FSL, 1777' FEL, SEC. 1, T12N, R8E, UM At effective depth 1878' FSL, 1616' FEL, SEC. 1, T12N, R8E, UM At total depth 1940.' FSL, 1564' FEL, SEC.1,. T. 12N, R8E, Uu 12. Present well condition summary Total Depth: measured 8 2 5 0 true vertical 6374' feet feet Plugs (measured) 6. Datum elevation (DF or KB) 76' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number ~H-14 9. Permit number/approval number 87-123 10. APl number so-103-2009200 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 81 29' feet true vertical 6283' feet Junk (measured) Casing Length Structural Conductor 80' surface 3421 ' Intermediate Production 8187' Liner Perforation depth: measured 7758'-7763', 7768'-7798', true vertical 6018'-6022', 6025'-6046', Size Cemented Measured depth 16" 200 SX AS I 115' 9-5/8" 1350 SX AS III & 3456' 4OO SX CLASS G 7" 800 SX CLASS "G" & 8220' 175 SX AS I 7882'-7902', 6103'-6117', 7919'-7929', 6128'-6136', Tubing (size, grade, and measured depth) 3 1/2" J-55 AB Mod. @ 7859' Packers and SSSV (type and measured depth) PKRS: BAKER FH @ 7674' and OTIS WD @ 7832' 13. Stimulation or cement squeeze summary A SAND FRACTURE STIMULATION Intervals treated (measured) 7882'-7902', 7919'-7929', 7954'-7974' Treatment description including volumes used and final pressure SEE ATTACHED WELL SERVICE REPORT SUMMARY 7954'-7974' 6154'-6168' True vertical depth 115' 3001 ' 6351' RECEIVE OCT l l 199~ -~laska (J~i & ~as Cons. C0m] Anchorage SSSV: CAMCO TRDP-1A-SSA ~ 1801' 14. Prior to well operation Subse,clu, ent to operation Re.oresentative Daily Average Production.er Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 150~989,'~ 17 1182 633 40 1248 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations ~ Oil X Gas Suspended , Service Tubing Pressure 145 130 ..S~Jned that the forgoing is true and correct to the best of my knowledge. '~- ~*'~ Title Sr. Petroleum Engineer Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE MORNING REPORT SUMMARY 07/07/93 TO 07/07/93 CPF-3 DS-3H 3H-14 07/07/93 PUMPED DATAFRAC WITH DS YF140D CONSISTING OF 4 SLICK WATER PUMP-IN/ INS, 1 NON XL GW PUMP-IN SHUT-IN, & 2 NON XL GW DATAFRACS EACH FLUS WITH NON XL GW STEP VOLUME RATE FWHTP ISIP FG XS FRIC CLOS P CLOS T FE PI~i 150 40 6943 2920 .92 N/A 5450 .... PI#2 25 20 4719 2950 .93 350 5280 .... PI#3 25 20 4683 2900 .92 360 5300 .... PI#4 25 20 4678 2970 .93 290 5450 .... PI#5 65 20 4605 2723 .89 460 5375 .... DF#I 265 20 4518 2850 .91 253 5300 .36 MIN <1% DF#2 141 20 4504 2850 .91 239 5200 .60 KEPT PAD VOLUME @ 57 BBL. RECEIVED OCT 1 1 199;5 Alaska OJJ & Gas Gon$. uummJsStu' Anchorage REPORT OF SUNDRY WELL ! 1. Type of Request: OILAND GAS CONSERVATION COMI~.,~ ~ OPERATION Operation Shutdown Stimulate X Pull tubing , Alter casing Repair well 5. TypeI of Well: ' Development X Exploratory _ Stratigraphic --. Plugging ..__ Perforate _.. _._ Pull tubin~l __. O t h · r .__ 6. Datum elevation (DF or KB) 76' P, KB feet. 7. Unit or Property name Kuparuk River Unit ' ' 8. Well numl~' 3H-14 producer .... 9. Permit number/approval number 90-538 10. APl number so- 103-20092 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool . 2. Name of Operator ARCO Alaska. Inc, 3. Address P. O. Box 100360, Anchorage, AK 9951.0 Service 4. Location Of well at. surface ...... 1157' FNL, 281' FWL, Sec. 12, T12N, R8E, UM At top of productive interval 1684' FSL, 1777' FEL, Sec. 1, T12N, R8E, UM At effective depth 1878' FSL, 1616' FEL, Sec. 1, T12N, R8E, UM At total depth 1940' FSL~ 1564' FELt Sec. 1, T12N~ R8E~ UM 12. Present well condition Summary Total Depth: measured 8 25 0' feet Plugs (measured) true vertical 6374' feet Effective depth: measured 81 2 9' feet Junk (measured) true vertical 6283' feet Casing Length Structural Conductor 8 0' Surface 3 4 21' Intermediate Production 81 8 7' Liner Perforation depth: measured 7758'-7763', 7768'-7798', true vertical 6018'-6022', 6025'-6046', Size Cemented Measured depth True vertical depth 16" 200SxASI 115', 115' 9 5/8" 1350 Sx AS III & 3456' 3001' 400 Sx Class G 7" 800 Sx Class "G" & 8220' 6351' 175 Sx AS I 7954'-7974' MD 6154'-6168' TVD Tubing (size, grade, and measured depth) 3 1/2", J-55, AB Mod. w/tail @ 7859' Packers and SSSV (type and measured depth) FHL Pkr. @ 7674', WD, Pkr. ~ 7832'., Camco TRDP-1A ENc SSS.V @ 1788' 13. Stimulation or cement squeeze summary Kuparuk "A" Sand Refrac. Intervals treated (measured) 7882'-7902', 7917'-7929', 7954'-7974' Treatment description including volumes used and final pressure i4. Gelled Water Refrac: 1064 BBLS Gel Water~79r200# 16/20 LWPr Final S/O Press: 7123 PSI. ..... J:ieoresentative Dail_V AVerS_se Production or In_iectlon" Dam ...... OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 150 70 0 1000 120 Subsecl,uent to operation 4 0 0 3 8 0 30 1 0 0 0 1 3 0 , 15. Attachments ~ 16.' Status of well classification as: I Copies of Logs and Surveys run __ Daily Report of Well Operations ~ ,,, ~ Oil _~ Gas Suspended .._. Service , , 17. I her~:~ certify' that the foregoing__' '{rue and correCt to the best of my knowledge. ' Signed . , Title '~!~-' ~ Date Form 10-404 Rev 06/15/88 ... PLICATE MAR 21 1991 Oil & Gas Cons. C0mmissi0~ , Anch0ra[;,~ IJOdeU /,; ff // · . 1. operations performed: 2. 'Name of Operator STATE OF ALASKA ' ~'~' ; ~" ~ i.', ~ i'~ii ~ ~ L ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Plugging , Perforate ._ X , Other __ S. Datum elevation (DF or KB) Operation Shutdown m Stimulate m Pull tubing X Alter casing Repair well 5. Type of Well: Development X .... Exploratory _ Stratigraphic _ Service measured 8 2 5 O' feet true vertical 6374' feet ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage.,. AK .99510 4. Location of well at surface 1157' FNL, 281' FWL, Sec. 12, T12N, R8E, UM At top of productive interval 1684' FSL, 1777' FEL, Sec. 1, T12N, R8E, UM At effective depth 1878' FSL, 1616' FEL, Sec. 1, T12N, R8E, UM At total depth 1940' FSL, 1564' FEL, Sec. 1~.T12N, R8E~ UM 12. Present well condition summary Total Depth: 59' RKB feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3H-14 9. Permit number/approval number , 87-123/90-578 10. APl number 50-103-20092 11. Field/Pool Kuparuk River Field Kupa,ruk River Oil Pool Plugs (measured) Effective depth: measured 81 2 9' feet true vertical 6 283' feet Junk (measured) Casing Length Size Structural 8 0' 1 6" Conductor Surface 3421' 9 - 5 / 8" Intermediate Production 81 8 7' 7" Liner Perforation depth: measured 7758'-7763', true vertical 6018'-6022', Cemented 200 Sx AS II Measured depth True vertical depth 115'm d 115'tvd 3456'md 3001 'tvd 8220'md 6351 'tvd 1350 sx AS III & 400 sx Class G 800 sx Class G & 175 sx AS I 7768'-7798', 7882'-7902°, 7917'-7929', 7954'-7974' md 6025'-6046', 6103°-6117', 6128'-6136', 6154'-6168' tvd Tubing (size, grade, and measured depth) 3-1/2", 9.2 #, j-55 @ 7832' md Packers and SSSV (type and measured depth) Baker 'FHL' Pkr @ 7674' wlm~ Camco SSSV TRDP;1A-ENC ~ 1797' md 13. Stimulation or cement squeeze summary 14. Intervals treated (measured) .... ~, ~{~ Treatment description including volumes used and final pressure ~[~ ~, ~5 Ct'~S'['~i~i~'''' Re_oresentative Daily Average Production or Injection Dat~'"~~, ~i..!.i' ,.~0'tc,~". OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector__ Oil X Gas . Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form ~0-404 Re,~' 05/~7/89 Title Area Drilling Engineer SUBI~IIT~N DUPLICATE ARCO Oil and Gas Company Well History - Initial Report- Dally Inetmctlone: Prepare and submit the "IM#M R~' on the flret Wednesday .fear a well is spudded or workover oparetlonl ere itlrted. Daily wo~ prior to spuddtn~ Ihe~ld be ~ummerizad on the form giving Inclusive dates only. District .... :. ICounty, parish or borough ARCO ALASKA INC. I NORTH SLOPE Field IL@asa or Unit KUPARUK RIVER 'UNIT ITMI ADL..' 25531 ALK: 2657 Auth. or W.O. no. AK5075 J WORKOVER IStete AK IWell no. 3I~-14 Operator ARCO Date and depth as of 8:00 a.m. 08/23/90 ( TD: 0 PB: 0 SUPV: GB 08/24/90 ( TD: 0 PB: 0 SUPV: GB 08/25/90 ( TD: 0 PB: 0 SUPV: GB 08/26/90 ( TD: 0 PB: 8129 SUPV:GB 08/27/90 ( TD: 0 PB: 8129 SUPV: GB 1) 2) 3) 4) 5) Complete record for each day reported NORDIC RIG #1 MOVING RIG FROM 3Q-2 7"@ 8220' M~: 0.0 DAILY:S864 CUM:$864 MOVING RIG FROM 3Q-2 ETD:S864 EFC:$197,000 7"@ 8220' Z~: 0.0 DAILY:S28,147 CUM:$29,011 ETD:S29,011 EFC:$197,000 MOVING RIG FROM3Q-2 7"@ 8220' MW: 0.0 DAILY:S102,614 CUM:$131,625 ETD:S131,625 EFC:$197,000 LAYING DOWN TBG HGR 7"@ 8220' MW:10.6 NaC1/Br FINISH MOVING RIG FROM 3Q-2 TO 3H-14. ACCEPT RIG AT 19:00 HRS, AUG 25,90. BLED ANNULUS AND TBG, DISPLACE WELL WITH 10.6 PPG BRINE. SET BPV, ND TREE, NU BOPE, TEST BOPE. PULL :~LY: $28,443 CUM: $160,068 ETD: $160,068 EFC: $197,000 :~:!WITH COMP STRING 7"@ 8220' MW:10.6 NaC1/Br ~i.TBG, (4' PUP BELOW SSSV DID NOT HAVE AB MOD RING AND WAS NOT MADE UP TIGHT. RUN TBG BACK IN HOLE WITH NEW SEAL RINGS ON PBR. DAILY:S59,082 CUM:$219,150 ETD:S219,150 EFC:$197,000 IARCO w.I. 55.2521 Prior status if a W,O. The above is correct . Drilling, Page 86 and 8 AR3B-459-1-D INumber all daily well history forms consecutively as they are prepared for each well. Page no. ARCO O~, and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Filial- Rll~rll" On tho first Wednesday after allowable has been assigned or well ia Plugged, Abandoned, or Sold. "Final Report" should be submitted also. WI'left Ol~eret~ofta are suspended for an indefinite or appreciable length of time. On workovera when an official test ia not required upon completion, report completl:Orl and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I County or Parish I NORTH SLOPE Field ILease or Unit JWell no. KUPARUK RIVER UNIT I ADL: 25531 ALK: 2657 ~H-14 I Title [ WORKOVER District ARCO ALASKA INc. Auth. or W.O. no. AK5075 Accounting cost center code Sidle Operator ARCO Spudded or W.O. begun SPUD A.R.Co. W.I. 55,2521 Date I otal number of wells (active or inactive) on this dst center prior to plugging and bandonment of this well our ]Prior status If a W.O. I Date and depth Complete record for each day reported as of 8:00 a.m. NORDIC RIG #1 08/28/90 ( TD: 0 PB: 8129 SUPV:GB 6) RIG RELEASED 7"@ 8220' MW:10.6 NaC1/B= FINISH RUNNING 3-1/2" COMP. ASSBY, TTEST TBG TO 1500 PSI (OK), TEST SSSV CNTL LINE (OK), RILDS, RU OTIS SLICK LINE, PULL CV AT 7629', DISPLACE BRINE FROM TBG W/ 80 BBLS DIESEL, DISPLACE ANNULUS W/ 12 BBLS DIESEL TO FREEZE PROTECT, SET DV AT 7629', BLEED ANNULUS TO 0 PSI, TST TBG TO 2500 PSI (OK), CLOSE SSSV, TST SSSV (OK), OPEN SSSV AND BLEED TBG TO 0 PSI, PULL LANDING JNT, SET BPV, ND BOPE, NU XMAS TREE, TEST P.O. AND TREE (OK), OPEN SSSV, SECURE WELL, RIG RELEASED AT 19:30 HRS DAILY:S65,822 CUM:$284,972 ETD:S284,972 EFC:$197,000 Old TD I New TD I PB Depth Released rig JOate iKind of rig Classifications (oil, gas, etc.) Producing method Type completion (single, dual, etc.) Official reservoir name(s) Potential test data Wei'i' no. D~te Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X.length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected .., The above is correct Signature/q~'-~ /' [Date-- For ,o m p ep~t;on hd distribution, W X-- ~ - see Procedure~Manual,~Section 10, ~ Drilling, Pages ~. AR3B-459'3-C INumber all daily well history forms consecutively as they are prepared for each well. iPage no. Dlvhdon of AllsntlcRIchfleldComplny AL/'"~'~ OIL AND GAS CONSERVATION · APPLICATION FOR SUNDRY APPROVALS '~. Typ~ of Request: Abandon _ Suspend L Operation Shutdown _ ' ' 2. Name of Operator Re-enter suspended Well_ Alter casing _ Repair well X Plugging _ Time extension _ Stimulate _ Change approved program_ Pull tubing ;X Variance _ Perforate m Other _ 5. Type of Well: 6. Datum elevation (DF or KB) Development ARCO Alaska. lng, Exploratory 3. Address Stratigraphic P. O. Box 100360, Anchorage, AK 99510 Service , , 4. Location of well at surface 1157' FNL, 281' FWL, Sec. 12, T12N, RSE, UM At top of productive interval 1684' FSL, 1777' FEL, Sec. 1, T12N, RSE, UM At effective depth 1878 FSL, 1616' FEL, Sec. 1, T12N, RSE, UM At total depth 1940' FSL, 1564' FEL, Sec. 1, T12N, RSE,.UM . . 12. Present well condition summary Total Depth: measured 8250' feet true vertical 63 74' feet Plugs (measured) RKB 59 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3H-14 9. Permit number 87-123 10. APl number so-103-20092 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured 8129' feet Junk (measured) true vertical 6283' feet None Casing Length Size Cemented Structural Conductor 8 0' 1 6" 200 Sx AS I Surface 3421' 9 5/8" 1350 Sx AS III & Intermediate 400 Sx Class G Production 81 8 7' 7" 800 Sx Class G & 175 Sx AS I Perforation depth' measured 7758'-7763', 7768'-7798', 7954'-7974' MD true vertical 601 8'-6022', 6025'-6046', 6154'-6168' 13. Replace damaged tubing and SSSV 14. Estimated date for commencing operation August. 10, 1990 16. If proposal was verbally approved Measured depth True vertical depth 115' 115' 3456' 3001' 8220' 6351' TVD Tubing (size, grade, and measured depth 3-1/2", J-55 set at 7859' MD Packers and SSSV (type and measured depth) Baker FHL pkr @ 7614', Otis WD pkr @ 7832', Camcq TRDP-1A-ENC SSSV @ 1788' Attachments Description summary of proposal _ Detailed operation program ~ RECEIVED Name of approver Date approved 15. Status of well classification as: Oil . X Gas __ Service Prod uce r . BOP sketch Suspended _ j7. I~;~y. ;rtify that ,!]~ foregoing is true and correct ,o the best of my knowledge. ' ' -- ' ~kll v · l , FOR cC)MMI~ION uSE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test~ Location clearance Mechanical Integrity Test_ Subsequent form Original S;r~,*'. "~ Approved by the order of the Commission David W, dgn~'~ · Form 10-403 Rev 06/15/88 require 10- ........ ,, r-...,,.Commissioner ,l~eturned / lqO _ -- · I Date SUBMIT IN'TRIF/LICATE Kuparuk River Unit Well 3H-14 Preliminary Workover Procedure Replace Tubing and SSSV Pre-Rig Operations 1. Obtain 24 hour surface pressure buildup to confirm BHP. e RU slickline unit and pull WRDP. Pull circulation valves at 2874', 5310', and 7621'. Set dummies at 2874' and 5310'. Confirm dummies in place at all GLMs except 7621'. 3. Set blanking plug in 'D' nipple at 7849'. Set isolation sleeve in ported nipple at 7818'. 4. Set BPV. 5. Clear and level pad. Rig Operations 1. MIRU Nordic #1. Displace well with brine. ND tree. NU BOPE. , POH with tubing above retrievable packer. Lay down damaged tubing and SSSV. Redress Baker PBR. 4. Pickup new tubing as necessary and new SSSV. Rerun completion assembly with dummy valves in 1" GLMs and CV with check in 1-1/2" GLM. 5. Release rig. 500O PSI BOP STACK I I 4 ! 3. 1. 9-5/8" CASING HEAD 11" -3000 PSI FLANGE 2. 11" - 3000 PSI X 7 1/6" - 5000 PSI TUBING HEAD 3. 7 1/6" - 5000 PSI X 11" - 5000 PSI CROSS~)VER SPOOL 4. 11" - 5000 PSI BLIND RAMS 5. 11" - 5000 PSI PIPE RAMS 6. 11" - 5000 PSI ANNULAR 13. 14. 15. ACCUMULATOR CAPACI,TY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST FILL BOP STACK AND MANIFOLD WITH BRINE. CHECK THAT ALL HOLI~DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 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 PREVENTER AND CLOSE PIPE RAMS. 6. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. 7. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 8. OPEN PIPE RAMS. BACKOFF RUNNING JOINT AND PULL OUT OF HOLE. 9. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 1 0. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF BRINE AND ALL VALVES ARE SET IN THE DRILLING POSITION. 1 1. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. RE~D TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRIllING SUPERVISOR. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. SRE 9/89 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ 2. Name of Operator ARCO Alaska. Inc, 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface ALASKA OIL AND GAS ~RVATION COMMISSIOI~ I APPLICATION FOR SUNDRY APPROVALS Operation Shutdown _ Re-enter suspended well _ Plugging _ Time extension Stimulate X Pull tubing _ Variance Perforate Other 5. Type of Well: ~ 6. Datum elevation (DF or KB) Development ~ i Exploratory _ RKB 76' Stratigraphic _ I 7. Unit or Property name Service _ I Kuparuk River Unit 1 8. Well number feet Plugs (measured) feet 3H-14 feet 1157' FNL, 281 FWL, Sec. 12, T12N, R8E, UM At top of productive interval 1684' FSL, 1777' FEL, Sec. 1, T12N, R8E, UM At effective depth 1878' FSL, 1616' FEL, Sec.1, T12N, R8E, UM At total depth 1940' FSL~ 1564' FEL~ Sec. 1~ T12N~ R8E~ UM 12. Present well condition summary ' Total Depth: measured 8 2 5 0' true vertical 63 74' 9. Permit number 87-123 10. APl number so-103-20092 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured true vertical 81 29' feet Junk (measured) 6 2 8 3' feet Norle Casing Length Size Structural Conductor 8 0' 1 6" Surface 3 4 21 ' 9 5/8" Intermediate Production 81 8 7' 7" Liner Perforation depth: measured 7758'-7763', true vertical 6018'-6022', Cemented 200 Sx AS I 1350 Sx AS III & 400 Sx Class G 800 Sx Class G 175 Sx AS I 7768'-7798', 7954'-7974' 6025'-6046', 6154'-6168' Tubing (size, grade, and measured depth 3 1/2" J-55 AB Mod. w/tail @ 7859' Packers and SSSV (type and measured depth) FHL PKR ~ 7674'r WD PKR ~ 7832'~ Camco TRDP-1A ENC SSSV ~ 1788' Attachments Measured depth True vertical depth 115' 115' 3456' 3001 ' 13. Description summary of proposal tPerform A Sand refrac w/gelled water and 16/20 carbolite. 14. Estimated date for commencing operation 15. Julv. 1990 ou X 16. If ~3roposal was verbally apProved Name of approver Date approved 17. I herel;w certify that the foregoing is true and correct to the best of my knowledge. Sit, ned '-~~.-"~), ~/~ Title Sr. Operations Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity _ BOP Test Location clearance m Mechanical Integrity Test_ -- Subsequent form require 10-~r~ 8220' 6351' RECEIVED UUL ! Oil & Gas Cons. C_ornm]s i Anchor~9~ ' _ Detailed operation program .~. BOP sketch X Status of well classification as: Gas Estimated BHTP = 4500 psi. Suspended Service IApproval No. Approved by the order of the Commission Form 10-403 Rev 5/03/89 Approved Cooy 0 Returned Commissioner Date *"1~, t~j3 I~;/O SUBMIT IN TRII~LI'CATE ORIGINAL SIGNED BY LONNIE C. SMITH Kuparuk Well 3H-14 A Sand Refrac Procedure Cost Tracking AFE: # K81301 1. Obtain two 12 hour well tests. 2. Pull GLV's from 2874', 5310', and 7621' MD-RKB and depths. Displace annulus with diesel. 3. Pressure test tubing. run DV's @ same Fracture Treatment Quality Control' 1. Check all tanks for cleanliness and check proppant for fines. uncontaminated. Insure water is 2. Insure adequate proppant and water are on location for the frac. 3. Perform pre-frac quality control tests on gelled water using water which has been delivered to the drill site for the frac. Frac Job: 1. MIRU fracturing equipment. Install tree saver and pressure test all surface lines. . Pressure up 3-1/2" x 7" annulus to 2800 psi. Do not allow thi~ pressure to exceed 3500 psi during fracture treatment. Maximum allowable wellhead treating pressure during the frac is 5500 psi. . Pump 150 barrel gelled water breakdown stage, shut-down for ISIP, and check for excess friction. Check tank straps against flow meter and correct flush volume as necessary. . Pump fracture treatment per attached schedule starting with a 800 barrel gelled water pad. The following gelled water systems are acceptable for the refracture treatment: Halliburton: BoraGel Dowell' YF240 B.J. Titan- RXL 5. The expected treating pressure is 4500 psi based on the following' Fracture gradient -- 0.74 psi/ft (6132' TVD) Tubing friction -- 0.28 psi/ft (7834' MD) Fluid gradient -- 0.43 psi/ft (6132' TVD) Estimated perf friction = 400 psi 6. If necessary, cut rate in 1 BPM increments down to 16 BPM during job to reduce WHTP. 7. Bleed down annulus to 500 psi. Rig down fracturing equipment. R CF..iVED LIUL 13 19g0 Oil & Gas Cons. Kuparuk Well 3Ho14 Refracture Treatment STAGE . " CLEAN voLUME PROPPANT DIRTY vOLUME CUMULATIVE STAGE HITS" , (BBL) (POUNDS) (BBL.,) DIRTY VOL (BBL) PERFS @ (BBL) BREAKDOWN (GW) 150 0 150 150 70 PAD (GW) 800 0 800 950 220 SLURRY (GW) 2 PPG 45.9 3860 50 1000 1020 , 4 PPG 51.0 8569 60 1060 1070 6 PPG 55.4 13950 70 1130 1130 7 PPG 50.5 14855 80 1210 1200 8 PPG 59.1 19872 80 1290 1280 10 PPG 34.7 14575 50 1340 1360 12 PPG 13.1 6593 20 1360 1410 FLUSH (SD) 68 0 68 1428 - TOTAL 1327 82273 1428 TOTAL GW 1260 TOTAL SD 68 , VOLUME TO PERFS (BBLS) = 69.6 GW-- GELLED WATER SD -- SLICK DIESEL PROPPANT = 16/20 MESH (CARBO-LITE OR LWP) PUMP RATE = 25 BPM (drop rate if necessary) ESTIMATED TREATING PRESSURE = 4500 psi BREAKDOWN = GW + 40 LB/1000 GAL SILICA FLOUR + BREAKER PAD = GW + 40 LB/1000 GAL SILICA FLOUR + BREAKER SLURRY = GW + BREAKER (NO SILICA FLOUR) FLUSH = SLICK DIESEL '1. Type of Request: 2. Name of Operator ALASKA OIL AND GAS 03¢qSERVATION OOMMI~I~ REPORT OF SUNDRY WELL OPERATIONS ,, , Operation Shutdown Stimulate ~ Pull tubing .v Alter casing Repair well !5. Type of Well: Development X Exploratory _ Stratigraphic m Service ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1157' FNL, 281' FWL, Sec. 12, T12N, R8E, UM At top of productive interval 1684' FSL, 1777' FEL, Sec. 1, T12N, R8E, UM At effective depth 1878' FSL, 1616' FEL, Sec. 1, T12N, R8E, UM At total depth 1940' FSL, 1564' FEL, Sec. 1~ T12N, R8E~ UM 12. Present well condition Summary ' ' Total Depth: measured 8250' feet true vertical 6374' feet Effective depth: measured 8129' feet true vertical 6283' feet Plugging Perforate m Pull tubing .... Ot h e r i6. Datum elevation (DF or KB) Casing Length Structural Conductor 8 0' Surface 3 4 21 ' Intermediate Production 81 8 7' Liner Perforation depth: measured 7758'-7763', 7768'-7798', true vertical 6018'-6022', 6025'-6046', 76' RKB feet 7. Unit or Property name Kuparuk River Unit , 8. Well number 3H-14 Producer 9. Permit number/approval number -504 10. APl number so-1.03-20092 i11,~;Field/Pool Kuparuk River Field · Kuparuk River Oil Pool . . Plugs (measured) Junk (measured) Size Cemented Measured depth 1 6" 200 Sx AS I 1 1 5' 9 5/8" 1350 Sx AS III & 3655' 400 Sx Class G 7" 800 Sx Class "G" & 8 2 2 0' 175 Sx AS I 7954'-7974' MD 6154'-6168' TVD Tubing (size, grade, and measured depth) 3 1/2", J-55, AB Mod. w/tail @ 7859' Packers and SSSV (type and measured depth) FHL Pkr. @ 7674',.WD Pkr. @ 7832', Camco TRDP-1A ENC SSSV ~ 1788' 13. Stimulation or cement squeeze summary True vertical depth 115' 2919' 6351' Intervals treated (measured) 7758'-7763', 7768'-7798' Treatment description including volumes used and final pressure 45 BBLS. Nitrified Acetic Acid~ Final TP -- 2250 psi (BHTP approx. 4050 psi) ReOresentative Daily Average Production .or InjectiOn Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 145 76 0 1000 14. 131 66 0 1000 16. Status of well classification as: Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X Oil , X Gas Suspended Service of my knowledge. 17. I hereby certify that the foregoing is true and correct to the/~best Signed _h(:~-'c~ .~ ~/~¢..~~-~ Title Form 10-404 ~lev 06/15/88 Tubing Pressure 120 118 Date ~/~h' SUBMIT IN DLJPLICATE . ARCO Alaska, Subsidiary of Atlantic Richfield ComPA . WELL SERVICE REPORT j PBDT WE,~ Z)/q- /"/ I ~"~)~ "3NTRACTOR REMARKS FIELD - DISTRICT- STATE IOPERATION AT REPORT TIME JDAYS J DATE / 0 lo30 /5'00 [~'"'CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather ' Temp. [ Chill Factor I Visibility Wind VoL Report °FI °FI miles Signed ~ knotsi ~.,~- REMARKS CONTINUED: DESCRIPTION DAILY ACCUM. TOTAL CAMCO OTIS SCHLUMBERGER DRESSER-ATLAS ; DOWELL ,.~ 3' 8 ¢_.¢' - ' HALLI BURTON ARCTIC COIL TUBING FRACMASTER /o ? ? 2- -- B. J. HUGHES Roustabouts ,5"'0 o '-':" Diesel Methanol Supervision ', t Pre-Job Safety Meeting AFE TOTAL FIELD ESTIMATE , CC: DS Engr.--- NSK Files ~l[~man ---.~ sssv I?fl~ GLM DV or GLV ~$i0 G LV Fou~ Ft . i i i KUPARUK FLUID LEVEL REPORT Fluid Level Shot Down: Casing Tubing CSG Press During Shot TBG Press During Shot Reason For~Shooting FL: ~ To Determine Operating Valve Well Status: t~On Continuous GL Operating CSG Press =,~5r4:~ # GL Rate (If Available)= ~.~ 70 MCFD On Intermittent GL On Time ==~ Min. Off Time = Hr. Min. Delta Time From End Of On Cycle= . .. No GL Min. Comments: RECEIVED 181989 A~,aska Oil & Gas Cons. Oomm~Ssto~' Anchorage ARCO Alaska, Inc. Date: December 6 1989 Transmittal #: 7618 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 H- 14 Kuparuk Fluid Level Report 11 - 1 8 - 89 Casing 2 A- 11 Kuparuk Fluid Level Report 11 - 30 - 89 Tubing 1 G-11 Kuparuk Fluid Level Report I 2-2.89 Casing 1 Q- 13 Kuparuk Fluid Level Report 11 - 30 - 89 Tubing 1Q-09 Kuparuk Fluid Level Report I I-30-89 Tubing Receipt RECEIVED · _---- DEC 1 81989 , Acknowledged - Date~\Jaska 0[l'&'~;;s' ~;ons. C0mmml0].t /~chorage DISTRIBUTION: BP Chevron D&M Mobil Unocal ARCO Alaska, In?~ Post Office-I:lox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 8, 1989 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 'Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in triplicate are multiple Applications for Sundry Approvals on the following Kuparuk wells. Well Action Anticipated Start Date 2 X- 1 2 Scale Sqz. June, 1989 2A- 1 5 Scale Sqz. · June, 1989 2A-09 Scale Sqz. July, 1989 3 H- 03 Acidize June, 1989 3H-1 4 Acidize June, 1989 2 U- 1 2 ~ Scale Sqz. June, 1989 2 W- 0 7 Scale Sqz. June, 1989 3 J - 0 6 Fracture June, 1989 3 J - 0 2 Fracture June, 1989 3 A- 1 0 Perforate June, 1989 I E- 0 6 Acidize June, 1989 I E- 1 1 Acidize June, 1989 1 E- 1 5 Acidize June, 1989 If you have any questions, please call me at 265-6840. Sincerely, G. B. Smallwood Senior Operations Engineer ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany RECEIVED IUN ! Igsg Alaska Oil & Gas Cons. Commlss;on Anchorage STATE OF ALASKA ALAsF, A OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate X Pull tubing _ Variance _ Perforate _ Other 6. Datum elevation (DF or KB) 2. Name of Operator ARCO Alaska, In(;, 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1157' FNL, 281 FWL, Sec. 12, T12N, R8E, UM At top of productive interval 1684' FSL, 1777' FEL, Sec. 1, T12N, R8E, UM At effective depth 1878' FSL, 1616' FEL, Sec. 1, T12N, R8E, UM At total depth 1940' FSL 1564' FEL, Sec. 1, T12N, R8E, UM 12. Present well condition summary Total Depth: measured 825 O' true vertical 6374' 5. Type of Well: Development .~. Exploratory _ Stratigraphic _ Service _ feet Plugs (measured) feet RKB 76' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3H-14 /~/~ ,~ ~L~ ~_~ 9. Permit number 87-183 10. APl number so-1 03-20092 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured true vertical 81 29' feet Junk (measured) 6 2 8 3' feet None Casing Length Structural Conductor 8 0' Surface 3 4 21 ' Intermediate Production 81 8 7' Liner Perforation depth: measured 7758'-7763', true vertical 6018'-6022', Tubing (size, grade, and measured depth Size Cemented Measured depth True vertical depth 1 6" 200 Sx AS I 1 1 5' 1 1 5' 9 5/8.' 1350 Sx AS III & 3456' 3001' 400 Sx Class G 7" 800 Sx Class G 8220' 6351' 175 Sx AS I 7768'-7798', 7954'-7974' RECEIVED 6025'-6046', 6154'-6168' JUN ,[~~ 13. Perform 'C' Sand Acid Stimulation w/10% Acetic Acid. 3 1/2" J-55 AB Mod. w/tail @ 7859' Alaska Oil & Gas Cons, Packers and SSSV (type and measured depth) Anchorage FHL PKR @ 7674'~ WD PKR @ 7832', Camco TRDP-1A ENC SSSV ~ 1788' Attachments Description summary of proposal Detailed operation program .~ BOP sketch No workover fluids will be used. Est. BHTP: 4000 14. Estimated date for commencing operation June. 198~t 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ '.xC,,(~;~ Title Sr. Operations Engineer FOR COMMISSION USE ONLY 15. Status of well classification as: Oil ~ Gas __ Suspended Date Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test~ Location clearance Mechanical Integrity Test~ Subsequent form require the order of the Commission Form 10-403 Rev 5/03/89 ORIGINAL SIGNED BY LONNIE C. SMITH IApproval No, ~,pproved Copy Returned Commissionor Data SUBMIT IN TRIPLICATE KRU WELL 3H-14 'C' SAND ACID STIMULATION PROCEDURE CHARGE CODE: 230DS36HL Pre-Wireline Work- 1. MIRU slickline unit. 2. Pull Otis comingling sleeve. 3. RI H with Otis XN Flow Sleeve Plug. This sleeve will enable the 'C' Sand to be opened while the 'A' Sand will be closed via the plug in the bottom of the sleeve. This sleeve can be rented from Otis. 4. Obtain a 'C' Sand well test, obtain a wellhead fluid sample, and perform sludge and emulsion tests (see attached forms). Send a copy of the test results to Steve Bradley at ATO-1156. Stirnulatiort; 1. MIRU CTU, transports, nitrogen, and pumps. 2. Titrate 10% Acetic acid. 3. RIH with CT to 7818' MD-RKB and pump the following fluids at 1 BPM (do not exceed surface formation breakdown pressure of approximately 2100 psi). A. 35 BBLS of diesel with 10% Musol (68 BBLS diesel/7 BBLS Musol). B. 35 BBLS of nitrified MRS200 (nitrify with 500 SCF per BBL of MSR200). C. 5 BBLS of diesel. D. Displace CTU with Nitrogen (24 BBLS). 4. Open well to tanks immediately. Nitrogen lift if necessary. Strap tanks every 15 minutes until at least 100 BBLS. of fluid has flowed back. Strapping can be extended to every 30 minutes after the first 100 BBLS. 5. Obtain 2 samples of the spent acid (spent acid will be at the wellhead after approximately 55 BBLS have flowed back) and analyze for ferrous and ferric iron (send copy of results to S. Bradley - ATO 1156). 6. Continue to flow to tanks until 300 BBLS of fluid are recovered. 7. POOH with CT. 8. RD equipment. 9. Obtain well test. Post Wireline Work: Do not proceed with post wireline work until a valid well test has been obtained. 1. MIRU slickline unit. 2. RIH and pull flow sleeve. 3. RIH with commingling sleeve. 4. POOH. RDMO slickline unit. NOTE: 1. Dowell will need at least 14 days advance notice before the job can be pumped in order to have the fluids shipped to Kuparuk from the Lower 48. SDB (6/6/89) el~eJotiou¥ uoiss!tutuoo 'suoo se9 V !!0 e~lSeiV XOg ONI..IJr'lJ.$ ,,g I,/I,t, lsd 000<~ 'g $1~V~ CINIqg ..g/I, t, lsd O00g Sdlq$ :::)I'IIqY~(:U,H ,,9/I, ¥ lsd O00g SINV~I 3did ,,gl,/L t lsd 000<~ 30NV'IJ ~IOLO3NNO0 Chr3Hqq3~ ,,/. lsd 000<; '1, i I III i i ~ I ! iii i i 9 1. T;pe of Request: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ,, Operation Shutdown Stimulate __ Plugging Perforate Pull tubing Alter casing Repair well Pull tubing Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic --. Service 4. Location of well at surface 1157' FNL, 281' FWL, Sec. At top of productive interval 1684' FSL, 1777' FEL, Sec. At effective depth 1878' FSL, 1616' FEL, Sec. At total depth 1940' FSL, 1564' FEL, Sec. 12, T12N, R8E, UM 1, T12N, R8E, UM 1, T12N, R8E, UM 1, T12N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 8 2 5 0' feet Plugs (measured) 6 3 74' feet 6. Datum elevation (DF or KB) 76' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 3H-14 9. Permit number/approval number 8~758 10. APl number 5o-103-20092 11. Field/Pool Kul3aruk River Oil Pool , feet Effective depth: measured 8 1 2 9' feet Junk (measured) true vertical 6 2 8 3' feet Casing Length Size Cemented Structural Conductor 8 0' 1 6" 200 SX AS I Surface 3421' 9 5/8" 1350 Sx AS III & Intermediate 400 Sx Class "G" Production 81 8 7' 7" 800 Sx Class "G" Liner 175 Sx AS I Perforation depth: measured 7758'-7763', 7768'-7798', 7954'-7974' MD true vertical 6018'-6022', 6025'-6046', 6154'-6168' TVD Measured depth 115' 3456' 8220' Tubing (size, grade, and measured depth) 3 1/2", J-55 Tubing with tail @ 7859' Packers and SSSV (type and measured depth) FHL pkr @ 7674' WD 13kr @ 7832', Camco TRDP-1A ENC SSSV @ 1788' 13. Stimulation or cement squeeze summary Intervals treated (measured) True vertical depth 115' 3001' 6351' Treatment description including volumes used and final pressure ' " Re.oresentat'iVe Daily Average.Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure ,, , Tubing Pressure Prior to well operation Subse.cj[u.ent to operation 180 180 0 900 180 180 0 9OO 180 180 15. Attachments Copies of Logs and Surveys run . X.. Daily Report of Well Operations X .... 16. Status of well classification as: Oil . X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 1'0-404 Re~ 66/1~/88 ' SUBMIT IN DUPLICATE Report of Sundry: Well 3H-14 Approval Number' 8-758 An application of sundry was submitted for Well 3H-14 on October 5, 1988 for purposes of operating the well while 'performing diagnostic work to determine the source of tubing X 7" communication. Approval was received from the State on October 6, 1988 (approval number 8-758). Diagnostic operations consisted of noise and temperature logs and pressuring up and bleeding off of the tubing, 7" casing, and 9 5/8" casing. It was determined that a small leak in the pup joint below the SSSV was the source of communication. Attached is a copy of the logs that were run and the report of the daily well operations. SDB (5/17/89) Lo~ ~ ~7. ~~, Icc c/~ ~ ~ ~ ~{~-~ ~ ~~XT ~r -- I t I ~ Il mm mi 1 i iiii Il I I Ti~ EvDrr 17:51 ~?qO, I 1900 CP 27· 290 FILE DATA 5 lO-DEC-S8 16~44 ACQUIRED lO-DEC-88 13~48 300000 HSH ~;MY ) 30.000 300000 N4H ( MY ) 30.000 300000 W3H ( MV ) 30.000 300000 ........................ _l,,l_a_H_ _ _,:_I'LJ Y_ _ _ ? ........................ 30.000 300000 NIH (MV ) SEMSOR MEASURE PO IHT TO TOOL ZERO c:)~. c) o c) c) o ~EPTH: I8e~.53 Fr ~SlTI~ Ht HI~ 1077,48 . ~;.52_1 I£1.617 IMCLLI]]E THIS ~ (Y/M) Y DEPTH: I86~. 53 HI~ 776.58.1 161.Z51 12.4. 78.I i[~I.UI)E TI~IS ME1B~d~~? (YxM) Y DEPTH: 18E~6.53 FT RCqlJISITIOlt 13 H I L~HP8~ ,-' ~-'~72.03I 144.646 110.513 ii'~CLUI~ THIS ~? (Y/M) "t BEPTH: I866.53 FT RC~JlSITIOtl 84 HIGHP8~ 7'41='386 155.854 117.070 IMCLUDE THIS f%ER.gLIRE~tT? (Y..I~) Y DEPTH: I836.63 FT F~2BUISITIOM ~ HIGi4F~S ::J78.543 517.003 488.593 iHCLUDE THIS ~~T? (Y/M) Y 8.4. ~i 0.0 0.0 0.0 288 24.6':K:~ '.37. 8343 DEP.'FH:I836.63 FT RCq-~UISITI~ ~5 Hi~t¥SS 891.56I ~.o. 879 49'3. 812 iNCLUDE THIS ME~T? ( Yx~t~ Y 297.078 31. 0494 39.1918 DEPTH: i836.63 FT RCQUiSITIO~I t7 HIGHFIBSS P_,E1.551 531. 720 500.491 IMCLUDE THIS ME~T? ( Y/M ) Y 293.86E ~. 5847 41. 8636 DEPTH:iS36.63 FT RC(3JISITIOII ~8 - HI~ 891.588 538.088 506.7'66 iMCI_U~ THIS ~_8StJREMEIIT? (Y/M) Y 287.376 37.7409 47.5086 DEPTH:ISIO.66 FT RCQUISITIOt9 ~9 H I GHPS~ 2331.56 i888.27 1648.08 I~tC1_UDE THIS ME--MT? ( Y,-~ ) Y 7.99.6.--'0 201.353 48. ~ DFPTH: 1810.66 FT RC%]UISITIOII ttlO HiGHPRb-~S 2015.61 iL~_4.79 I I~'7.04 IHCLUDE THIS I~D:kSilI%EMEHT? (Yxlg) Y 603. 656 i 14. 067 61. 7879 DEPTH': 1810.66 el' i3COOlSlTlOl~ Ill H I Glf'6~ I Em,_,6. ~ 760,... :38 i 70 6.276 iMCLUDE THIS r~dtSOREI'EI~T? ( Y-'M ) "( 397' 657 8,4. 7349 51 · 4988 D~TH: iSiO.~ FT RCO~ISlTIOtt H i L~HPRSS 110 6.65 598.526 564. iHCLUDE THIS ~_R.SUREMEIIT? (YxM) '-( 339. ~ 5 48. E455 42.0446 DEPTH: i809.05 FT P~ISITIOtt ~t3 H I GHPR~ 938. ~6 577.744 545.98R ZMC]_UDE ~IS MEBSUREI'E~T? (Y/M) Y 328. 699 48. 8538 45. E728 -DEPTH: i:909.05 ~-i' RCI3JISiTiOM ~f14 Hi~8SS 911.969 588..820 ~4. 125 IMCLUDE ,']dis ME.~--dJt~'iEIfF? (Y/ri) Y 341. 581 45. 3887 4~ . 5589 DEF']H: 1809.05 Fl RCQUISITIOI9 $15 H IGHPR~S 876. ~%~B 547.8.31 517. 4~5 ir!CLUDE THIS HF. RSI~EIIT? (Y/M) Y :~. 078 39.4~_Fg4 38. 4545 DEPTH: i809.05 FT 8CQUISITIOM ~16 H i ~-~SS 9~0. ~0 554.80 9 58.5 IMCLUI~ THIS ~EFk?W.~.EMEMT? ( Y,'M ) :~4. iE"86 :35. 4586 '&9. 7895 DEPT~: 18~8.89 Fl' P~xolTIO;1 #17 HIGHPF~ 1084.68 58~.376 583. I9~ IMCLUIE ]'HIS HEASUR~D~DO'? (Yx19) Y DEPTH: 18~8.89 F1 fl~ISITIOM #18 HIGHPSSS 868.037. 548.388 517.83~ IHCLUDE THIS M~. (Y/M) Y DEPTH: I~!~18.S~9 FT RO33ISITIO~ #19 HI GHPS~ 899.679 .568.608~ 537. 768 IHCLUI]E THIS MF_~T'? ('f/M) Y DEPTH: 1806.'~3 FT F~ISITIOH ~ H i 12HPSSS 1156.47 598.8?7 .568. -i-; 0 i~CLUDE THIS ~.~St~T? { YzM) Y D~TH: I806.93 FT F~CQUISITIOM HIGHPRSS 988.141 5%. 169 568. i85 IHCLU~ THIS ~~~? DEPTH: I:~06..03 FT rlP~ISITiO~ ~ HIGHPS'-~ 1066.17 767. i14 781.666 iM~JODE THIS t~gSU~? (Y/M) Y *,3 " DEPI'H: ~0o.23 FT E~SC~ISITI~ ~ n i .~-r~oo 1030.04 ,' m,~. 8.66 719.416 IM,1CFl~E THIS MEF~URF_~? ( Y/~ ) Y DEPTH: 1806.23 FT Ft(~ISITIOH ~.04 H.IG;-~'SSS °~088.3(; ~0355..°3 E085.08 IbBCLUD[ THIS M~? (Yzl~) Y D~'I'H: 1804.76 FT :~ISITI~ ~ Hi T. iHPHSS l 1G~3.36 7i8.671 m~4. 791 DEPTH: ~ ~o04.;'~ FT P~ISITIO~ Hi~HPSSS 937.051 659.0441 619.9QO i~iCLUI]E THIS MES~T? (Y/H) "? DEPTH: 1804.63 FT ~ISITiO~ .. .~rn~o i043.%~i 748.043 706.157 DEPTH: 1804.63 FT F~ISITIO~ ~429 H I L~HPSSS I079.78 759. O I9 715.577 i~CLUDE THIS ME~St~E~T? (Y/M) Y DEPTH: 18Q4.63 FT ;~D2~JISITi~ ~3~ Hi~PSSS i 16Q. 8.8 7~7.915 686. ii-,lODE THIS ~T'7 (Y,,"M) Y DE~i]H: 1804..03 FT F~ISITIO~ #38 H IC~H~SSS I~4.49 675.186 6~. 159 ZMCLUI]E THIS ~:.SSi~T? [ Y/M ] Y 3",:;8.430 '-344. 713 371.5R8 865 438.519 11.00.39 ~I. ,-"81 388.145 40 t-'. i83] 383.993 E7.5500 53.8911 49.'9485 59.76i0 78.3455 61.E617 ~7.871 I4~. 987 67.51'~ 2989 39.4335 q~_.IlO0 45.696~ 51.8103 47.63.07 51.43'-28 37. i601 83.5876 ........................ I II I I I~ ~ ........... ., - - DEPTH: 1884. I0 Fl' F~J:lt_~ITIOet #33 HI~~ 9~.~ 6~.~ ~.~I I~ ~IS ~7 (Y~) Y 381. 126 57. 8D88 39.0118 DEPTH-: I884. I0 F-~ F~ISITI011 #34 H I{~ i007.97 654. °..43 683.798 IMCI. L~ THIS ~? (Y/N) Y 363.410 44.2.30E 30.~4 DEPTH: 1804. l0 FF P~ISITIOM #35 HIL~ 2677.16 2085.68 I988.56 £MCLUIIE THIS MERIT? {Y/M) Y i005.04. 257.3Q9 57.17~8 DEP,TH:I:~Q2.63 FT F~CQUISITIOM #3~ HIGHPRSS 1823.73 t24I.~-~9 I177. IHCLUDE .THIS ~T? (Y/M) '¥' 694. 528 196. 785 80.98~9 · DEPTH: 1802.63 ~ PEQUISITIC~9 #37 H I C4-~Ff-3S i353.07 '.%6~. ~] 911.630 iNCLUDE THIS ~_8~tJREME~T? (Y/M) Y 536.042 I I3.3~10 61.~9 DEPTH: 1802.63 FT ~ISITIOM HiGHPSSS I15~.01 807.451 77'2.497 IMCLUBE THiS ~7 [Y/M) 'f 47i . b32 80 . q-TEN] q~5.2101 DEPTH: 1802.52 FT F~ISITIOM #.39 HI Gt-tPS~ i 125.27 765. 196 7:39.495 iMCLIil]E THIS MEREST? (Y/M) Y 447 68.39~i 49.0115 DEPTH: ie~2. 52 FI RCQUISiTiOM ~ HI~ 1070.96 749. ~0 7E3.000 IHCLUDE THIS FF_SSU~EME~T? (Y/M) Y DEPTH: 1802.52 FT F~ISITIOM ~1 HIm~ 1181.81 L'~D. 515 752. 045 iliCLUDE THIS ,~R~SU~T? ( Y/M)- Y DEPTH: i72t12, i0 'Fg' ;~QUISiTiOH ~ ;: 'rl~ ~.l-~, · ,~ l ~8So i25-m6.69 791 7~ 766.7~ INCLU~ THIS ~~tT?' (Y/M3 Y 448.451 510 .E~]2 ~'2. ~5~4 OEPTH: 1802. iOFT ~JlSITIOM HiCJ-H~ 1120 19 I IMCLL~ THIS ~~~?' (Y-~) Y 493.44)7 73. O 137 45. 9769 D~'TH: io~]2, iO FT F~ISITIOM ~4 HIGHP~SS i08~.89 756.412 72B.304 INCLUDE THIS {'F_.flSJJREPH~P~? ( Y,~I9 ) Y 487. 589 ~. 6466 45'. 8598 DEPFH:iSill.99 FT RCOUISiTIOM ~5 H I GHfM~SS 1184. 44 788.4% ~. 172 iMu'~._UDE THIS i~~RED'E~tT? ( Y/M ) "," .504.072 ;.'6.7235 46.0706 3EPiIH: 1GQ 1.99 FT Pi.-X33ISITIO~ ~46 H I GHPSSS 1115.02 816.843 787.376 IMCLUI}E THIS MEflSUREMEHT? ( Y.drt ) Y 513 · 570.. 84. 749~ 51 . 52.67 DEPTH: 18il 1.99 FT hC~ISITIOM ~7 HIGHPFPJS 2179. :~ i6£9.53 i538.30 IMCLLr~E THIS; FES~JF.'FMF_3tT? (Y./M:~ Y 924. 164 ~{li..52_8 105.6P.4 3EPTH:iSOO.53 FT FEQUISITIOM /f48 Hi~~ 1157.21 775.713 747.053 IHCLLO)E THIS MEB~~? (Y/N) Y 52~) .216 128. ~ 5Q. · ' I DEPTH: I880.40 FT ,FE~33ISITIOM HI--SS I584.94 1164.33 1134.87 THIS 1~? (Y/M) Y 690. DEPTH: 1800.44I FT F~3Q{JlSITIO{~I ~I HI~ i371.68 I1;:'6.7?' I097.36 IHCLLrDE THIS NEFt~? ( Y/H ) Y 666.006 134.538 61.5437 IEPTH:ITS~J.73 FT ~-~UISITIO~ ~ H IC~4P~ ~.638. '?~. L~;59.04 I85~. 3~P_ It~CLb'~E THIS ME~? ~ Y~) Y · =_.60.630 0.0 0.0 DEP~H:1795.?3 FT FEiQUISiTIOM ~ HIGHFI:~SS 1580.53 959.471 ',:~6. i4~ Ib~C2_U])E THIS t~:.F~? (YxTt~ Y 338.~ ~.,' .0000 'DEPTH: 1791. ~ Fr F~ISITIOtl ~ HI~ 905.98.1 552.."~ 510. ~ INCLUDE THIS MEF~. ? ( y.xt{ ) y 176.120 0.0 DEPTH: 179I. ~ FT F~ISITIOI~ #55 Hi--SS 8_031.54 1412. 74 II08.88 IHCLLE~E THIS MF_R~MT? ~Y,'M) Y 864. 156 0.0 0.0 DEP~: 1789.69 Fl' F~2QUISITIOII ~ HI~~ 1710. iii 891. ~ 797. 764 INCLUDE THIS t~~7 ( Y-'H ) Y 147.570 0.0 0.0 DEPi'H: 1789.69 FI Fr~ISITIOII ~57 H I GHPF~SS 1618.81 :~6.781 766.654 IHC'LO~E THIS ~? ( 'c';~ ) 5" DEPTH: I 7G9.16 FT F~.~ISITIOM ~ HiGHPFt~ 1 I,°4.27 504.791 478.. i45 INCLUDE THIS MErle? ( Y,'?~ ) Y DEF?~: 17.'39.16 Fi' 8C~JISITIOH ~59 H I L~4F'R~ 135,?.. 4? 430.502 44)0.591 INCLUDE THIS MERSUREMEITF? ( Y/l~ ) %-: i59.887 0.0 158.08I 0.0 12'9.7St] 0.0 :). 0 DEPTH: 1784.93 Fr F~CqUISITIOll ~6~ Fi I C, HPFkSS i 103.08 4{85. '9~_ .c_;BO. 061 Ir~cJ_UDE THIS ~'~E~iE]gF_.t'FI','T' ( Y.~M ) Y 643 :). 0 a4.8E69 · DEPTH: 17:24.93 FT FtO~UIStTIOM t~61 HiGHPS~ IEt~1.07 447.637 409. 134 t?ICLUDE THIS ~MF_NT? t Y/ti) Y 118.678 0.0 II.I~99 DF_PUd: i7~.45 FT' flCQUISITIOtl ~ HtC~PASS 8838.41 I065.54B 873.109 IMCLb~E THIS ME--hr['?' ( Y.,9'i ) Y ?o, ~. ?:~a8 0 . O 0.0 DEPTH: 1753.45 FT F~ISITIOtl H t GNP 1516.2I :378.785 720. INCLLrl)E THIS MF_ASI~IIT? ( Y.'H ) Y I87.875 0.0 0.0 AD_ ~, OIL AND GAS CONSERVATION COMMI, ,ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well_ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance X Perforate _ Other _ 6. Datum elevation (DF or KB) 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. BOX 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1157' FNL, 281' FWL, Sec. 12, T12N, R8E, UM At top of productive interval 1684' FSL, 1777' FEL, Sec. 1, T12N, R8E, UM At effective depth 1878' FSL, 1616' FEL, Sec.1, T12N, R8E, UM At total depth 1940' FSL, 1564' FEL, Sec. 1,.. T12N, R8E~ UM RKB 76 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3H-14 9. Permit number 87-123 10. APl number 50-1 03-20092 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured true vertical 8250' feet Plugs (measured) 6 3 7 4' feet None Effective depth: measured 81 29' feet Junk (measured) true vertical 62 8 3' feet None Casing Length Size Cemented f b,.,+ ;ll ,.,all Me~ured depth True ve~ical depth Conductor 8 0' 1 6" 200 Sx AS I Surface 3421' 9 5/8" 1350 Sx AS III & 400 Sx Class G Production 81 8 7' 7" 800 Sx Class G & 175 Sx AS I Perforation depth: measured 7758'-7763', 7768'-7798', 7954'-7974' MD true vertical 6018'-6022', 6025'-6046', 6154'-6168' TVD Tubing (size, grade, and measured depth 3 1/2", J-55, tbg w/tail @ 7859' Packers and SSSV (type and measured depth) FHL pkr @ 7674', WD pkr @ 7832', & TRDP-1A ENC SSSV @ 1788' 13. Attachments 115' 115' 3456' 3001' 8220' 6351' Description summary of proposal JAt' O 5 tg .q Detailed operation program _ BOP sketch_ i4.'' Estimated date for commencing operation ... December, 1~){~ 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ~ Gas _ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ? FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test_ Subsequent form require 10-,'~J'~ ORIGINAL SIGNED BY Approve, d by the order of the Commission LONNIE C. SMtTH Form 10-403 Rev 06/15/88 IApproval No.~... ~) q Commissioner ,Date /'"'/~"~? Approved Copy SUBMIT IN TRIPLICATE Returned _ KRU WELL 3H-14 APPLICATION FOR SUNDRY APPROVAL Kuparuk River Unit Well 3H-14 is a Iow rate oil well currently producing 180 BOPD @ 900 GOR on natural flow. The annulus between the tubing and 7" casing has been observed going on vacuum, indicating a leak to another string. An application for sundry approval was filed with the State and approved October 6, 1988 (Attachment 1). This application granted Arco a variance to continue producing the well to diagnose the leak location. Results Arco's diagnostic work consisted of monitoring tubing, 7", and 9 5/8" pressures while pressuring up or bleeding off various strings, pulling and resetting dummy gas lift valves, and running a noise/temperature log for leak detection. A summary of the leak detection work is presented as Attachment 2. Conclusions from this work are shown below: . . The 7" by 9 5/8" annulus has integrity. The packer has integrity. . .i EC IYED JAN d ~ ]9~fi Al_a~l tDii & ~as Cons, A small tubing leak is located at the base of the 4' pup joint beneath the SSSV. When gas lift is applied to the tubing x 7" annulus, the noise and temperature logs identify this leak. The size of the leak is such that the gas lift flow from the casing to tubing is immeasurable with surface meters. Proposal Arco requests a continued variance according to AAC 25.200(d) to operate Well 3H-14 with the small tubing leak. The location of the tubing leak and verification of the integrity of the 7" x 9 5/8" annulus and packer has demonstrated the safe operating condition of this Iow rate oil well. Monitoring of the tubing, 7", and 9 5/8" pressures will continue to insure 7" x 9 5/8" annulus and packer integrity. Casing Gas lift will be used to operate this well which will establish intentional communication from the casing to the tubing via the gas lift valve. The minor gas passage through the tubing leak should not effect the efficiency of the gas lift operation. Should any adverse pressure responses be observed in this monitoring, Arco will notify the State in a timely manner via sundry application, and diligently pursue diagnostic and corrective action. ! · , · I ! i I ~i ~- ~1 I · ~ i ~ 1 q~l i ~ I ! 1 ~ii ' ~/ii lit ,~ I ii i ', ~ - ~ [i ' ~ [ i . ~ ! ~ ~' i : i ~ i I 1900 ATUR ATTACHMENT 1 N.ASKA OIL AND ~ CON~=RVA~ ~S~UN APPLICATION FOR SUNDRY APPROVALS I'1. Type ot Request: Abandon_ Suspend _ Operation Shutdown'_ Re-enter suspended well_ Nt~' oaaing _ Repair well _ Plugging _ 2. Name of Of=eral~ ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 4. Location of well at surface 1157' FNL, 281' FWL, Sec. 12, T12N, R8E, UM At top of productive interval 1684' FSL, 1777' FEL, Sec. 1, T12N, R8E, UM At effectiv~ depth 1878' FSL, 1616' FEL, $ec.1, T12N, R8E, UM At total depth 1940, ESL, 1564' FEL, Sec. 1., T12N, R8E., UM 12. Present well condition summery Total Depth: , Cllll~ alN3mved program_ Pull tubing _ $. Type of Well: Development :X Exploratory _ i Stratigraphic _ 99510 Service _ Time extension _ Stimulate Variance .~ Perforate _ Other _ 6. Datum elevation (DF or KB) RKB 76 ,, feet _ 7. Unit or Property name Kuparuk River Unit.. 8. Well number 9. P~'ermit number 87-123 10. APl number S0-103-20092 11. F~d/Po~ Kuparuk River Field , Kup, aruk River Oil .P. ool measured 8250' feet Plugs (measured) true vertical 6374' feet Norle Effective depth: measured true vertical 81 2 9' feet Junk (measured) 6283' feet None Casing Length Size Cemented Measured depth True vertical depth Conductor 8 0' Surface 3 4 21' Production 81 8 7' Perforation depth: measured 7758'-7763', true vertical 6018'-6022', Tubing (siZe, grade, and measured depth 1 6" 200 Sx AS I 1 1 5' 1 1 5' 9 5/8" 1350 Sx AS III & 3456' 3001' 400 Sx Class G 7" 800 Sx Class G & 8 2 2 0' 6 3 51' 175 Sx AS I 7768'-7798', 7954'-7974' MD 6025'-6046', 6154'-6168' TVD JAN u 5 ]9 9 14. Estimated date for commencing operation 115. Status of well classification as: October 6. 1988 ! o, .~ Gas _ 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed 't'!',4-~.~ ~,. ,, ~.<.,. . T!tle . ,~ .~ ~.,,~ ~ ' ' FOR, COMMISSION USE ONLY .... Conditions of approval: Notify Commission so representative may witness Plug integrity _. BOP Test Mechanical Integrity Test_.. Approved by the order of the Commission Form' 10-403 Rev 06/15/88 Location clearance.._ Subsequent form require , I ....... ....... · , Commissioner Suspended _ ]Appro~/'al'No4~_' 7~-'-'~I . Date /" ' ; ' SUBMIT IN TRIPLICATE KRU WELL 3H-14 APPLICATION FOR SUNDRY APPROVAL Kuparuk River Unit Well 3H-14 has suspected communication between the tubing and tubing x 7" annulus (7"), and possibly the 7"x 9 5/8" annulus (10"). The well is currently shut in pending review of this application. The Commissioner's approval as authorized under AAC 25.200(d) is requested to continue producing this well to perform diagnostic and repair work. Diagnostic efforts will include monitoring tubing, 7", and 10" pressures while pressuring up or bleeding off various strings, pulling and resetting dummy gas lift valves, and running leak detection logs if warranted. Well 3H-14 is a 3 1/2" single completion with two packers and 5 dummied gas lift mandrels. It is an oil 'producer and is not on gas lift. The Kuparuk C Sand is currently shut in and was last tested at 47 BOPD, 300 GOR. The Kuparuk A Sand is producing 143 BOPD at a 1050 GOR. The pressures for the three strings are summarized below: FTP = 150 psi 7" = on vacuum 10" = 250 psi. Since Well 3H-14 is a Iow rate producer and is not on gas lift, the possibility of wellbore fluids entering formations from the 7" or 10" strings is believed to be minimal. Continued operation of the well is recommended to augment diagnostic efforts so that any leaks may be repaired. RECEIVED JAN ~ S !9~q Alaska Oil & (las Cons, Commission; ~chorage WELL 3H-14 SURFACE LOCATION: 1157'FNL, 281'FWL, SEC12, T12N, R8E TREE: McEvoy 3-1/8' 5000 PSI DEPTHS REFERENCED TO (7 RKB TUBING SPOOL ELEV: 35' RKB 16": 62.5# H-40 @ 11s' 9 5/8": 36# J-55 @ 34s5' PBR: BAKER 2.992' ID @ 7660' PKR: BAKER FHL 2.992' ID @ 7674' L OTIS XN NIPPI F WITH SLEEVE 2.35' ID @ 7818' C PKR: OTIS 'WD' B A2 A1 @ 7832' 9-7-88i 7": 26# J-55 @8220' APl #: 5010320092 REVISION: 06/2/88 SS&V' Camco ~DP.1A 2.813' ID @ 1788' Camoo GLMs GLMI: 2874' / 1.0' GLM2: 5310' / 1.0' GLM3: 8753' I 1.0' GLM4: 7279' I 1.0' Gl.MS: 7821' / 1.5' 7758' 7763' 7768' 7798' GLM6: 7710' I 1.0' 10 SPF 3.5" 9.2# J-55 BTC ABMOD TO 7841' X-OVER TO 2.7/8 6.5# J-55 @ 7841' CAMCO 'D' NIPPLE 2.25' ID @ 7849' TUBING TAIL @ 7859' 7954' 4 SPF 7974' HOLE ANGLE ACROSS KUPARUK = 42° TAGGED FILL AT 7970' (4' PERFS COVERED) PBTD: 8106' ATTACHMENT 2 ,Well 3H,-14 Annular Communication History Problem: SUSPECTED TUBING X 7" COMMUNICATION 7"X 9 5/8" COMMUNICATION (subsequently eliminated after reviewing pressure history) Well History: DRILLED 12/87 - Tested lower tree (7") to 3000# - No note of packoff test or Iockdown screw torque ARCTIC PACKED 7" x 9-5/8" annulus 2/26/88. Pressure tested pack 2/28/88 to 1000# - Pressure bled off to 920# in 1 hour - OK. Left 200# on annulus. COMPLETED 5/88 - 3-1/2" selective single completion - Sheared PBR - Tested tubing to 2500# for 15 minutes - Tested 3-1/2" x 7" annulus to 2500# for 15 min. - Tested 5000# McEvoy tree and tubing x 7" packoff to 5000# - Left diesel in 3-1/2" x 7" annulus - Initial wireline work replaced CV in 1.5" bottom mandrel with DV 5/27/88 - No mention of any problems pulling/running valves on WSR. Tested DV to 1000 psi. Remaining mandrels loaded with dummy valves. 5-28-88: MIT on 3-1/2" x 7" annulus to 2500#. Lost 60# in 30 minutes - good test. 5-29-88: A Sand musol wash 6-11-88: C Sand musol wash 7-9-88: Frac'd A sand - BJ Titan. Screened out w/ max surface pressure of approx. 7100# (per BJ plot). Tubing x 7" annulus initially pressured to 2500# at start of frac and increased to approx. 3200# @ screen out (per BJ plot). Prefrac (7/8/88) tubing pressure tested to 3000# - no mention of 7" response. 9-5-88 : Did CTU cleanout with nitrogen. 9-14-88: Ran PBU with ameradas. Communication Problem History: 6/8 8 Observed 7" going on vacuum. 8/1 2/8 8: Tba fluid level for leak detection -- - Shut in well for 24 hours. SITP = 1150 psi. Tbg fluid level approx. 2331'; 7" csg fluid level near surface (0# CP) -- Pressure gradients do not intersect. Data is NOT DEFINITIVE FOR LEAK DETECTION. 8/26/88: Csa fluid level for leak detecti0rl - Tbg fluid level ?; 7" csg fluid level could not be determined since csg was on a vacuum -- NOT DEFINITIVE FOR LEAK DETECTION 1 0/1/88' J.nstalled 8 pen Barton recorder on 7" & 10" casings. Pressure UB 7". - FTP=162#; 7"=vacuum; 10"=300# - Pressures are approximate due to using wrong type of circular chart - 1300 hrs: Pumped up 7" from vacuum to 500# with unheated diesel. 7" pressure bled back to vacuum within 90 minutes. During this time, 10" increased approx. 100# and fell back to original 300# when 7" re-attained vacuum. 1 0/3/8 8: Pressure uB 7". - FTP=?; 7"=vacuum; 10"=250# - Pressures are approximate due to using wrong type of circular chart. - 1200 hrs: Pumped up 7" from vacuum to 1000# with unheated diesel. 7" pressure beld back to vacuum with 45 minutes. During this time, 10" increased approx. 200# and fell back to original 250# when 7" re-attained vacuum. 1 0/4/8 8' SI tbg & displace W/diesel. Pressure up 7". - Pressures are approximate due to using wrong type of circular chart. - 0900 hrs: Shut-in tubing at choke (in order to monitor SITP w/KDGS) and displaced with 70 bbl diesel. SITP after pumping diesel=500#. - 1300 hrs' Pumped 3 bbl diesel down 7" to pressure up from vacuum to approx. 1000#. 10" increased from 275# to just over 500#. 7" fell to 500# in 6 hrs and 10" fell to 275# in 5 hrs. 10/5/88' 10" pressure test - Wanted to pressure 10" higher than 7" and monitor 7" response. pumped up both 7" and 10" by mistake to 1000 psi. Pressure truck ADBliCation for Sundry Notice . . - Erin filed written application notifying AOGCC of suspected tbg x 7" and possible 7" x 10" communication and requesting approval to continue to produce well in order to perform diagnostics. Application was hand carried to AOGCC and verbally approved 10/6. Consider Dossible tOD Backer leak . - Per Erin, C sand SBHP approx. 2800-3000 psig at approx 5960' TVD. If top packer was leaking and 7" was full of diesel, 7" should have 900-1100# surface pressure and not go on vacuum. If the 7" pressure was 0# and the top packer was leaking, the C sand pressure would have to be approx. 2100 psig. which seems unreasonably Iow. co,c us,o,: 1 0 / 6 / 8 8' Casino oressure histo,rv review - 7" has ha(J ~istory of bein~l on vacuum since 6/4/88, approx 1,J,~:~eJ~ ''~'~ft~'~'"c~initial wireline work was done in which 1 5" CV was replaced with DV list this date). DV may not be seated all the way but enough to'1~t~'"t11~'"~h~)~g-~/28/88. 10" does not track 7" beyond what's normal from 7" thermal/mechanical expansion. When pressured to 1000 psi, 10" retains pressure. CONCLUSION: NO 7" X 9 5/8" PRESSURE COMMUNICATION IS EVIDENT. RECOMMENDED ACTION: PULL 1.5" DV IN BOTTOM MANDREL AND INSPECT PACKING FOR DAMAGE. REDRESS AND RERUN DV. REPEAT 7" PRESSURE TEST. Installed new 0-1500# pressure gauges on 7" and 10" - Pressures on gauges and recorder do not exactly agree. Production personnel will note gauge pressures on chart when pressures are checked or manually changed. Pulled/redressed/reran 1.5" DV in bottom mandrel - No problems pulling or rerunning DV. No severe packing damage seen on pulled DV. 1 0/7/88- Tubin(] fluid level - A sand SBHP estimate -- - Tubing fluid level (diesel) at surface with 470# SITP. 2660# Estimate A sand SBHP = RECOMMENDED ACTION: INJECT GAS LIFT GAS AT A MINIMUM RATE INTO 7" AND MONITOR FLUID LEVEL WITH ECHOMETER. DETERMINE DEPTH OF TUBING LEAK WHERE FLUID LEVEL STOPS. 10/8/88' Brought well back on production ¢ approx. 0700 hrs 1 0/9/8 8' Check hydraulics for ability to detect tubing leak w/gas lift gas - Casing pressure is higher than tubing pressure at the depth of the top packer. There is sufficient casing pressure to locate a tubing leak as deep as the top packer. 10/15/88 Locate leak in tUbing using casino fluid level Put 7" on gas lift. After 24 hours shot casing fluid level. P casing = 1200 psi. Fluid level around 1800'. Increased casing pressure to 1350 psi. After another 24 hours, shot fluid level at the same depth. CONCLUSION: TUBING X 7" STILL HAS PRESSURE COMMUNICATION. LEAK APPEARS TO BE AT THE SSSV (or the first reflection of the SSSV: Fluid level is ambiguous). 1 0 / 1 8 / 8 8 Procedure submitted to Field for Noise/Temp. Lo0. A logging package was sent to the Slope outlining the proposed leak detection logs. 1 2/1 0/88 Noise/Temp Log. R~jn With slickline, a tubing plug was set in the D nipple at 7849' MD to prevent production up the tubing during the leak detection logging. Gas lift pressure was applied to the tubing x 7" annulus to pass gas through the leak. Both the noise and temp logs (attached) indicate a tubing leak at 1806' (base of 4' pup joint below the SSSV). No other tubing leaks were observed. This leak location was verified by a casing liquid level measurement. The tubing plug was removed from the well and the well returned to production. CONCLUSION: THE SOURCE OF THE 7" X 9 5/8" COMMUNICATION IS A SMALL TUBING LEAK AT 1806' MD, THE BASE OF THE PUP JOINT DIRECTLY BELOW THE SSSV. EMO 12/23/88 00~; O~13Z 'lOOJ. Oi il, IZOd '~lnS~:aw aOSI,13S 00000~ ( /~W) o0000~: ( ^W) 00000~ ( ^W) 00000~ 000'0~ HIM 000'0~ R'~-~ ........................ 000'0~ < A--"~") HD, M 000'0~ H~M O00'Ot~ O00'O& HgM 06:~',,'~ dO ! - -- ! I , - I KUPARUK STIMULATION SUMMARY ~/~-/~/ WELL: TUD ~) PERFS: MD ~) PERFS: HOLE ANGLE ~-PEflFS: SAND , pERF INTERVAL · 77.~ - '77 COMPANY ~o~ ACTUAL VOLUME RATE PRESSURE EFF. PAD: ~51 uu'~ EFF. SLURRY: ~?.oo ~,~oo TYPE DENS lTV -'- c" ~ , .%'" ,~ P 4s. eF · 71 "N D u M-,-a p~.a PROP. PROP. /~-zo /~ -Zo /~,'Zo ii ii i ii i PHASING /~ DESIGN ANN. VOLUME PRESS. STG/£UM ii ii i i WHTPR: %~8o / ~ FRRC 6RAO: ,-',lqq / ,,~/ ISIP: ,'b.qto /,,~ TBG.FRIC: I/I'D PERF FRIC: Z~ / LOG INTERVAL: FLUID TEMP: FLUID VlSC: LERKOFF: 5MIN.,,~ IOMIN. ~- IS MIN. NOTES:~ ~ \o ~?~ r~so ARCO Alaska, Inc. Date: December 15, 1988 Transmittal #: 7375 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. J 3 H - 1 4 Kuparuk Fluid Level Report 1 2- 1 0 - 8 8 Casing ~ 3 H- 1 5 Kuparuk Fluid Level Report 1 2- 0 9 - 8 8 Tubing · 3 H - 1 7 Kuparuk Fluid Level Report 1 2 - 0 9 - 8 8 Casing · 3 M - 1 9 Kuparuk Fluid Level Report I 2- 0 9 - 8 8 Casing · 3 H - 0 6 Kuparuk Fluid Level Report 1 2- 0 8,8 8 Tubing · 3 H - 0 9 Kuparuk Fluid Level Report 1 2 - 1 3 - 8 8 Casing ~ 3 H - 21 Kuparuk Fluid Level Report 1 2 - 1 3 - 8 8 Casing · 3 K - 0 6 Kupaurk Fluid Level Report 1 2 - 1 2 - 8 8 Casing ~' 3 H - 21 Kuparuk Fluid Level Report I 2 - 1 2 - 8 8 Casing · 1 Y- 0 6 Kuparuk Fluid Level Report 1 2- 1 2 - 8 8 Casing · 30-07 BHP Report I I-27-88 Receipt Acknowledged: Alaska 0il & Cas Conr~. Commission A~]cho~age ........................... Date: ............ DISTRIBUTION: State of Alaska D&M Unocal SAPC Chevron Mobil '~' ~' ;"-~ ·STATE OFALASKA ~ 0 RI G IN A ' ALASKA OIL AND GAS CONSERVATION COMMISSION ~'~ ,~v-~ WELL COMPLETION OR RECOMPLETION REPORT AND LO 1. Status of Well Classification of Service Well OIL~] GAS [] SUSPENDED [] ABANDONED F-] SERVICE [] ~2. Name of OPerator 7. Permit Number ARCO Alaska, Inc. 87-3,~,~ 3. Address 8. APl Number P, 0. Box 100360, Anchorage, AK 99510 50- 103.-20092 4. Location of well at surface 9. Unit or Lease Name 1157' FNL, 281' FWL, Sec.12, T12N, R8E, UN Kuparuk River Unit:. At Top Produc ng Interval 10. Well Number 1684' FSL, 1777' FEL, Sec. 1, T12N, R8E, UN 3H-14 At Total Depth 11. Field and Pool 1940' .....FSL, 1564' FEL, Sec.1, T12N, RSE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River Oi 1 Pool 76' RKB [ ADL 25531 ALK 2657 12. Date Spudded12,07,87 13. Date T.D. Reached12,1 2,87 14' Date C°mp" Susp' °r Aband' 115' Water Depth' if °ffsh°re 116' N°" °f C°mpleti°ns07/09/88, N/A feet MSL .1 .. 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafr~'st 8250'MD/6374'TVD 8129'MD/6283'TVD YES"~] NO [] 1788' feet MD ] 1600' (aDorox) 22. Type Ele(~tric or Other Logs Run ' ' DIL/GR/SP/SFL, FDC/CNL, CAL, GE, GCT, CET 23. CASING, LINER AND cEMENTING RECORD I SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED ~,,. ~ c'~ -..- ..-~ ~ H .... i' 115: -,~, .,u, 24;: ZUU SX Ab I c~_~/~,,_ -. - ~c~v...,,n~ ..-' 55 .~Lii-f 3&,56: i2-i/,~'"'" i33U SX /%b III & ~UU S~ Class G 7', --.-.')c n~ .-' 55 .~Ui-f 8220: 8-1/2;: 800 SX Class ci & 175 l~x A5 I 24. Perforations open' to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET {MD) pACKER SET (MD) Perforated w/lO spf, 120° phasing 3-i/2" ~859" 7674' & 7832' 7758 ' -7763' MD/6018 ' -6022 ' TVD 7768' -7798' MD/6025 ' -6046'TVD 26. ACID, FRACTURE, CEM'ENT SQUEEZE, ETc. Perforated ~/12 spf, 60° phasing DEP~'_H_IN,'j'.ERV. AL' (~M.D) .AMO. UNT_& KIND oF MATERIAl. USED d~:~::~ CIt.~.CIUII~U Ob llllJlal;lOn oummary 7881 '-7901 'MD/6102'-6116'TVD ddted 7/9/66 for 'racture data'. 7916 ' -7928 ' MD/6127 ' -6135 ' TVD Perforated w/4 spf, 135° phasing 7Q~./, ' -'TQ-/I, IMF~ I~:'! I:;I, I _~_,1 ~O ...... , · ,,~. v,..,~ i.,,l,~..., aVl..,, 27. · PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) ?=, N/A Date of Test Hours Tested PRODUCTION FOR OI L"-BBL GA'S-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCLJLA~TED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (cor'r) Press. 24-HOUR RATE I~ 28. CORE DATA . . ; :~ ~ .,,. .... Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ~; ~ None · NOTE: Drilled RR 12/14/87. Perforated well and ran tubing 5/17/88. Fractured weli ~[,: ~:'O[~q~' C3m~.~;o.....~._.., 7/9/88. Added perforations 10/30/88. Form 10-407 WC5/046 Submit in duplicate Rev. 7-1-BO CONTINUED ON REVERSE SIDE 29. ,, 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 7767' 6024' N/A Base Kuparuk C 7793' 6042' Top Kuparuk A 7866' 6092' Base Kuparuk A 8027' 6207' 31 LIST OF AT. TACHMENTS 'A-d~en~lum (dated 11/17/88) & Stimulation Summary (dated 7/9/88) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed '~~~~y Title^r'ea DrY'ling Fng'neer' Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas' injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in'item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain.. Item 28: If no cores taken, indicate "none". ADDENDUM 5129/88 6/11/88 7~9/88 9/05/88 10/30/88 3H-14 RU GSL. Pmp 20 bbls diesel + 5% Musol. Displ w/71 bbls diesel to top perf @ 7954'. SI well & RD. RU WL, RIH w/2.25" std'g vlv, set in D Nipple @ 7849'. Pmp 30 bbls diesel + 5% Musol Displ diesel/Musol w/65 bbls @ 1.5 BPM, 2300 psi. POOH w/std'g vlv. RD Otis. Attempt to frac Kuparuk A Sand perfs 7954' - 7974'in 10 stages per procedure dated 6/22/88. Sanded out w/half of 6# stage in formation. Screened out. Fluid to recover: Sand in zone: 5800# Sand in csg/tbg: 16,200# RU CTU. Pressure tbg to 4000 psi. GIH to 7000'. Break circ, 1.5 BPM gelled diesel, 350 scf/min Ng, 4200 psi. Wsh f/7859'-8106' KB. CBU two times while'reciprocating pipe f/PBTD to TT. Switch to cln diesel, POOH, displ w/cln diesel. RD Fracmaster. Turn well over to Production. RU Schl, tst lubr to 2500 psi. Perf 7916'-7928' @ 7881'-7901' @ 12 SPF, 60* phasing. Release well to Production. Drilling Supervisor Date SUB'SURFACE DIRECTIONAL SURVEY [~UIDANCE r~ONTINUOUS r'~OOL Company ARC,,,O ALASKA~ INC. Well Name 3H-14 (1157' FNL` 281' FWL, ,SEC 12~ T12N~ R8E,,,,,UM) Field/Location.,, KUPARU, K,,,, NORTH SLOPE,, ALASKA Job Referenc,,e No. Date 72608 18-FEB-88 Loaaed By: Computed By: SARBER KOHRING iSV3 NIH Z£ 9~0 B~ HI,ON ~0 HIRWIZV 1~9B¥1 V O/NO 02£3~£0Ud '1510 'ZIBOH :NOI£3~$ ]VOlI~A B~NI9 =NOIIV90dU~IN! HIR~IZV ONV NOIZVIABO O~5V~AV -gVlIN2ONV/ :N011¥309 9001 NOIIVIRdWO~ ~C ~OOHI]N BB-83~-B! :31V0 ~N~VdN~ ~[-H£ '3NI ~V~VgV ONIlgI9 ~NOISN3 A~ASN$ IVNOlI3~)IO 130 ARCO ALASKA~ INC. 3H-14 , KUPARUK NORTH SLOPE,ALASKA COMPU'TATION DATE: OZ-MAR-88 PAGE 1 DAT~ OF SURVEY: 18-FE8-88 KELLY BUSHING ELEVATION: 76.00 FT ENGINEER: SARBER · INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COUR~ MEASURED VERTICAL VERTICAL DEVIATION I"UTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0.00 0.00 -76.00 0 0 N 0 0 E 100.00 100.00 24.00 0 13 S 3 30 W 200.00 200.00 124.00 0 13 S 12 6 5 300.00 300.00 224.00 0 11 S 23 31 E 400.00 400.00 324.00 0 20 S 39 11 E 500.00 499.99 423.99 0 23 S 49 14 E 600.00 599.99 523.99 0 28 S 66 11 E 700.00 699.99 623.99 0 33 S 74 49 E 800.00 799.98 723.98 0 37 S 75 53 E 900.00 899.98 823.98 0 36 S 71 55 E 0 44 0 48 2 2 1000.00 999.97 923.97 1100.00 1099.96 1023.96 1200.00 1199.93 1123.93 1300.00 1299.64 1223.54 6 13 1400.00 1398.55 1322.55 10 1 1500.00 1496,44 1420.44 13 47 1600.00 1592.62 1516.62 17 42 1700.00 1687.12 1611.12 20 36 1800.00 1779.15 1703.15 25 32 1900.00 1867.54 1791.54 30 19 2000.00 1951.83 1875.83 34 11 ZlO0.O0 2033.40 1957.40 36 53 2200.00 2111.25 2035.25 40 2300.00 2185.78 2109.78 42 52 2400.00 2258.50 2182.50 63 32 2500.00 2330.91 2254.91 44 3 2600.00 2402.18 2326.18 2700.00 2473.00 2397.00 44 57 2800.00 2543.52 2467.52 65 23 2900.00 2613.38 2537.38 45 52 3000.00 2683.05 2607.05 45 54 3100.00 2752.45 3200.00 3300.00 3400.00 3500.00 3600.00 3700.00 3800.00 3900.00 [676.45 46 2821.77 .d~rf45.,7 46 2891.25 a!112815.25 45 46 2961 · 48..~ 2 ~J85.48 28.49 21 ~317 ~ 44 33 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH F6ET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 0.00 N 0.00 E -0.25 0.00 0.36 S 0.03 W -O.6g 0.04 0.74 S 0.01 -0.63 0.13 1.08 S 0.11 -0.69 0.00 1.47 S 0.37 E -0.66 0.00 1.92 S 0.81 -0.45 0.04 2.32 S 1.46 0.00 0.14 2.60 S 2.29 E 0.60 0.13 2.85 S 3.30 E 1.19 0.00 3.15 S 4.35 E S 84 33 E 1.89 0.00 S 83 42 E 2.81 0.16 N 81 33 E 4.27 3.80 N 69 0 E 11.03 3.92 N 65 53 E 24.90 2.73 N 65 27 E 44.34 4.50 N 63 0 E 70.62 3.32 N 59 28 E 102.52 3.94 N 60 36 5 140.84 5.02 N 61 20 E 186.33 5.37 N 59 37 E 238.98 N 58 53 E 295.74 N 55 24 E 357.81 N 51 44 E 424.20 N 51 6 E 492.79 N 49 6 E 561.72 N ~9 35 E 631.86 N 49 38 E 702.65 N 49 37 E 773.34 N 49 59 E 844.88 N 'SO 32 E 916.58 N 50 40 =_ 988.54 N 51 39 E 1060.55 N 53 6 5 1132.32 N 54 45 E 1203.19 N 56 18 E 1272.71 N 56 20 E 1341.84 N 56 23 E 1411.13 N 56 34 E 1480.58 N 56 48 E 1550.17 1.50 4.92 3.45 2.84 1.60 1.57 0 0.35 0.79 0.45 0.51 0.29 1'.03 1.21 1 0.52 0.20 0.45 0.34 0.52 0.00 N 0 0 E 0.36 S 4 4 W 0.74 S 0 33 E 1.09 S 5 54 E 1.52 S 14 15 E 2.09 S 22 53 E 2.73 S 31 51 E '~ 3.46 S 41 17 E ,~ 4.36 S 49 15 E 5.37 S 54 7 E 3.36 S 5.48 E 6.43 S 58 31 E 3.51 S 6.83 E 7.68 S 62 49 E 3.53 S 8.80 E 9.48 S 68 7 E 1.29 S 15.83 E 15.89 S 85 20 E 4.51 N 29.22 E 29.56 N 81 13 E 12.90 N 47.73 ~ 49.44 N 74 52 E 24.71 N 72'35 E 76.46 N 71 8 E 40.46 N 100.98 E 108.79 N 68 10 E 60.28 N 134.59 E 147.47 N 65 52 5 82.48 N 175.67 E 194.06 N 64 50 E 109.13 N 222.36 E 247.70 N 63 51 E 138.31 N 272.28 E ' 305.40 N 63 4 E 172.54 N 324.85 E 367.83 N 62 I E 212.16 N 378.43 E 433.85 N 60 43 E 255.32 N 431.81 E 501.65 N 59 24 E 299.65 N 484.63 E 569.79 N 58 16 E 345.32 N 537.87 E 639.18 N 57 17 E 391.04 N 591.67 E 709.22 N 56 32 E 436.99 N 645.67 E 779.64 N 55 54 E 483.17 N 700.32 6 850.82 N 55 23 E 529.01 N 755.43 E 922.29 N 54 59 E 574.72 N 811.12 E 994.09 N 54 40 E 620.00 N 867.20 E 1066.04 N 54 26 E 663.90 N 924.17 E 1137.92 N 54 18 E 705.83 N 981.69 E 1209.10 N 54 17 E 745.37 N 1039.50 E 1279.12 N 54 21 E 784.05 N 1097.56 E 1348.84 N 54 27 E 822.78 N 1155.78 E 1418.73 N 56 33 E 861.50 N 1214.23 E 1488.80 N 54 38 E 900.10 N 1272.96 E 1559.04 N 54 44 E ARCO ALA. SKA, INC. 3H-14 KUPARUK NORTH SLOPE ,ALASKA COMPUTATION DATE: 02-MAR-88 PAGE 2 DATE OF SURVEY: 18-FEB-88 KELLY BUSHING ELEVATION: 75.00 FT ENGINEER: SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF NEASURED DEPTH TRUE SUB-SE, COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET OEG/IO0 FEET FEET FEET DEG MIN 4000.00 3389.78 3313.78 44 30 4100.00 3461.10 3385.10 44 29 4200.00 3532.37 3456.37 44 37 4300.00 3603.40 3527.40 44 48 4400.00 3674.40 3598.40 44 42 4500.00 3745.45 3669.45 44 46 4600.00 3816.37 3740.37 44 50 4700.00 3887.27 3811.27 44 51 4800.00 3958.20 3882.20 44 42 4900.00 4029.51 39513.51 44 15 5000.00 4101.34 4025.34 43 54 5100.00 4173.44 4097.44 43 38 5200.00 4245.94 4169.94 43 18 5300.00 4318.95 4242.95 43 2 5400.00 4391.62 4315.62 43 59 5500.00 4462.67 4386.67 45 6 5600.00 ¢533.52 4457.52 44 38 5700.00 4604.70 4528.70 44 32 5800.00 4675.97 4599.97 44 32 5900.00 4747.25 4671.?.5 .44 22 6000.00 4818.77' 4742.77 44 24 6100.00 4890.11 4814.11 44 24 6200.00 4961.44 4885.44 44 35 6300.00 5032.39 4956.39 45 2 6400.00 5101.79 5025.79 47 8 6500.00 5169.32 5093.32 47 44 6600.00 5236.74 5160.74 47 26 6700.00 5304.43 5228.43 47 21 6800.00 537?..08 5294.08 47 33 6900.00 5439.53 5363.53 47 36 7000.00 5506.97 5430.97 47 36 7100.00 5574.27 5498.27 47 45 7200.00 5641.60 5565.60 47 37 7300.00 5709.03 5633.03 47 35 7400.00 5776.63 5700.63 47 19 7500.00 5844.37 5768.37 47 21 7600.00 5912.02 5836.02 47 34 7700.00 5979.42 5903.42 47 34 7800.00 6066.59 5970.59 47 42 7900.00 6115.49 6039.49 45 19 N 54 5 E 161'9.64 N 51 4 ~ 1689.60 N 50 57 E 1759.69 N 50 50 E 1830.02 N 50 46 E 1900.39 N 50 42 F, 1970.71 N 50 39 E 2041.16 N 50 39 E 2111.64 N 50 34 E 2182.08 N 50 17 E 27.52.15 N 50 4 E 2321.70 N 50 0 E 2390.97 N 49 56 E 2459.84 N 49 49 E 7.528.14 N 47 40 E 2596.82 N 45 6 E 2667.11 N 45 3 E 2737.55 N 44 57 E 2807.65 N 44 41 E 2377.64 fl 44 11 E 2947.59 N 43 52 E 3017.26 N 43 23 E 3087.07 N 43 Z E 3156.85 N 42 37 E 3226.97 N 41 12 E 37.98.47 N 40 32 E 3371.53 N 40 8 E 3446.62 N 39 47 E 3517.39 N 39 31 E 3590.14 N 39 24 E 3663.03 N 39 30 E 3735.91 N 39 31 E 3808.95 N 39 38 E 3881.97 N 39 45 E 3954.92 N 39 50 E 4027.74 N 39 50 E 4100.43 N 39 55 E 4173.22 N 39 47 E 4Z46.24 N 39 2.3 E 4319.41 N 39 40 E 4390.96 3.68 0.31 0.12 0.15 0.34 0.63 0.40 0.34 0.69 0.38 0.34 0.61 0.81 0.41 3.76 0.34 0.72 0.53 0.27 0.68 0.38 0.67 0.77 1.13 2.05 0.46 0.54 0.46 0.34 0.02 0.19 0.26 0.00 0.34 0.30 0.26 0.40 0.78 1.91 1.80 939-33 N 1331.00 E 1629.08 N 54 47 E 982.34 N 1386.34 E 1699.09 N 54 40 E 1026-46 N 1440.87 E 1769.10 N 54 32 E 1070.85 N 1495.49 E 1839.35 N 54 23 E 1115.34 N 1550.08 E 1909.64 N 54 15 E 11 59.90 N 1604.54 E 1979.8'8 N 54 8 E 1204.56 N 1659.09 E 2050.26 N 54 l 1249.24 N 1713.66 E 2120.67 N 53 54 E 1293.96 N 1768.14 E 2191.04 N S3 48 E 13.38.56 N 1822.23 E 2261.03 N 53 1383.13 N 1875.66 E 2330.48 N 53 35 E 1427.64 N 1928.77 E 2399.64 N 53 29 E 1471.94 N 1981.51 E 2468.40 N 53 23' E 1515.94 N 2033.77 E ?.536.59 N 53 17 E 1560.92 N 2085.69 E 2605.10 N 53 11 E 1609.80 N 2136.30 E 2674.93 N 53 0 E 1659.62 N 21'36.2@ E 2744.85 N 52 47 E 1709.29 N 2235.94 E 2814.45 N 52 36 E 1759.02 N 2285.41 E 2883.97 N 52 24 E 1809.09 N 2334.53 E 2953.44 N 52 13 E 1859.36 N 2383.09 E 3022.64 N 52 2 1910.02 N 2431.49 E '3091.98 N 51 50 E 1961.09 N 2479.51 E 3161.30 N 51 39 E 2012.72 N 2527.47 E 3230.97 N 51 28 E 2066.25 N 2575.59 E 3301.98 N 51 15 E 2122.09 N 2623.77 E 3374.53 N 51 2 E 2178.37 N 2671.59 E 3467.13 N 50 48 E 2234.80 N 2718.86 E 3519.45 N 50 34 E 2291.50 N 2765.86 E 3591.79 N 50 Zt E 2348.51 N 2812.78 E 366~+.32 N 50 8 E 2405.50 N 2859.70 E 3736.89 N 49 55 E 2462.56 N 2906.78 E 3809.66 N 49 43 E 2519.54 N 2953.90 E 3882.47 N 49 32 E 2576.36 N 3001.06 E 3955.24 N 49 21 E 2632.98 N 3048.21 E 4027.93 N 49 10 E 2689.46 N 3095.34 E 4100.53 N 49 0 E 2745.98 N 3142.56 E 4173.26 N 48 51 E 2802.64 N 3189.96 E 4246.25 N 4'3 41 E 2859.73 N 3237.17 E 4319.41 N 48 32 E 2915.62 N 3283.29 E 4391.00 N 48 23 E ~ 8 89 N *[E'9Z59 ~ O8'OLEE N 8L'OZO£ ~ 5! $9 N S*['0999 ~ E6'LZE£ N Bg'696Z 00'0 00'0 00'0 99'E 6E'gZ99 B Z 09 N 99'1659 ~ Z 09 N ~*['9Z~9 ~ Z 09 N 90'099'9 B 5E 6£ N 8Z *[9 £9'£6Z9 Z9'EZE9 O0'O5ZB BZ *[9 ZZ'O9Z9 ZZ'9EE9 O0'OOZ8 8Z *[9 0E'S8~9 OE'*[9Z9 00'00.[8 0.[ E9 ~6'0~9 56'98~9 00'0008 NIW 9jO NIW 9gO H£d~O H£d~O H£d~O Hi~WIZU NOIiVIA]O 1VOII~]A 1~311~3A ~S~N03 ~gS-~NS Hld30 03BASV~W ~0 l~J 00.[ N~Ag 80~ S]AIVA O~IVIOd)BINI U29UVS :~3~NIgN3 lJ O0'9L :NOIZUA~93 9NIHSnB A993) BB-g~-B! :A~ABNS ~0 g£VO E ~OVd 88-~VW-ZO :gI90 NGIIVIR~W03 V~IS1/'IV*3dO*IS HI'iON ~naVdn~l 9*[ -HE '3NI *V)SV~V 038V ARCO ALASKA, INC. 3H-14 KUPARUK NORTH SLOPE,ALASKA COMPUTATION DATE: 02-MAR-88 PAGE DATE OF SURVEY: 18-FEB-88 KELLY BUSHING ELEVATION: 76.00 FT ENGINEER: SARBER INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN' DEG MIN 0o00 0.00 -76.00 0 0 1000.00 999.97 923.97 :0 44 ZO00oO0 1951.83 1875.83 34 11 3000.00. Z683.05 2607.05 45 54 4000.00 3389.78 3313.78 44 30 5000.00 4101.34 4025.34 43 54 6000.00 4818.77 4742.77 44 24 7000.00 5506.97 5430.97 47 36 8000.00 6186.95 6110.95 43 10 8250.00 6373.67 6297.67 41 28 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN N 0 0 E 0.00 S 84 33 E 1.89 N 59 37 E 238.98 N 50 3Z E 916.58 N 54 5 E 1619.64 N 50 4 E 2321.70 N 43 52 E 3017.26 N 39 30 E 3735.91 N 39 35 E 4460.06 N 40 2 E 4624.39 0.00 0.00 1.50 0.51 3.68 0.34 0.38 0.19 3.44 0.00 0.00 N 0.00 E 0.00 N 0 0 E 3.36 S 5.48 E 6.43 S 58 31 E 109.13 N Z~-2.36 E 247.70 N 63 51 E 529.01 N 755.49 E 922.29 N 54 59 E 939.33 N 1331.00 E 1629.08 N 54 47 E 1383.13 N 1875.66 E 2330.48 N 53 35 E 1859.36 N 2383.09 E 3022.6'4 N 52 2 E 2405.50 N 2859.70 E 3736.89 N 49 55 E 2969.48 N 3327.93 E 4460.15 N 48 15 E 3096.86 N 3434.71 E 4624.69 N 47 57 E -) ARCO ALASKA, INC. 3H-14 KUPARUK NORTH SLOPE~ALASKA COMPUTATION DATE: 02-MAR-88 PAGE 5 DATE OF .SURVEY= [8-FEB-88 KELLY BUSHING ELEVATION: 76.00 FT ENGINEER= SARBER ' INTERPOLATED VALUES FOR EVEN [00 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG NIN 0.00 0.00 -76.00 0 0 N 0 0 E 76.00 76.00 0.00 0 17 S 4 15 E 176.00 176.00 100.00 0 13 S 10 13 E 276.00 276.00 200.00 0 11 S 19 14 E 376.00 376.00 300.00' 0 18 S 38 0 E 476.01 476.00 400.00 0 22 S 47 15 E 576.0! 576.00 500.00 0 26 S 62 34 E 676.0! 676.00 600.00 0 32 S 73 28 E 776.02 776.00 700.00 0 37 S 76 49 E 876.02 876.00 800.00 0 37 S 71 59 E 976.03 976.00 900.00 0 44 1076.04 1076.00 lO00.O0 0 47 1176.05 1176.00 1100.00 1 21 1276.24 1276.00 1200.00 5 23 1377.12 1376.00 1300.00 9 26 1479. O0 1476.00 1400.00 12 50 1582.59 1576.00 1500.00 17 7 1688.13 1676.00 1600.00 2.0 10 1796.51 1776.00 1700.00 25 22 1909.82 1876.00 1800.00 30 50 2029.31 1976.00 1900.00 34 40 2154.09 2076.00 2000.00 39 5 2286.65 2176.00 2-100.00 42 38 2424.13 2276.00 2200.00 43 27 2563.12 2376.00 2300.00 44 41 2704.25 2476.00 2400.00 44 58 2846.39 2576.00 2500.00 45 41 2989.86 2676.00 2600.00 45 51 3134.00 2776.00 2700.00 46 9 3278.11 ,2876.00 2800.00 45 54. 3420.49 2976.00 2900.00 44 42 '" 3560.19 3076.00 3000.00 44 14 3700.03 3176.00 3100.00 44 26 3840.34 3276.00 3200.00 44 38 3980.70 3376.00 3300.00 44 21 4120.89 3476. O0 3400.00 44 29 4261.39 3576.00 3500.00 44 46 4402.26 3676.00 3600.00 44 41 4543.08 3776.00 3700.00 44 51 4684.11 3876.00 3800.00 44 50 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN S 84 20 E S 82 45 E N 89 9 E N 70 17 E N 65' 49 E N 65 34 E N 63 36 E N 59 49 E N 60 27 E N 61 6 E 0.00 0.00 0.00 N 0.00 E -0.19 0.45 0.25 S 0.03 W -0.44 0.00 0.65 S 0.01 W -0.61 0.00 1.01 S 0.08 E -0.69 0.11 1.37 S 0.29 E -0.68 0.00 1.82 S 0.69 E -0.53 0.18 2.24 S 1.27 E -0-13 0.06 2.54 S 2.07 E 0.45 0.00 2.79 S 3.05 E 1.05 O.OO 3.07 S 4.11 E 1-68 0.04 3.3.3 S 5.17 E 2.59 0.11 3.47 S 6.50 E 3.70 2.26 3.60 S 8.10 E 8.80 3.33 2.12 S 13.59 E 21.20 2'28 2.92 N 25.68 E 39.72 4.54 10.90 N 43.34 E 65.59 3.68 22.37 N 67.70 E 98.42 3.92 139.37 5.27 191.20 5.21 N 59 52 E 255.25 2.10 N 56 44 E 328.63 4.22 N 52 10 E 415.13 3-17 N 50 46 E 509.38 2.11 N 49 28 E 605.88 0.71 N 49 37 E 705.46 0.36 N 49 47 E 806.46 0.61 N 50 30 E 909.30 0.75 N 50 52 E 1013.04 0.60 N 52 47 E 1116.65 1-20 N 55 ~ E 1217.56 N 56 20 E 1314.29 N 56 23 E 1411.14 N 56 40 E 1508.63 N 55 4 E 1606.21 N 51 Z E 1704.23 N 50 53 E 1802.83 N 50 46 E 1901.97 N 50 42 E 2001.06 N 50 40 E 2100.44 0.00 N 0 0 E 0.25 S 6 33 W 0.65 S 0 58 W 1.01 S 4 39 E 1.40 S I1 56 E 1.95 S 20 52 E 2.57 S 29 33 E 3.27 S 39 9 E 4.13 S 47 35 E 5.13 S 53 15 E 6.15 S 57 15 E 7.37 S 61 55 E 8.86 S 66 2 E 13.76 S 81 8 E 25.85 N 83 30 E 44.6B N 75 52 E 71.30 N 71 42 E 38.34 N 97.39 E 104.66 N 68 30 E 59.54 N 133.29 E 145.98 N 65 55 E 84.88 N 180.04 E 199.05 N 64 45 E 117.48 N 236.68 E 264.24 N 63 36 E 156.11 N 300.44 E' 338.58 N 62 32 E 206.52 N 371.31 E 424.88 N 60 55 E 265.80 N 444.69 E 51B.OB N 59 7 E 328.46 N 518.11 E 613.45 N 57 37 E 392.98 N 593.96 E 712.20 N 56 30 E 458.41 N 670.93 E 812.58 N 55 39 E 524.38 N 749.87 E 915.03 N 55 2 [ ~ 590.22 N 830.12 E 1018.56 N 54 35 E 654.43 N 911.64 E 1122.22 N 54 19 E 1.66 0.34 0.45 0.23 3.71 0.39 0.17 0.35 0.19 0.41 714.1~ N 993.51 E 1223.55 N 54 17 E 768.64 N 1074.42 E 1321.05 N 54 25 E 822.79 N 1155.79 E 1418.75 N 54 33 E 877.09 N 1237.88 E 1517.11 N 54 40 E 931.51 N 1319.98 E 1615.5T N 54 47 E 991.54 N 1397.73 E 1713.71 N 54 38 E 1053.68 N 1474.39 E 1812.20 N 54 26 E 1116.35 N 1551.31 E 1911.23 N 54 15 E 1179.13 N 1628.05 E 2010.19 N 54 5 E 1242.14 N 1704.99 E 2109.48 N 53 55 E ARCO ALASKA~. INC. 3 H-14 KUPARUK NORTH SLOPE,ALASKA COMPUTATION DATE: O2-MAR-88 PAGE 6 DATE OF SURVEY: 18-F~8-88 KELLY BUSHING ELEVATION: 76.00 FT ENGINEER: SARSER ' INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG HIN VERTICAL DOGLEG RECTANGULAR COORDINATES HgRIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 4825.02 3976.00 3900.00 44 37 4964.79 4076.00 4000.00 44 3 5103.54 4176.00 4100.00 43 38 5241.23 4276.00 4200.00 43 4 5378.35 4376.00 4300.00 43 37 5518.88 4476.00 4400.00 45 3 5659.70 4576.00 4500.00 44 38 5800.04 4676.00 4600.00 44 32 5940.19 47'76.00 4700.00 44 17 6080.23 4876.00 4800.00 44 27 6220.47 4976.00 4900.00 44 41 6362.34 5076.00 5000.00 46 19 6509.93 5176.00 5100.00 47 45 6658.01 5276.00 5200.00 47 2.4 6805.82 5376.00 5300. O0 47 33 6954.08 5476.00 5400.00 47 33 7102.57 5576.00 5500.00 47 45 7251.03 5676.00 5600.00 47 34 7399..07 5776.00 5700.00 47 19 7546.70 5876.00 5800.00 47 23 7694.93 5976.00 5900.00 47 34 7843.23 6076.00 6000.00 46 35 7984.91 6176.00 6100.00 43 37 8250.00 6373.67 6297.67 41 28 N 50 33 E 2199.66 N 50 7 E 229'7.26 N 50 0 E 2393.42 N 49 54 E 2488.04 N 48 31 E 2581.84 N 45 4 E 2680.46 N 44 58 E 2779.41 N 44 41 E 2877.68 N 44 1 E 2975.59 N 43 32 E 3073.28 N 43 0 E 3171.18 N 41 48 E 3271.24 N 40 30 E 3378.81 N 39 55 E 3486.85 N 39 30 E 3594.38 N 39 23 E 3702.,44 N 39 31 E 3810.83 N 39 41 E 3919.20 N 39 50 E 4027.06 N 39 51 E 4134.39 N 39 48 E 4242.54 N 39 29 E 4350.69 N 39 35 E 4449.80 N 40 2 E 4624.39 0.25 0.65 0.57 0.37 3.03 0.54 0.30 0.27 0.36 1.04 0.41 2.85 0.44 0.31 0.32 0.04 0.29 0.3O 0.29 0.50 0.79 2.84 3.42 0.00 1305.13 N 1781.73 E 2208.60 N 5'3 46 E 1367.44 N 1856.91 E 2306.08 N 53 37 E 1429.21 N 19130.64 E 2402.08 N 53 29 E 1490.10 N 2003.10 E 2496.56 N 53 21 E 1550.91 N 20?4.53 E 2590.18 N 53 13 E 1619.24 N 2145.77 E 2688.17 N 52 57 E 1689.27 N 2215.95 E 2786.41 N 52 40 E '"~ 1759.05 N 2285.44 E 2884.00 N 52 24 E 1829.25 N 2354.08 E 2981.25 N 52 9 E 1899.97 N 242&.96 E 3078.28 N 51 53 E 1971.61 N 2489.32 E .3175.53 N 51 37 E 2045.69 N 2557.41 E 3274.94 N 51 20 E 2127.68 N 2628.54 E 3381.76 N 51 0 E 2211.08 N 2699.05 E 3489.09 N 59 ~0 E 2294.81 N 2768.59 E 3596.01 N 50 20 E 2379.34 N 2838.15 E 3703.55 N 50 1 E 2464.03 N 2907.99 E 3811.54 N 49 43 E 2548-55 N 2977.95 E 3919.60 N 49 26 E 2632.46 N 3047.7'7 E 4027.25 N 49 10 E 2715.83 N 3117.36 E 4134.45 N 43 56 E 2799.77 N 3187.56 E 4242.55 N 48 42 E 2884.19 N 3257.30 E'4350.70 N 48 28 E 2961.48 N 3321.31 E 4449.88 N 4~ 16 E 3096.86 N 3434.71 E ~624.69 N 47 57 E 98*'960£ ,L9 °Z. 6Z9 zg*E2..£9 6'z*~£0£ ZO*LOZ'9 ZO*ESZ9 06'9682 ~i'~t09 ~i'Z609 9Z'SSBZ 88'S96S 88'I909 9B'09BZ S9'896~ ~'9Z09 Wfl '~B~ *NZtX 'ZI 3~S ~9M~ lB~ 'IN~ LSX! =NI~I~O N0119009 g~ 00'0528 O0 '6ZIB O0 'L~'OB 00'998£ O0 'E6L£ DO' Z. 9Z.Z SNOZI~OH N~SOH3 ~0~ s2ngUA 031VgDdB2£NI 1~ O0'gL :NDIIVA~I~ ONIHS~B All~) BB-~-SI :A2A8~S ~0 ~lVO OL V ~nUVdflX dOl 3 ~n~vdn~ dO1 ~n~Vdn~ 9T-HE BB-~VW-ZO :~lVO NOIlVlfldWO3 ~ Z.g L9 N NI~ 9~0 ~l~Nl~Vd~O 69'9Z99 3~NVISIO 1VINCZI~DH Z9'L6Z9 Z~*£ZE9 O0'O~Z8 Hld~ Hld~G Hld]O :Ol lV NOIIVOGI ll~ I~NI~ wn 3 Ii'9£9£ N 9~'g60£ ~ 9I'£8££ N 3 99'6EE£ N Ig'~B6Z ] 6l'i9Z£ N 3 88'££Z£ N 3 09'TZZ£ N 98'098~ IS3~/ISV~ HlflOS/HIBON NOIIV309 33V~flS Id O0'9L BB-g~J-8! B 3~Vd :~33NIgN3 :~OI£~A~ ~NIH$~ Z9'L6Z9 zg'ELE9 ZO'£OZ9 ZO*EBZ9 5L'OE~9 5£'90Z9 ZL'SI09 ZZ'~609 BB'5965 B8'1909 *lNJ iSII =NIgIBO BB-~VW-ZO O0'O5~B O0'6ZIB O0'LZOB 00'99Bi 00'£6Z£ O0'lgZZ Ol~d V ~N~Vdfl~ 3SVB 9 ~N~gdN~ 3 ~N~dN~ 3SVB D ~N~VdN~ dO£ ~SVl~]dOl$ HIUON 9I-H£ 800~£ 33N3B3_~3~ 88 - 83~ - 8I 03000-] 31WO 3NO Nn~ 'W's'n lalNnO3 ~n~u~n~ Oq~I~ ~ I-H~ 993M · 3NI '~XSW9~ 03~ IN~W03 ~3AWn$ qUNO 1133W I 0 W3OW38NQgH3S 0009 OO09 000k 000E 000~ 000 ! 0 000 ! - .Ld/N I 0001 / ! -' ~!'1U35 L$3N 0003- 000~- HLR0S 000[- 0 000! 0003 000Y 0009 ~1:~ 000S HL~0N NO II33['OUd 9VINOZIBOH '3BB 'NgL/ 'gH=I , LBZ "IN_-I ,ZSLL) IzL-H£ '993H ii l~/NI O00{/I : )l~35 ZINOH ~HLd30 ld3IL~d3A NI 03"1~35 '(~ - '6P 3N~gd 9U311~3^ NO NOI£O3PO~d 0009 O00S 000~ O00E 000~ 000[ 0 0 O00t- OOO~- NOIlO3['0Bd 'lV3IIU3A (wn '38u 'NZti 'gL ' 'i H_-I ,LBZ '9N..I tTL-HE ,Z~LL) ARCO Alaska, Inc. Date: October 28, 1988 Transmittal #: 7333 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 H - 1 4 Pressue 3 K - 0 6 Kuparuk I F- 0 4 Kuparuk 3 H- 1 1 Kuparuk 3 H ~ 0 3 Kuparuk 1 E- 2 5 Kuparuk 3 N- 1 7 Kuparuk 3 H - 1 4 Kuparuk Build-Up Analysis Fluid Level Report Fluid Level Report Well Pressue Report Fluid Level Report Fluid Level Report Fluid Level Report Fluid Level Report 1 0-24-88 PBU 1 0 - 21 - 8 8 Casing 1 0 - 2 3 - 8 8 Casing & Tubing 1 0 - 1 0 - 8 8 Amerada 1 0 - 2 1 - 8 8 Casing 1 0 - 2 1 - 8 8 Tubing I 0- 2 1 - 8 8 Casing 1 0 - 2 1 - 8 8 Casing Receipt Acknowledged: ......... DISTBIBUTION: D&M ',Alaska 13il I ~as Cons. Commlsflori ', ~ohorage State of Alaska Chevron Mobil Unocal SAPC ARCO Alaska, Inc. Date: October 21, 1988 Transmittal 8:7330 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3H-14 Sub-Surface Pressure Survey 9-14-88 8AKU3H14 3H-15 Sub-Surface Pressure Survey 9-1 7-88 801KU3H15 3 H - 1 6 Sub-Surface Pressure Survey 9 - 21 - 8 8 801 K U 3 H 16 3H-18 Sub-Surface Pressure Survey 9-27-88 801KU3H18 3 N- 1 7 Kuparuk Fluid Level Report 1 0- 1 3 - 88 Casing Receipt Acknowledged: DISTRIBUTION: D&M State of Alaska Unocal Mobil SAPC Chevron ARCO Alaska, Inc.,. Date: October 14, 1988 Transmittal ~. 7316 - RE--I'URN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 H- 1 2 Sub-Surface Pressure Survey 9 - 2 2 - 8 8 PBU 3 H - 1 2 Sub-Surface Pressure Survey 9 - 2 2 - 8 8 PBU 3 H - 1 7 Sub-Surface Pressure Survey 9 - 2 2 - 8 8 PBU 3 H - 2 2 Bottom-Hole Pressure Survey 8 - 0 7 - 8 8 PBU 2 C - 1 I Kuparuk Fluid Level Report 1 0 - 0 6 - 8 8 Casing 3 H - 1 4 Kuparuk Fluid Level Report I 0- 0 7 - 8 8 Tubing 3 F - 1 3 Kuparuk Fluid Level Report 1 0 - 0 7 - 8 8 Casing 3 C - 1 6 Kuparuk Fluid Level Report 1 0 - 0 7 - 8 8 Casing 3 K - 0 6 Kuparuk Fluid Level Report 1 0 - 1 I - 8 8 Casing Receipt Acknowledged: DISTRIBUTION: D&M ~'State 'of Alaska Chevron 'Unocal Mobil. SAPC ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 5, 1988 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in triplicate is an Application for Sundry Approval on Kuparuk well 3H-'~,~' The well is suspected of having communication between the tubing and the annulus of the tubing and the 7". Your prompt attention is appreciated. If you have any questions, please call me at 265-6840. Sincerely, G. B. 8~m'allw°od Senior Operations Engineer GBS:kjr Attachments cc: J. Gruber M. L. Hagood S. P. Twiggs KOE1.4-9 ATO 1478 ATO 1120 ATO 1130 RECEIVED OCT u 5 1988 ;~laska.Oil & Gas Cons. Commission ~ Rnchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany '/'~ CONSERVATION C, OMM,~'~JON ' Ab OIL AND GAS APPLICATION FOR SUNDRY APPROVALS il. Type of Request: Abandon Suspend _ Operation Shutdown Re-enter suspended well Alter casing _ Repair well Change approved program _ _ Plugging _ Pull tubing _ Time extension Variance .~ Stimulate Perforate _ Other 2. Name of Operator ARCO Alaska. lng. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1157' FNL, 281' FWL, Sec. 12, T12N, R8E, UM At top of productive interval 1684' FSL, 1777' FEL, Sec. 1, T12N, R8E, UM At effective depth 1878' FSL, 1616' FEL, Sec.1, T12N, R8E, UM At total depth 1940' FSL, 1564' FEL, Sec. 1, T12N, R8E, UM 12. Present well condition summary Total Depth: measured 8 2 5 0' true vertical 63 74' feet Plugs (measured) feet None 6. Datum elevation (DF or KB) RKB 76 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3H-14 9. Permit number 87-123 10. APl number 50-1 03-20092 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool . Effective depth: measured 81 2 9' feet Junk (measured) true vertical 6 2 8 3' feet None Casing Length Size Cemented Measured depth True vertical depth Conductor 8 0' 1 6" 200 Sx AS I Surface 3421' 9 5/8" 1350 Sx AS III & 400 Sx Class G Production 81 8 7' 7" 800 Sx Class G & 175 Sx AS I Perforation depth: measured 7758'-7763', 7768'-7798', 7954'-7974' MD 115' 115' 3456' 3001' 8220' 6351' true vertical 6018'-6022', 6025'-6046', 6154'-6168' TVD Tubing (size, grade, and measured depth 3 1/2", J-55, tbg w/tail @ 7859' Packers and SSSV (type and measured depth) FHL pkr @ 7674'~ WD pkr ~ 7832'~ & TRDP-1A ENC SSSV @ 1788' Attachments Description summary of proposal X Detailed operation program _ RECEIVED OCT o 5 i988 Alaska.0il & Gas Cons. Commission Anchorage BOP sketch 14. Estimated date for commencing operation October 6. 19~ 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil .~ Gas _ Service Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~' ' - FOR C_,C~MISSIOi~ USE ONLY Mechanical Integrity Test_ Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test_ Location clearance__ Subsequent form require Approved by the order of the Commission Form 10-403 Rev 06/15/88 OFll61NAL 81~iNED DY 10-A-~ed Copy Retu r ne~l,,,~ IApproval No.~::~_ 7~'-~ ! SUBMIT IN TRIPLICATE KRU WELL 3H-14 APPLICATION FOR SUNDRY APPROVAL Kuparuk River Unit Well 3H-14 has suspected communication between the tubing and tubing x 7"'annulus (7"), and possibly the 7"x 9 5/8" annulus (10"). The well is currently shut in pending review of this application. The Commissioner's approval as authorized under AAC 25.200(d) is requested to continue producing this well to perform diagnostic and repair work. Diagnostic efforts will include monitoring tubing, 7", and 10" pressures while pressuring up or bleeding off various strings, pulling and resetting dummy gas lift valves, and running leak detection logs if warranted. Well 3H-14 is a 3 1/2" single completion with two packers and 5 dummied gas lift mandrels. It is an oil producer and is not on gas lift. The Kuparuk C Sand is currently shut in and was last tested at 47 BOPD, 300 GOR. The Kuparuk A Sand is producing 143 BOPD at a 1050 GOR. The pressures for the three strings are summarized below: FTP = 150 psi 7" = on vacuum 10"= 250 psi. Since Well 3H-14 is a Iow rate producer and is not on gas lift, the possibility of wellbore fluids entering formations from the 7" or 10" strings is believed to be minimal. Continued operation of the well is recommended to augment diagnostic efforts so that any leaks may be repaired. WELL 3H-14 SURFACE LOCATION: 1157'FNL, 281'FWL, SEC12, T12N, R8E TREE: McEvoy 3-1/8" 5000 PSI DEPTHS REFERENCED TO 0' RKB TUBING SPOOL ELEV: 35' RKB APl #: 5010320092 REVISION: 06/2/88 16": 62.5# H-40 @ 115' J 9 5/8": 36# J-55 @ 3455' PBR: BAKER 2.992" ID @ 7660' PKR: BAKER FHL 2.992" ID @ 7674' OTIS XN NIPPLE WITH SLEEVE 2.35" ID @ 7818' C PKR: OTIS 'WD' B @7832' A3 A2 A1 7": 26# J-55 @8220' L SSSV' Camco TRDP-1A 2.813" ID @ 1788' Camco GLMs GLMI: 2874' / 1.0" GLM2: 5310' / 1.0" GLM3: 6753' / 1.0" GLM4: 7279' / 1.0" GLM5: 7621' / 1.5" Camco GLM GLM6: 7710' / 1.0" 7758' 7763' 7768' 7798' lO SPF 3.5" 9.2# J-55 BTC ABMOD TO 7841' X-OVER TO 2-7/8 6.5# J-55 @ 7841' CAMCO 'D' NIPPLE 2.25" ID @ 7849' TUBING TAIL @ 7859' RECEIVED OCT 0 ~'.~ 1988 .0il & Gas Cons. Commissior~ ,., Anchorage PBTD: 81 O6' ARCO Alaska, Inc. Date: September 7, 1988 Transmittal #: 7285 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 F- 1 3 Kuparuk Fluid Level Report 8 - 2 7 - 8 8 Casing 3 K - 1 8 Kuparuk Fluid Level Report 8 - 2 7- 8 8 Tubing 3 B - 1 3 Kuparuk Fluid Level Report 8 - 2 6 - 8 8 Casing ' 3 Q- 15 Kuparuk Fluid Level Report 8 - 2 7 - 8 8 Casing ' '3N-08A Kuparuk Fluid Level Report 8-26-88 Casing ~ 3 H - 1 4 Kuparuk Fluid Level Report 8 - 2 6 - 8 8 Casing I E- 1 2 Kuparuk Fluid Level Report 8 - 2 6 - 8 8 Casing '~ 3 K - 1 4 Kuparuk Fluid Level Report 8 - 2 6 - 8 8 Casing ' 31 - 0 3 Kuparuk Fluid Level Report 8 - 2 6 - 8 8 Casing 1Y-06 Kuparuk Well Pressure Report 8-26-88 Both Sands 1 Y- 0 7 Kuparuk Well Pressure Report 8 - 2 6 - 8 8 Sand W Receipt Acknowledged: DISTRIBUTION: D&M State of Alaska Chevron Unocal Mobil SAPC ARCO Alaska, Inc. Date: August 19, 1988 Transmittal #: 7264 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge-receipt and return one signed copy of this transmittal. 1 G- 1 4 Kuparuk Well Pressure Report 8 - 0 8 - 8 8 Amerada 3 H- 1 4 Kuparuk Fluid Level Report 8 - 1 2 - 8 8 Casing 1 G-0 7 Kuparuk Fluid Level Report 8 - 1 3 - 8 8 Tubing I'R- 1 5. Kuparuk Fluid Level Report 8 - 1 3- 8 8 Tubing 1 C- 0 8 Kuparuk Fluid Level Report 8 - 1 2 - 8 8 Tubing Receipt Acknowledged: ........................... Date: ............ DISTRIBUTION; D&M State of Alaska Unocal SAPC Chevron Mobil ARCO Alaska, Inc. Date: July 15, 1988 Transmittal #: 7225 RETURN TO: ARCO Alaska, Inc. ^ttn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. one signed copy of this transmittal. Please acknowledge receipt and return ~30-15 Kuparuk Fluid Level Report 30-10 Kuparuk Fluid Level Report 2D-15 Kuparuk Fluid Level Report 2A-06 Kuparuk Fluid Level Report 1G-07 Kuparuk Fluid Level Report 1 G- 08 Kuparuk Fluid Level Report 1 G-15 Kuparuk Fluid Level Report 31-01 -~-Kuparuk Fluid Level Report 31-1 2 Kuparuk Fluid Level Report 2A-03 Kuparuk Fluid Level Report 3 H- 1 4 Post Frac Job Report 2 B- 1 6 Bollom Hole Pressure' Survey 3J-1 0 Kuparuk Well Pressure Report 7- 1 I - 8 8 Tubing 7- 1 1 - 8 8 Tubing 7 - 1 2 - 8 8 Casing 7- 1 2- 8 8 Tubing 7 - 0 8 - 8 8 Casing 7- 0 8 - 8 8 Casing 7- 0 8 - 8 8 Casing 7- 0 8 - 8 8 Tubing 7 - 0 8 - 8 8 Tubing 7- 0 6 0 8 8 Casing 7-09-88 Allo Frac A-10 7 - 0 3 - 8 8 PBU 3 - 0 8 - 8 8 Amerad Receipt Acknowledged: --'- ........................Date: ............ DISTRIBUTION: D&M State of Alaska SAPC Mobil Unocal Chevron ~ STATE OF ALASKA ~ ALASK~ ,ilL AND GAS CONSERVATION COMIV. _ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate ~ Pull tubing [] Alter Casing [] Other I~ COMPLETE 2. Name of Operator ARCO Alaska, Inc. 3. Address 6. P.0. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 7. 1157' FNL, 281' FWL, 5ec.12, T12N, R8E, UN At top of productive interval 1684' FSL, 1777' FEL, Sec. 1, T12N, R8E, UN At effective depth 1878' FSL, 1616' FEL, Sec. 1, T12N, RSE, UM At total depth 1940' FSL, 1564' FEL, Sec. 1, T12N, R8E, UM 5. Datum elevation (DF or KB) RKB 76' Unit or Property name Kuparuk River Unit Well number 3H-14 8. Approval number 7-992 9. APl number 50-- 103-20092 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80 ' Surface 3421 ' Production 8187' Perforation depth: measured true vertical 8250 'MD feet Plugs (measured) None 6374 ' TVD feet 8129 'MD feet Junk (measured) None 62 83 ' TVD feet Size Cemented Measured depth 16" 200 sx.A5 I 115'MD 9-5/8" 1350 sx AS III & 3456'MD 400 sx Class G 7" 800 sx Class G & 8220'MD 175 sx AS I 7758'-7763'MD, 7768-7798'MD, 7954'-7974'MD 6018'-6022 'TVD, 6025'-6046'TVD, 6154-6168 ' TVD Feet True Vertical depth Tubing (size, grade and measured depth) 3½", J-55, tbg w/tail (~ 7859' 115 'TVD 3001 ' TVD 6351 ' TVD RECEIVED 12. NS/t~mulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation dUl~l .~ v 4,.300 Alaska 011 & Ga8 Cons. Commission Anchorage Tubing Pressure 14. Attachments Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Copies of Logs and Surveys Run ~] Gyro (Completion Wel~. History) Daily Report of Well Operations I~ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Title Associate Engineer Form 10-404 Rev. 12-1-85 (Dani) SW03/88 Date Submit in Duplicate~- ARCO-~,,I and Gas Company Daily Well History-Final Report Inllrucllonl: Prepare and submit the "Final Reporl" on the first Wednesday after allowable has been assigned or well II Plugged, Abandoned, or Sold. "Final Report" should be aubmitted also when operations are suspended for an indefinite or appreciable length of time. On workoverl when an Official tell Is not required upon completion, report completion and representative test date in blocks provided. The "Final Report" form may be uled for reporting the entire operation if space is available. District ICounty or Parish ARCO Alaska, Inc. I NORTH SLOPE Field ILease or Unil KUPARUK RIVER FIELD I ADL: 25531 Auth. or W.O. no. JTitle AK2572 I COMPLETION Operator ARCO Spudded or W.O. begun IAccountlng StalL coil center code 3H-14 iwell no. IA.R.Co. W.I. rrotal number of wells (active or inactive) on thisI Icost center prior to plugging and 56,0000 labandonment of this well 05/16/88 / 0715 }{RS ACCEPT Date and depth as of 8:00 a.m. Old TD Released rig 05/18/88 ( TD: 8250 PB: 8106 SUPV:DL/BB Classifications (oil, gas, etc.) Producing method Complete record for each day reported NORDIC i RELEASED RIG 7"@ 8220' MW: 6.9 DIESEL MU HANGER. LOST CONTROL LINE PIECES. POOH. REPLACE CONTROL LINE. RIH WITH TUBING. LANDED TUBING. SET PACKER. TESTED TUBING TO 2500 PSI. SHEARED PBR. TESTED ANNULUS TO 2500 PSI. TESTED SSSV TO 1500 PSI. SHEARED BALL g 2200 PSI AND SET BPV. ND BOPE. NU TREE AND TESTED TO 5000 PSI. DISPLACED WELL WITH DIESEL. TESTED CV TO 1000 PSI. SET BPV. SECURED WELL AND RELEASED RIG @ 1800 HRS, 5/17/88. (TAIL @ 7859', 'WD' PKR @ 7832', 'FHL' PKR @ 7674', & SSSV @ 1788') DAILY:S175,257 CUM:$1,061,744 ETD:S1,061,744 EFC:$1,394,000 RECEIVED JUN 1 0 1988 JNew TD Date Alaska 011 & Gas Cons. Commission Anchorage IPB Depth Kind of rig IType completion (single, duel, etc.) Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production OII on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected Signature I Date I Title Drilling, Pages 86 and 87. AggOOIATE ENt~ttNFER AR3B-45~3-C INumber all dally well hlatory forma as they are prepared for each well, conlecutlvaly IPlge no. Division of Altl~tk~l~hflMdC~mplny ARCO O. and Gas Company Well History - Initial Report - Daily Insffuctions: Prepare and submit the "Initial RePort" on the first Wednesday after a well is spudded or workover operations are Itlrted. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ICounty, psrish or borough ARCO Alaska, Inc. I NORTH SLOPE Field JLease or Unit KUPAROK RIVER FIELD I ADL: 25531 Auth. or W.O. no. ITitle AK2572 J COMPLETION ]ata~K 3H-14 IWell no. Operator ARCO Spudded or W.O. begun IDate ACCEPT I 05/17/88 Date and depth as of 8:00 a.m. 05/17/88 ( TD: 8250 PB: 8106 SUPV:DL/BB Complete record for each day reposed NORDIC i l ARGO W.I. IHour I 56.0000 IPrior status if e W.O. 0715 HRS MU HANGER 7"@ 8220' MW:10.0 NACL/NABR MOVED RIG FROM 3H-13 TO 3H-14. ACCEPTED RIG @ 0715 HRS, 5/16/88. ND TREE. NU BOPE AND TESTED TO 3000 PSI. PERFORATED 'C' SAND WITH 10 SPF FROM 7758'- 7763', 7768'-7798'. PERFORATED 'A' SAND WITH 4 SPF FROM 7954'-7974' RAN GR AND JB. SET WD PACKER @ 7832'. RIH WITH 3-1/2" COMPLETION EQUIPMENT. DAILY:S99,430 CUM:$886,487 ETD:S886,487 EFC:$1,394,000 The above is correct For form preparatiory~nd distribution, see Procedures Mar(~al, Section 10, Drilling, Pages 86 end 87. IDate I Title b- :~ -,~ ASSC)OIATE ENGINEER INumbar all con#cutlvely ,Page no. prepared for each well. I las they ara dally well hlltoly form-, I AR3B-459-1-D ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: February 29, 1988 Transmittal #: 7107 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~,3H-11 Cement Evaluation Log 2-15-88 5000-7534 ~3H-12 Cement Evaluation Log 2-15-88 4300-7108 ~3H-13 Cement Evaluation Log 2-15-88 4400-7228 ~--3H-17 Cement Bond Log 2-19-88 6300-8470 ~'~ Cement Bond Log 2-17-88 3150-8102 ~ 3H-15 Cement Evaluation Log 2-17-88 5250-8330 Receipt Acknowledged: DISTRIBUTION: NSK Drilling Oil & Gas Cons. C0mmisgk~ Date: State of Alaska(+sepia) ARCO Alaska. Inc. is a Subsidiary (3f AtlanticRichfieldCompany ,(uedmo3plallqotUOllUell¥ jo ,{Jelp!sqnS · si U3Ul 'e)lSel¥ OOUV ~a3UT~aoD uu~q :NOIZfi~IMZSI~ :pa~palaOU~V ~dTaoaM eOe.loqooV u01sSlmtU00 'su00 se~,,~ I!0 mls~ ~ ~UT~STq pu~ ad~z alOH uado ~UT~ST~ pu~ ad~£ ~TPM HO ~uT~sTq pu~ ad~z ~TP3 HO 'T~Tmsu~a~ sTq3 ~o ~doa pau~ls auo uan~aa pu~ ~dTaoaa a~paTmouMo~ asuaId 'smart ~uT~oTIo~ aq~ aa~ q~T~aaaq pa~Tmsu~az 09~0-01966 MV 'a~aoqouv 09~OOl xo~ 'O'a 6lll-OIV ~aalD spaooa~ ~naednM :u~v : O.T. NMfI.T. MM 960£ :~ l~Tmsu~az 886! '6! Ka~naqa~ :a~e~ Stg[ 9Zg Z06 auoqdalal 09£0-0~S66 e)lSelV 'a§e~oqouv 09£00! "-', e:)!JlO ISOd TELECOPY NO~ (907) 276-7542 January 19', 1988 Mr. Jeffery B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O.'Box 100360 Anchorage, AK 99510-0360 Re: Correction of A.p¢I, Numbers for KuparUk River Unit Wells 3H-11, 3H-14, and 3H-20 Dear Mr. Kewin: A~~ error was made in. the assignment by the Commission of A.P.I, numbers for K.R.U. wells 3H-11, 3H-14 and 3H-20. The erroneous 'assignments were based on the bottom hole locations of these wells. They should have been based on the surface locations.' Accordingly, the A.P.I, numbers for these wells have been corrected by the Commission as follows: KRU 3H-11 (Permit No. 87-124) API number erroneously assigned as 029-21771 has been corrected to 103-20091. KRU 029 Permit No. 87-123) API Number erroneously assigned as has been corrected to~ KRU 3H-20 (Permit No. 87-134) API Number erroneously assigned as 029-21775 has been corrected to 103-20093. Petroleum Information has been notified and the Tuesday report of the Commission will list the corrections. For your reference, I. am enclosing corrected copies of the Commission's permits to drill (10-401) for these wells. Accordingly, please correct your records. Please telephone me at (907) 279-1433 if you need further infor- mation. Sincerely, ~ : W; W. Barnwell Commissioner dlf: 1. WWB, 22 ~ Attachment ARCO Alaska, Inc. Post Offi .~--"~x 100360 Anchorag,- ........ aska 99510-0360 Telephone 907 276 1215 Date: December 31, 1987 Transmittal # 7047 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return-one signed copy of this transmittal. 3H-14 Colville OH Edit Tape and Listing 12-13-87 #72546 HAPPY NEW YEARS Receipt Acknowledged: DISTRIBUTION: Martin Stanford Alaska Oil & Gas Cons .... ,, BPAE SAPC Unocal : State of Alaska ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCornpany Date: ARCO Alaska, Inc. Pos! Offi~ 100360 Anchorage.,..~aska 99510-0360 Telephone 907 276 1215 December 31, 1987 Transmittal #: 7046 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3H-14 OH Edit Tape and Listing 12-13-87 #72545 HAPPY NEW YEARS Receipt Acknowledged: DISTRIBUTION: Date: & Gas C0n~.-C0mmi$~i0u Anchorage Martin Stanford State of AZaak~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany /..-,,, ~ STATE OF ALASKA ~ ALASr,~ OIL AND GAS CONSERVATION CON ..... ,~SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown IX Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator 5. Datum elevation (DF or KB) ARCO A1 aska, I nc. RKB 76 ' feet 3. Address 6. Unit or Property name P. 0. Box 100360, Anchorage, AK 99510-0360 Kuparuk River Unit 4. Location of well at surface 1157' FNL, 281' FWL, Sec.12, T12N, RSE, UM At top of productive interval 1674' FSL, 1786' FEL, Sec. 1, T12N, RSE, UM At effective depth 1830' FSL, 1596' FEL, Sec. 1, T12N, R8E, UM At total depth 1887' FSL, 1544' FEL, Sec. (approx) (approx) 1, T12N, R8E, UM (approx) 11. Present well condition summary Total depth: measured true vertical 8250, MD feet Plugs (measured) 6395' TVD feet 7. Well number 3H-14 8. Permit number 87-12R 9. APl number 50-- 029-21770 10. Pool Kuparuk River 0il None Pool Effective depth: measured true vertical Casing Length Conductor 80' Surface 3421' ProdUction 8187' 81 29 'MD feet Junk (measured) None feet 6301 ' TVD Size Cemented Measured depth True Vertical depth 16" 2'00 sx AS I 115'MD 115'TVD 9-5/8" 1350 sx AS III & 3456'MD 3012'TVD 400 sx Class G 7" 800 sx Class G 8220'MD 6371 'TVD Perforation depth: meaSured None true vertical None Tubing (size, grade and meaSured depth) None Packers and ssSv (type and measured depth) None RECEIVED DEC z :[ 87 Alaska 0il & Gas Cons. C0mmissi0n Anchorage 12.Attachments Well Hi story Description summary of proposal [] Detailed operations program [] BOP sketch 13. Estimated date for commencing operation March, 1988 14. If proposal was verbally approved Name of approver Subsequent Work R, ePortea oa / ~Form Ho. ~~_.~Dated .~/.~;r Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~(/~/'Y//)L./ ,,~,/,L/.k,~! .. Title Associate E nqin~r Signed (~ - Commission Use Only (Dani) $A3/41 Date Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Approved Copy Returned - .../: ., 'ORIGINAL SIGNED BY Approved by I n~l~: P. RMITH Form 10-403 Rev 12-1-85 Commissioner IAppr°va' N°' 7 by order of the commission Date/c~---- ' Submit in triplicate~ ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ARCO Alaska, Inc. Field Auth. or W.O. no. AK2572 ICounty, parish or borough NORTH SLOP;- Lease or Unit ADL: 25531 Title DRILL 3H-14 ]Well no. API: 50-029-21770 Operator ARCO Spudded or W.O. begun SPUD Date and depth es of 8:00 a.m. 12/07/87 ( TD: 605'( SUPV:RB 12/08/87 ( TD: 3492'( 2 SUPV:RB -12/09/87 ( TD: 3492'( SUPV:RB ~ 12/10/87 ( TD: 4020'( SUPV:JP .12/11/87 ( TD: 7029'( 3 SUPV:JP 12/12/87 ( TD: 7981'( SUPV:JP 12/13/87 ( TD: 8250'( SUPV:JP 12/14/87 ( TD: 8250'( SUPV:JP ID@re 12/07/87 IH°ur Complete record for each day reported DOYON 14 0245 IARCO w.I. 56.0000 Prior statue if a w.o. ) [90) DRILLING. 16"@ 115' MW: 8.9 VIS: MOVE RIG. NO DIVERTER AND LINE. ACCEPTED RIG @ 2000 HRS 12/06/87. TEST DIVERTER, AND DRILL ICE. SPUDDED WELL @ 0245 HRS, 12/.7/87 MU BHA AND DRILLED 12-1/4" HOLE TO 605'. DAILY:S17,752 CUM:$17,752 ETD:S17,752 EFC:$1,394,000 ~) I87) CIRCULATING @ 12-1/4" TD 16" @ 115' MW: 9.5 VIS: 75 DRLD 12-1/4" HOLE_F/605'-2509'. DROPPED SURVEY. POOH. CHANGE BHA. RIH. DRLD 12-1/4" HOLE F/2509'-3492'. DAILY:S83,981 CUM:$101,733 ETD:S101,733 EFC:$1,394,000 0) TESTING BOPE 9-5/8"@ 3456' MW: 9.3 VIS: 56 CIRCULATE AND SHORT TRIP. CIRCULATE AND POOH. LD BHA. RUN 87 JTS 9-5/8" CSG. CMTD W/ 1350 SX AS III @ 12 PPG AND 400 SX CLASS G. CIP @ 2230 HRS 12/8/87 . ND DIVERTER. NU BOPE. TEST BOPE. DAILY:$186,889 CUM:$288,622 ETD:$288,622 EFC:$1,394,000 ) 28) ) )09) DRILLING 9-5/8"@ 3456' MW: 8.8 VIS: 32 ND BOP'.S. REPLACE BRADENHEAD. NO BOP~%S..AND TEST SAME. TIH. TEST CASING' TO 2000 PSI. RUN LOT EMW = 12.5 PPG. POOH. MU BIT, TURBINE AND .ORIENT SAME. TIH. DRILL 8-1/2" HOLE F/ 3512' - 4020'. DAILY:S55,829 CUM:$344,451 ETD:S344,451 EFC:$1,394,000 DRILLING 9-5/8"@ 3456' MW: 9.4 VIS: 35 DRILLED 8-1/2" HOLE FROM 4020'-.7029'. DAILY:S40,829 CUM:$385,280 ETD:S385,280 EFC:$1,394,000 ;) 152) ) 69) 0) DRILLING 9-5/8"@ 3456' MW: 9.9 VIS: 39 TURBODRILL 8-1/2" HOLE TO 7779'. POOH LD TURBINE. DRILL 8-1/2" .oo. .o. ..: .3 DEC 1987 DRILL 8-1/2" HOLE TO 8250'. CIRC HOLE CLEAN. RIH WITH LOGS ANDLoGs.HIT BRIDGE @ 6420'. MU .HA AND REAM THROUGH. DAILY:S44,206 CUM:$486,398 ETD:S486,398 EFC:$Z,394,000'~Cu0ra§e RUNNING 7" CASING 7"8 8220' MW: 9.9 VIS: 41 LOG OH. RUN DIL/GR/SP/SFL 8250'-3455'. FDC/CNL 8250'-7550'. CAL 8250'-3455'. GR 8250'-1000'. COLVILLE 4200'-3700'. CIRC HOLE CLEAN. RU AND RUN 7"'CASING. DAILY:S105,359 CUM:$591,757 ETD:S591,757 EFC:$1,394,000 The above ia correct For form preparetiol~and distribution, see Procedures Ma~Jial, Section 10, Drilling, Pagea 86 dhd 87. IDate J Title Associate Engineer ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if 'space is available. Accounting cost center code District ICounty or Parish State I ARCO Alaska, Inc. NORTH SLOPE AK Field Lease Dr Unit Well no. KUPARUK RIVER FIELD ADL: 25531 3H-14 Auth. or W.O. no. ITitle AK2572 J DRILL Operator ~ A.R.Co. W.I. ARCO J 56,0000 Spudded or W.O. begun ~ Date SPUD I 12/07/87 Date and depth as of 8:00 a.m. 12/15/87 ( TD: 8250'( SUPV:JP Complete record for each day repo~ed DOYON 14 Iotal number of wells (active or inactive) on this, Dst center prior to plugging and I bandonment of this well our 0245 IPrlor status if a W.O. I RIG RELEASED 7"@ 8220' MW:10.0 BRINE FINISHED RUNNING 7" CASING. RAN 190 JTS OF 7", 26#, J-55 BTC CASING. FS @ 8220'. CEMENTED CASING WITH 500 SX OF 50/50 POZ, FOLLOWED BY 300 SX OF CLASS G. CIP @ 1300 HRS, 12/14/87. NU TREE .SECURED WELL & RELEASE RIG @ 1930 HRS 12/14/87. DAILY:S195,300 CUM:$787,057 ETD:S787,057 EFC:$1,394,000 Old TD Released rig Classifications (oil, gas, etc.) Producing method Potential test data INew TD I PB Depth Date IKind of rig I Type completion (single, dual, etc.) Official reservoir name(s) ,, Well no. Date ' Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day ... Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected .... The above is correct For form preparation an/~Jdistribution, see Procedures ManuaI,L,~ection 10, Drilling, Pages 86 and 87. Associate Engineer ~. ~,9'l~Z, 699 Z,06 ARCO Alaska, Inc. Post Office BOX 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: December 24, 1987 Transmittal # 7044 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3H-14 2" & 5" Porosity FDC 12-13-87 7550-8215 3H-14 5" Dual Induction 12-13-87 1000-8215 3H-14 2" & 5" Raw Data FDC 12-13-87 7550-8215 3H-14 2" Dual Induction 12-13-87 1000-8241 3H-1I West Sak 5" Dual Induction 12-18-87 3650-3656 3H-.ll West Sak 2" & 5" Raw Data FDC 12-18-87 3636-3656 3H-11 West Sak 2" Dual Induction 12-18-87 3650-3656 3H-11 West. Sal 2" & 5" Porosity FDC 12-18-87 3636-3656 Receipt Acknowledged: DISTRIBUTION: A~C~0mgu NSK Franzen Drilling D & M Lucille Johnston(vendor package) ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: December 24, 1987 Transmittal ~ 7042 IU~TURNTO: 'ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3H-8 Colville"Strattgraphic High- Resolution Dipmeter 10-23-87 3H-14. Colvilte:2!~ & 5".Porosity FDC 12-13-87 3H-14 Colville 2" & 5h Dual Induction 12-13-87 3H-14 Colville 2" & 5" Raw.Data FDC 12-13-87 #72476 3700-4200 3700-4200 3700-4200 Receipt Acknowledged: DISTRIBUTION: EC 2 8 1987CJ NSK Drilling Geology D & M Piano SAPC (+sepia) Unocal(+septa) "i"~' State' of 'Alaska (+oej~ .Ih,) BPAg(+sepia) ARCO Alaska. Inc. is a Subsidiary of AllantlcRIchfleldCompany X.zo~o"I '"t ~no(I '.zI,,I · iou~ o/~ uo'l:.3~S ::l. ea'!:qeH '~ureo S q~]:.& go ~u~m:~.,z~d~ :DO ~osoIou~ ~IP NOISBIN~OD ~H~ ,.,.tO ~I'3(I"(I0 7,At uo~ssx.'_mm_oo UOX.~A:t~S.UO3 S~0 pu~ I~0 e~lS~lV uo~3~qD 'A 'O · adld zoaonpuoo aq~ ~o aoqs aq~ RoI~q ~u~II~P ~ogaq ~u~asa~ ssau3$~ ~em uo~ss~oD ~q~ ~q3 os uo~a~II~aSu~ 3uamd~nb~ ~ulouammo~ 03 ao$~d sanoq ~ ~$g~o s!q3 i~$'3ou osIe ~s~Id aoe~ne aq~ a~ogaq 3uamd~nbo oq~ ~o ~u~3sa~ ssau3~ o~ 3uosa~d ~q i~m uo~ss~umaoD oq~ ~o oa~e3uosaadoa e ~eq~ os ~u~md~nbo uolTuaaaad ~noaolq oq~ ~o uol~li~sul tul~uounaoo o~ aolad sano~ 9~ aol~lo slq~ l~l~ou aS~ald 'aaot plal~ ~ullnp:o~os ul sn pie ol ~q3 IISZtP o7 3!u~ad :to~ uox. 3vo$Idd~ p~Ao:tddv aq3 s! P~SOlOU~ ~,~gL'gLz (LO6) :~doooI~,I, L86I ' 9 :taqmo~oQ 'l STATE OF ALASKA ALASK~-~IL AND GAS CONSERVATION C..,}VlMISSION PERMIT TO DRILL 20 AAC 25.005 I la. Type of work Drill ~ Redrill lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] Deepen[]1 Service [] Developement Gas [] Single Zone ~ Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc RKB 76' PAD 39' feet Kuparuk River Field · ' Kuparuk River Oil Pool 3. Address 6. Property D~ignation P.O. Box 100360 Anchorage, AK 99510-0360 ADL 255'5:t: ALK 265? 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 1157'FNL, 281'FWL, 5ec.12, T12N, R8E, UM Kuparuk River Unit 5tatewide At top of productive interval ~ TO, l'(~h 8. Well nurpber Number i1674'FSL, 1786'FEL, Sec. 1, T12N, R8E, UM 3H-14 #8088-26-27 At total depth 9. Approximate spud date Amount 1834'FSL, 1605'FEL, Sec. 1, T12N, R8E, UM 12/10/87 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 3H-15 81 73'MD property line 1605'~ TD feet 25' (~ Surface feet 2560 (6324'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 17..00 feet Maximum hole angle 4[p° Maximum surface 1 8'~.'~ psig At total depth (TVO) 3',O~ psig .... 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' ±200 cf 12-1/4' 9-5/8" 36.0# J-55 BTC 3441 ' 35' 35' 3476' 3086' 1255 sx AS II I & HF-E} W 400 sx Class G blend 8-1/2" 7" 26.0# J-55 BTC 8139' 34' 34' 8173' 6324' 200 sx Class C(minimum HF-EIW TOC iO0' abo,e top of Kuparuk 19. To be completed for Redrill, Re-entw, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate [)i:.C ().5 Production Liner ~:~S!:~ 0ii ;~ Gas Cof~s. O0~,~;liSS[ON Perforation depth: measured ~',-" true vertical 20. Attachments Filing fee ~ Property plat [] BOP Sketch ~ Diverter Sketch ~ Drilling program ~[ Drilling fluid program j~ Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements 21.1 herebY cer~y-tl~t the ,oreg,eh'~~e and correct to the best of my knowledge Signed //////~/~//¢'~-"~/'~>~.~:z~.4/.~'~ TitleRegi°nal Drilling Engineer Date r/ ~'(.// '~ Commission Use Only (AWM) PD2/61 I I Isee c°ver lette'r Permit Num/b"er/ APl number 10~,~o.~O~¢1~,. App~.o~_a)(~t~87 for other requirements ~'1' -'12. ~ 50-- ¢'¢~O - . 0 · Conditions of approval Samples required [] Yes BS~qo Mud log required L--] Yes Hydrogen sulfide measures [] Yes E~;~No Directional survey required I~P~Yes [] No Required working pressure, for B~E.~[]2M; ~3M; [] 5M; [] 10M; [] 15M Other: ~(~~ by order of Approved by Commissioner the commission Date Form 10-401 Rev. 1; !-1-85 :ate , " : oood. 'i °°o, ooo, . . tOBS-+t¥OI: SBA '~ 000~ .' 000 ? , ; p,~$odod , : ~il l-dBo 6~si-a~l s£1£-Oil ]lllAlO0 t~LL-J3Q..gx~t-GWJ, g80£-OAJ..-.LJ 880 ..8/S 6 - -.. I 16-dig 98 i£-01,11 988~:-0AJ. ~: 141 jOO-d$O 8;R-awl teS~-OAl' SONS )IVS A /l ~ ' ' '~ ' t - - , ' . i O-d~ oo~ J. , , k-t~,ll~ 00~ l loll 'dO] VI ,°N 'HR I leP, , 3'10N¥ 30¥~!3^¥ -O00g _ _ ~ ' 'O00P ..... -ooo£ .... ~'-- 000~ .................... ' 0009 oooz-": ..... -'--i ..... HOF(-'ZONTAL PROJECTION SCALE 1 IN. "1000 FEET , .. imco ..... i Prod 3H. ~.11 Ne~14;_P~opo~ed '~EST'EAST 4000 1000 0 1000 3000 . 2000 _ !DO0 . ................. 1000 ' 2000 ;3000 , ,,i .,I ,,. 1834' IrOL, ?AK~T C~NTER TVDI40O4 THD-7'840 DE'P-4383 NORTH 3831 EAST 3al 3 TAR~ LOOATI, ON, I~7'4' f:'SL. 17'~' FEL, ~EO. I. TI3tl. R~E' 4000 ~.IRF'AOE: LOOAT I l~/" FILL. ,. · t . : ~ I N 48' OEO 37 I'I]:. E ! 4282 ...... ~. (TO TAROET) ............ ~ ....................... 0~ 00~ I, · ' 00~,' [ 11' 06Z 1~/ ...... / 0 / 0~8 i, Zt, 1/~- ............. ~:001 ........ · i i Ol' i / I i ~ g6 I. ' OOffl '0~11 '0011 ' OgOl · ' 0001 i I , 0~6 DI.LVI,43H:)$1,43J. SAS O1'11,4 1V:)ldA.L U]NV'J'IO 39N..IIVIN30 ON~ ~U3~IVH~ UIX~ UltC~ UI].~ U3NV3'IO Clnld. U~3CI · u~ ~nqs '0~2 o~ XXM ~X~ *0~ *dot q~dJp T~2o~ qouq 9uTd u~oq ,~T epTAo2d o~ eToq .~ hTTTTzp ~3u~ '6 · dot 'u~Td 'lTa S"Z'Z3A Density DRILLING FLUID PROGRAH Spud to Drill out 9-5/8" Surface Casini 9.6-9.8 ' Wei{ht Up to I'D 10.3 PV 15-30 5-15 9-13 20-40 8-12 8-12 Viscosity 50-100 35-40 35-~5 3-5 10 Minute WI 15-30 4-8 5-12 Filtrate APl 20 10-20 pR 9-10 9.5-10.5 9.5-10.5 Solids 10~ 4-7 9-12 Drillins Fluid Szstes: Triple Tande~ Shale Shaker 2 Mud Cleaners Centrifuse Degasser PiC Level Indicator (Visual & Audio Alarm) Trip Tank Fluid Flow Sensor Flui~ Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calcUlated using a surface casing leak-off of 13.5 ppg F. MW (Kuparuk average) and a gas gradient of .ll psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. In accordance with Area Injection Order No. 2, excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during an'. extended shutdown in disposal operations. The annulus will sealed with 175 sx of cement followed by arctic pack upc:: completion of the fluid disposal. LWI~ / ih 99-£-t I ~r ANY ~ONn ' N0151:13^10 k. I I I NOI.LYJ:13d'O · 3~NYN~J..NI¥t,,I g NOi.Lalu;~$~o 31.LVId3H3S t:13.1.~l:l^la .OZ; .LINI'I ~l]AIt:l 'dl'li::lVdrl)l III (z~ ~ 28) (6) ~ ~ l ~/<>~W (29 r. nru. ~1) 01/28/87 6.011 9. D~ ~=~. hava a bad in f~ .................................. 10. IS a c~~~ order ~~d ...................................... ,,, !! Is admiuis~-a~f_ve mm~r~-naedad ].2. Is ~ lease mmioer aznormrrlaua ..................................... 13. Do~ ~ba ~ h~ a uni~. .o 14. IS ~d~~ s~-iuE ~dad ........................................ ~ , 15. W~ll sur~ ~i~E p~C= ~h ~u~ z~ ....................... ~ 16. ~ ~~ c~: ~ed ~ ~~]ata ~ ~~r ~d ~~a ......... ~ 17. ~ c~: ~e ~ ~~ ~ ~u~ua ~ p~~~ s~~ ... ~, __ 18. W~ c~u ~ ~ ~ ~~~ ~~ ..................... ~ - ,,, 19. ~!~ ~ e~g~ ~ a~~a s~a~ ~ ~~sa, ~im ~ ~~.. ~ .... 20. ~ ~ ~ ~ be o~ ~ ~ ~q~ ~]:Oh~ ............ ~ __ ~. ~ o~d ~!qhore ~~~ ~ca~ ~~d ~ 10-403 ............ 2.00 .i, 24. Is ~ha ~:t!~nE fluid p~~ s~~ic and lisu of ~e~. u adequa, ra ~ 26. ~ ~ ~ m~cS~ ~~ ~~ - T~u ~ 3000 P~ .. ~ 27. ~ ~ ~ ~~old c~ly wt~I ~-53 ~ 8~) .................. , ~. ~ ~ ~~ of ~S. ~ ~~ ................................. ,, Fo= explcrzr, o=7 and $~-a~~ 29. A=e dar. a p=esen~_d aa poran~_al cr~rpres, m=e z~,s? ................. 30. Are s~,~-~c ~]ysis data p=esenr, ad c= s~]~ gas 31. If ~ ~ loc., ~-e ~ remalus of seabed ccndi~ 32. ~_~,',,',=,! r~r-~ °too O~u-! OFF-- ggo I~ /Go o~ - ii ii i _ ! 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. I I I I I I I I I I I I I I I I I I I e e Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: ConocoPhillips Alaska, Inc. Decernber19,2005 6052 1 3.5" 9.2 lb. L-80 Tubing & Liner Well: 3H-14B Field: Kuparuk State: Alaska API No.: 50-103-20092-00 Top Log IntvI1.: 5,170 Ft.(MD) Bot. Log Intvl1.: 7,972 Ft. (MD) Inspection Type: COffosive & Mechanical Damage Inspection COMMENTS: This caliper data is tied into "0" Nipple @ 7,748' (Driller's Depth). This log was run to assess the condition of the 3.5" tubing and liner with respect to corrosive and mechanical damages. The caliper recordings indicate the 3.5" tubing and liner is in good condition with respect to corrosive damage. No significant wall penetrations in excess of 20% are recorded throughout the 3.5" tubing and liner interval logged. Perforations are recorded in joint 249 of the liner (7,890' - 7,896'). No significant areas of cross-sectional wall loss or 1.0. restrictions are recorded throughout the 3.5" tubing and liner interval logged. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. A graph illustrating the correlation of recorded damage to borehole profile is included in this report. During the logging operations the caliper became hung up in GLM 3, resulting in a loss of recordings for the pup joint directly above this GLM MAXIMUM RECORDED WAll PENETRATIONS: No significant penetrations (> 20%) are recorded throughout the tubing and liner interval logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL lOSS: No significant areas of cross-sectional wall loss (> 9%) are recorded throughout the tubing and liner interval logged. MAXIMUM RECORDED ID RESTRICTIONS: No significant 1.0. restrictions are recorded throughout the tubing and liner interval logged. ~'£.¡"~¡"ilFr..) u,wnJ,;~r;~,,~~\ I Field Engineer: D. Cain Witness: V. Yoakum I Analyst: M Téihtouh ProActive Diagnostic Services, Inc. / P.O. Sœ< 1369, Stafford, TX ì7497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS(cÜmemorylog.com Prudhoe Bay Field Office Phone: 659-2307 Fax: (907) 659-2314 Iß7-JÞ3 < ~\Y V> ~p\P / 'b\)\).' \<' '-,.,' I PDS Report Overview Body Region Analysis I I December 19, 2005 MFC 24 No, 40665 169 24 M. Tahtouh Well: Field: Company: Country: Survey Date: roo! rype: rool Size: No. of Fingers: Analyst,-__~~... 3H·14B Kuparuk Conocor'hillips Alaska, In(, USA I -"~~"~"'--~_..__._~. Upper len. 1,2 ins Lower len. 1,2 ins Nom,ID ins Nom. Upset 3.5 ins I ----------- Penetration amI Damage Profile (% wall) I penetration body o 164 metal loss body 50 penetration body metal loss body 100 100 80 60 40 20 0 o to 1'% I I 10 to 20% 20 to 40% 40 to over 85~ío 85% to 10%, I ClM 3 2 93 90 o o o I Damage Configuration ( body) I 80 60 I CUv\ 4 40 I 20 o Isolated I)!ttlng ge-neral line ring hole I pOSS corrosion COIT0510n corrosion ¡ble hole I ClM 5 I Bottom of Survey = 251,1 o I I Analysis Overview page 2 I I I PDS EPORT JOINT TABULATION SHEET Pen. Pen ,v'eL)1 Min, Body ID. (Ins.) (Ins.) 164 5168 0 0.04 IS '1 291 16'1 H51 ìì 0 ....... O.lß ! ) ¡, :ìRR 166 5207 0 0.04 j 7 ) 2.85 167 5238 0.03 III 2.88 1 ('R~5269 0 0.04 1 (, I; 2~89 1 (,9 5299 (W41 (,I 2.86 170 5;335 0 0,03 j) ) 2.86 171 5364 0 0.03 11 4 2.88 17) 5395 0 (W4 Ii 4 2.88 1735426 ( 0.05 I 2 4 2.R8 174 5456 I q.0111 2.87 175 5489 0.04 I 4 2.91 176 5520 0,04 II ') 2,88 177 5550 0.05 21 (, 2.86 ¡ 78') ')81 0.04 1 ~ 2.89 1ì9 ')61( 0.031 3 2.91 180 ')642 0.041 I· 4 2.1'19 181 ')67- 0'<)41 ') 2,82 182 5705 n 11.04 IS 3 2.87 183 5736 n 0.041 ).. 2.91 184 5767 n 0.051 c¡ 1.86 185 5798 0.. 0.03 2.87 ~8f>.. ~Z n 0.ü3 2.91 1 5859 0 0.03 2,88 1'H5883 0 no:1 2.88 1. 5923 n -¡)~(M 2.92 1 5954 íi'(i(i:1 1 -¡ 2.92 1 ) 1 .')985 .. n "'¡:¡¡:Y¡- 3 2.92 1CJ1.1 H6017 n 0 ON/A PUP No Dat,~~- .~.- 192.1 6019 0 Ö n N/A CLM 3~- 1191.3 .... 6033 ~. tti O.lJI 2 2.90 PUP 192 6036 ~~ ---º---- 0.04 2.84 ShallowJ)ítting. 193 6065, (I 0.05 ) 2.84 Shallov\'J)itting. Lt. Deposits. 194 I" 6096~FF(I to,041 2.85 Shallow pitting. Lt. Deposits. r...195 1 6126 . ......... (I 1 0.0417... 6.. ~1.J3Z.....Shallow pitting. 196 6158 OTO.03 I U ..l3 2.91 Shallow pitting. I 197 1 6189 1 I ¡ I (1.05 T19T4T 2.89 1 Shallow pitting. ['198 16217 1 0 I 0.04~T15~T 3T 2.86 I... Shallow pitting. Lt. Deposits..~ , 199 I 6250 1 OOC, 1 0.04 j{) i ) 2.86 1 Shallow oittin<>. :ì00 6282 0 0.031)j 2.87 Sballow pitting, Lt. Deposits. :ìO 1 6312 0 0.04.. 1 t¡ e¡ 2.92 Shallow pitting. Lt. Deposits. :ìm 6342 0 0.03i'ìl 2.89 I Shallow oitti!w. Lt. Deposits. .203 6373 0 0.04 I") ; 2.88 Shallow pitting. Lt. Deposits. 'H' 204 6405 (I l10411; ) 2.89 1 Shallow [Jilting. Lt. Deposits. ~~_ 205 6435 0 0.04 1'7 ) 2.87 Shallow pitting. Lt. Deposits._ 206 6464 0 0.04 114 I, 2.86 Shallow pitting. Lt. DeDosits. .~.__~_ 207 6499 0 0.04 "1h ¡ 2.84 Shallow oitting. 208 6530 0 0.04 Ii 2.85 Shallow nitt¡;:;;; 2()q 6562 0 I 0.041h 2.85 Shallow!~ It ¡"'"mite )1() 6591 0 T 0.041F\ 2.91 Shallow~ I Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in I I loint No. Jt. De¡;tï~T (Ft.) I I I I I I I I I I I I I I I Well: Field: Company: Country: Survey Date: 3H-14B Kuparuk ConocoPhillips Alaska, Inc USA December 19, 2005 ~.._.~- Comments Shallow oitting. Shallov'.l!2ittÍl}g. Shallow oittínQ. Shallow pitting. ----'ili.illlow!)ittilw;. ~ Shallow illWng. U. Deposits, .~.. Lt. Depos.its. ~....~- .~.~- ..~ ~""" ~"'~- Shallow ')ittinG. Shallow Ditting. Shalk?w pitting. Lt. DeQf)sits. Shallow pitting. Lt. Deposits. Shallow pitting._Lt. Deposits. ... Shallow pitting,--_~ Shallow ')ittinO'. Shallow .,ittirw, -- -...- - ...~ ....~- ]1 ~ 11<1 ow nilt nO' I t rbn"",k ~ ha ow -;:;¡¡:;: nO' ¡ t nan,,,~,h' ~ ')i1 ow nitt nO' ~ hi) ow -;:;¡;:;:¡;)~ 'I t ~:::-,;::: ~ ')i1 ow '}íttinO'. Shallow pittinKlt Deposits, Shallow ~;.~;; Sh,}lIow l7ítting,.__....~.... Shallow pitting. Lt. Deposits. :;ballow pitti!ìg. Lt DepQ~its. -~.,~~- -~-~- ..~- -~...- I I -~ =]1 '- ~. .-.~~..- ~- ... Page 1 Damage Profile (%wall) 50 100 o w I I Body Metal Loss Body I I I I I I I I I I I I I I I I I I I PDS EPORT JOINT TABULATION S EET Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf l-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 3H-14B Kuparuk ConocoPhillips Alaska, Inc. USA December 19, 2005 r~- Jt Depth Pell. Pen. Pen. ;\Iet;"'! Min. Damage p-¡:;:~mel I Joint I No. (Ft.) ¡ Body I.D. Comments (%wall) I (Ins,) (Ins.) 0 50 100 'I 6626 [) 0.03 ~ 2.91 Shallow Dittiml. :1 6655 n I 0.03 2.86 Shallow DittinQ. Lt Deoosits. :1 '6687 () ()JJ4 2,80 Shallow oittinQ. Lt DeDo~~~ " I ".."'~"~.~ , 1 6719 (104 2.84 Shallow DittÍlw. '1 6749 0.04 2,89 Shallow DittinQ. II! I ------ '1( 6ìì8 0.04 2.91 Shallow oittinQ. « ¡ 6814 ( 0.04 " 2.90 Shallow DittinQ. ; 218 6842 n 0.04 4 2.87 Shallow pitting. LtDepositâ,~,,~~.. I 219 68ì2 n 0.04 IS \ 1.87 Shallow oittilw. Lt Deno_~t~'m___~~~~ .. 220 6903 () 0.04 16 '"7 2.89 Shallow Dittilw. ; 121 6916 () 0.04 17 6 2,90 Shallow DittìnQ. II! 222 6965 n 0.04 17 7 2.90 Shallow nittÍlm. « 222.1 6998 () O,O~ . Iß 4 2,8(~ PUP )ittinQ rs 222.2 7004 0 0 () () _J'liiL "' ClM 4 (latch @I :OQL, _^M_~"'M~.'_ 222.3 7010 0 0.04 17 6 2.89 PUP Shallow DittinQ. 224 7017 {) 0.04 i7 9 2.86 Shallow DittinQ. Lt. DeDosits. ".~" I 224 7056 0 0.04 14 \ 2.85 Shallow corrosion. Lt Deposits. ')') r. 7079 0 0.04 IS 41 2.82 I Shallow pitting. LtDeQosits. ~~.} "' -- I 226 7114 0 fI+:i j 2,85 227 7143 0 : 1---1.?8 ìl76 () t~~I~æ:)ittiI1Q' I 229 ì206 PI 0.03 14 i !2~_ --------------- _.. _ ~M______~~M~_ 240 7239 0 0.01. ~'H~ " ~J14 ) .231 .... ì270 () om ') 2.87 242 TI99 U I 0,0.5 19 6 2.87 ... , 233 7329 () 0.04 17 4 2.83 corrosion. Lt. DeDosits. I 244 7357 () 0.05 19 4 2.85 Shallow corrosion. I I I ')'")/:" 7391 n 0.04. 14 4 2..86 ""~ba1!.o\vÇ<)ffosioll. Lt. Deposits~~m._ I ~,L) 246 7424 ( 0.04 Ii J 2.79 Shallow corrosion. Lt. DeDosiK 237 7453 ( 0.04 I 4 2.81 Shallow corrosion. I 248 7485 0,03 -.. I 9 2.89 corrosion, Lt DeDosits. 249 7515 ( 0.04 I (, 2,89 corrosion. 240 7544 0 0.04 11 j 2.91 Shallow corrosion, 241 7575 0.04 I 4 2,87 Shallow corrosion. Lt. DeDosits. '4 7607 0.04 I ) 2.86 Shallow Ditting. Lt. Deposits. '4 7641 0.03 I (¡== 2ß..C)~ Shallow oittinQ. Lt. '4 7674 0.03 I 2.91 2' .1 7699 0.04 1 j j 2.84 PUP Shallow It. 2' .2 ìì05 o {) (I N/A CLM 5 (Latch @ 3:001 ~44:,i . 7711 {) we 2.88 PUr' Shallow Lt. 245 .ZZIL .." , (J 0.04 7 4 2.86m Shallow corrosion. 145.1. ìì47 4 o {) 0 2.75 D Nìnnle 246 7750 () 15 4 2.86 Shallow corrosion .~_....~ '_M~~ -I 246.1 7787 () o () 2.99 SEAL 246.2 7800 0 0 0 () 4.00 LINER HANi:;m .... 247 7824 () ~ 0.03 11 6 2.88 248 7856 (). ) om 13 ) 2.82 Shallow Ditting. Lt. DeDosits. 249 7888 0.19 76 7 2.91 Perforation In'c",,·,1 IIUIIiIl 250 7917 .11Ql í! '5 2.87 251 7955 0,02 11 \) 2.84 Slight Bend. Body Metal Loss Body Page 2 I I Pipe: Body Wall: Upset Wall: NominaII.D.: I PDS EPORT JOINT TABULATION SH 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: I I I I I I I I I I I I I I I I Page 3 3H-14B Kuparuk ConocoPhìllips Alaska, Inc. USA December 19, 2005 Comments Body Metal Loss Body I I I I I I °RODUCTlON (0-6039. OD:7.000, Wt26.00) I I I I I I I I Perf 1 (7884-7686) I I Perf (8172-8182) A-SAND FRAC I (8172-8187) Perf (8212-8222) I RETAINER (8223-8224, OD:3.500) I I e KRU 3H-14B . - . API: 501032009202 1 Well T vpe: 1 PROD Anole (â) TS: 44 deo (â) 8018 - SSSV Type: TRDP I Orig 14/19/2005 Angle @ TD: 34 deg @ 8450 -----;--~'~."'- " ---- Completion: 1 Annular Fluid: Last w/o: 6/16/2005 Rev Reason: TAG,PullFRAC -""~-,. . Sleeve, PERF Reference Log: 137.5' RKB Ref Log Date: '''''[8St Update: l17f2T2005 -- Last Tag: 17961 ~ Last Date: 9/3012005 Max Hole 1 Description , Size TOD 1 Bottom TVD Wt Grade Tim:,-ªª- CONDUCTOR ",,,- 16.000 0 115 115 62.50 H-40 WELD SURFACE 9.625 0 3455 3002 36.00 J·55 BTC -. PRODUCTiON ~ Toòü- 0 ." 6039 4848 26.00 J·55 BTC LINER -_.~ ^^~~ 5.500 6039 7925 6007 15.50 L-80 HYDRIL511 LINER 3.500 7780 8450 8450 9.30 L-80 HYDRIL511 Tubing String - Size Top I Bottom I TVD I Wt I Grade 1 Thread 3.500 0 1 7780 I 5916 I 9,30 1 L·80 I ModEUE8rd Interval TVD lone Status Ft SPF Date TVDe Comment 7884· 7886 5981 . 5982 2 4 5/18/2005 IPERF Shot TBG punch hoies (9) 7886 - 7888 5982 - 5984 ' 2 4 5/13/2005 IPERF Shot TBG punch holes (9) 8147·8157 6165 . 6173 A-3 , 10 6 1017/2005 APERF 2.5" PJ 2506, 60 deg phase 8172·8187 6184 - 6196 A-2 15 6 8/9/2005 APERF 2.5" HSD, 60 deg phase 8212·8222 6215 . 6223 A-l 10 6 10/7/2005 APERF 2.5" PJ 2506, 60 deo phase .. 8250· 8254 6245 - 6248 A-1 4 6 5/13/2005 SOZ 2506 PF chgs, 60 deg I Intarval : 8/~~~~òstA~SANDT~~~c-" 1 Comment I 8172 - 8187 I H? f\f\fHf: 16/20 CARBOLlTE IGa1 lift 1St MD TV!) Man Man Type V Mfr V Type VO!) Latch Port TRO Data Vlv I Mfr I Run Cmnt -: , 2967 2661 CAMCO KBUG·M -"._-------~- ~ GLV 1.0 BK-5 0.156 1335 9/7/2005 4824 3977 CAMCO KBUG·M GLV 1.0 BK-5 0.156 1335 9/7/2005 6022 4836 CAMCO KBUG-M OV 1.0 BK-5 0.313 0 9/7/2005 7004 5460 CAMCO KBG-2-9 DMY 1.0 DK-1 0,000 0 6/15/2005 7706 5872~G-2'9 DMY 1.0 DK-1 0.000 0 6/20/2005 DeDth TVD TVDe DescriDtion ID 2329 2208 SLEEVE FRAC SLEEVE 80" OAL, 2.857" NO GO· set 8/14/20Q.L _.~~ _ 2.300 2329 2208 SSSV CAMCO TRMA-10E SSSV set 6/16/2005 2.810 7748 5897 NIP CAMCO 'D' NIPPLE wiNO GO PROFILE set 6/16/2005 -.--- ""~--~-------_. 2.750 7789 5922 SEAL BAKER SEAL ASSEMBLY (3 SETS) set 6/16/2005 2.990 Depth TVD Type DescrilJ non 10 6039 4848 PACKER BAKER CPH LINER TOP PACKER ¡:; LINER 4.500 6050 4856 HANGER BAKER HMC LINER FOR 5' JNER 4.000 7780 5916 PACKER BAKER 'HR' SZP I INFR FOR ~" I IN H :i <;00 BAKER HMC LINER HANGER FOR 3.5" LINER SVB RETAINER set 5/13/2005 3.500 2.690 --~·I ··1 9/16/1999 WAIVER ED WELL: IA x OA COMMUNICATION-----' 4/2112005 WELL SIDETRACKED FOR SECOND TIME-----· 4/29/2005 TREE: 3-1/8" CIW GEN 3 5K..-----·- -...- ._- TREE CAP CONNECTION: 5" OTIS --~~-~..__._._._-- _~m..._.'_,_..,. ..._........_..~~ RECEIVED '~laska Oil & Gas Cons. ,, ~~ommi~.on Anchorage VERIFICAT]:ON bISTING , , ********************** 90 900 000 000 :9:o ~oo $~i ooo°°° ooo ooo gTO 000 000 ~T~HE I :ii00:) 3Z.lg 3,~V3 3dA3, J, lNll ** 90~033~ NOZLYNBOJN! 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