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184-041
7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 12-26 Install K valve redesign Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 184-014 50-029-21071-00-00 11470 Conductor Surface Intermediate Production Liner 9229 80 2497 10923 840 11426 20" 13-3/8" 9-5/8" 7" 9191 29 - 109 28 - 2526 26 - 10948 10630 - 11470 29 - 109 28 - 2526 26 - 8775 8497 - 9229 none 470 2670 4760 7020 none 1490 5380 6870 8160 10948 - 11235 5-1/2" 17# 13cr 24 - 10528 8775 - 9027 Structural 5-1/2" Baker S3 10477 , 8410 10477 , 8410 2129 , 2129 Bo York Operations Manager David Bjork David.Bjork@hilcorp.com (907)564-4672 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final 13.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028331 HES K valve 24 - 8410 2129 , 2129 322-100 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2021 Submit Within 30 days or Operations Sr Res Eng: By Grace Salazar at 9:33 am, Mar 29, 2022 Digitally signed by Bo York (1248) DN: cn=Bo York (1248), ou=Users Date: 2022.03.28 16:11:59 -08'00' Bo York (1248) ACTIVITYDATE SUMMARY 3/17/2022 ***WELL FLOWING ON ARRIVAL*** (sssv maintenance) PULL 4-1/2" HES K-VALVE (s/n = K-41A) ON 5-1/2" X-LOCK FROM 2,129' MD. SET 4-1/2" HES K-VALVE (s/n = K-05A - 233 psi @ 60*) ON 5-1/2" R-LOCK AT 2,129' MD. ***WELL FLOWING ON DEPARTURE, NOTIFIED DSO OF WELL STATUS*** Daily Report of Well Operations PBU 12-26 ect Well History File' Covei~l~ge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. RESCAN DIGITAL DATA [] Diskettes, No. [] Other, No/Type Color items: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: BY: ~BREN VINCEN3; ~ARIA LOWELL DATE: Project Proofing BY: BEVERLY BREN~) SHERYL MARIA LOWELl. OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) Logs of various kinds Other Is/ DATE: 7~ ' o Scanning Preparation x 30 = + = TOTAL PAGES ~--~) ' BY: BEVERLY BREN (~ Production Scanning Stage BY: Stage 2 BY; (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO DUal.ri'Y, GRAYSCALE OR COLOR IMAGES) PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: YES /~ NO IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: ~ NO RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S/ General Notes or Comments about this file: Quality Checked (done) 10/25/02Rev3NOTScanned.wpd • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Plugged Q - Abandoned gi - Suspended ❑ 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development 0 - Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5 Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband.: September 16, 2012 184 - 041 / 312 - 240 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 April 1, 1984 / 50 029 - 21095 - 00 . 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 155' FNL, 1450' FEL, Sec. 33, T11 N, R9E, UM April 8, 1984 ✓ 2F - 11 Top of Productive Horizon: 8. KB (ft above MSL): 125' RKB 15. Field /Pool(s): 1338' FSL, 1122' FEL, Sec. 34, T11 N, R9E, UM GL (ft above MSL): 92' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 1004' FSL, 769' FEL, Sec. 34, T11 N, R9E, UM 9351' MD / 5907' TVD . Kupuruk River Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 517782 y 5948729 Zone 4 10160' MD / 6488' TVD ADL 25657• TPI: x - 523407 y - 5944957 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 523762 y 5944624 Zone 4 2010' MD / 1844' TVD ' 2583 18. Directional Survey: Yes ❑ No III i 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) na (ft MSL) 3825' MD / 2869' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re drill /Lateral Top Window MD/TVD none not applicable 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 30' 110' 30' 110' 24" 225 sx Cold Set II 9.625" 36# J -55 29' 3810' 29' 2860' 12.25" 1 050 sx AS III, 780 sx Class G 7" 26# J -55 29' 10137' 29' 6471' 8.5" 350 sx Class G, 250 sx AS I 24. Open to production or injection? Yes ❑ No El If Yes, list each 25. TUBING RECORD Interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET ( MD/TVD) na perfs squeezed off D 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No EI DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED NOV 2 8 2012 9345' -9532' 7 bbls of 15.8# Neat cement AOGCC 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) suspended Date of Test Hours Tested Production for OIL -BBL GAS -MCF WATER -BBL CHOKE SIZE GAS - OIL RATIO Test Period - -> Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) Press. 24 -Hour Rate -> 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No is Sidewall Cores Acquired? Yes ❑ No 0 If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. NONE SCANNED JUL 0 8 2093 Fw..j NOV V Lt: i» Form 10 -407 Revised 10/2012 CONTINUED ON REVERSE V/ I . S bmit original only CP il I- TO k5 29. GEOLOGIC MARKERS (List all formations and mils encountered): 37 FORMATION TESTS NAME MD TVD Well tested? ❑ Yes Q No If yes, list intervals and formations tested, Permafrost - Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom 3825' 2869' needed, and submit detailed test information per 20 AAC 25.071. not applicable N/A Formation at total depth: not applicable 31. LIST OF ATTACHMENTS Summary of Daily Operations, schematic 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Gary Eller @ 263 -4172 Email: J.Garv.Ellera conocophillips.com Printed Namee - /4 7 mar Gantt ^ Title: CTD Supervisor Signat re � y i t et -g r I-6 Phone 263 -4021 1/ - Z1—I2 Date \`�2.kpt \2 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10 -404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service wells: Gas injection, water injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 • a KUP 2F -11 ConocoPhillips if Well Attributes Max Angie & MD TD Alaska Inc Wellbore API /UWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) Conoaithe Bps 500292109500 KUPARUK RIVER UNIT PROD 61.50 5,950.00 10,160.0 ` ° ' Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date ••• Well Cantle: - 2F t, 1016/2012 7.5743 AM SSSV: TRDP 45 10/5/2011 _ Last WO: 33.01 4/10/1984 Schematic - Actual Annotation Depth (ftKBI End Date Annotation Last Mod ... End Date Last Tag: SLM 9,558.0 6/22/2012 Rev Reason: ADD CEMENT ninam 10/7/2012 HANGER, 24 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd I CONDUCTOR 16 15.062 30.0 110.0 110.0 62.50 H - 40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.921 29.3 3,810.0 2,860.3 36.00 J - 55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 1 AIMS PRODUCTION 7 6.276 29.0 10,1372 6,470.7 26.00 J -55 BTC Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 31/2 2 I 23 I 9 , 3 73.9 5,921.2 9 I J -55 EUE8RD Completion Details Top Depth (ND) Top Inc! Nomi... W Top (ftKB) (ftKB) ( °) Item Description Comment ID (In) III 23.7 23.7 -0.29 HANGER FMC GEN II TUBING HANGER 3.500 II 2,009.8 1,843.6 47.43 SAFETY VLV BAKER FVL SAFETY VALVE 2.810 C0NDUC7oR, 7,483.0 4,839.2 59.12 GASLIFT MMH FMHO 2.875 30 -110 9,330.1 5,893.8 51.89 PBR BAKER PBR 3.000 9,343.8 5,902.3 51.79 PACKER BAKER FHL RETRIEVABLE PACKER 3.000 SAFETY VLV, 2.010 1 --- o 1 9,360.9 5,912.9 50.22 NIPPLE CAMCO D NIPPLE NO GO 2.750 9,372.4 5,920.2 50.15 SOS VANN GUN RELEASE 1.810 Other In Hole Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth GAS LIFT, )1. � (TVD) Top Inc! 2.122 Top (ftKB) (ftKB) ( °) Description Comment Run Date ID (In) - - --� 9,351 5,906.5 50.27 CEMENT TAG BOTTOM @ 9558 SLM 8/30/12. PUMPED 15.8 PPG 9/16/2012 6.276 NEAT CLASS G CEMENT. TAG TOC @ 9351 9/19/12. 9,354 5,908.4 50.26 TBG PUNCH 6 SPF, 60 DEG, BIG HOLE CHARGES 7/2/2012 2.992 9,757 6,189.5 42.30 FISH 5" Vann Gun 272.67 Iong 5/4/1984 SURFACE. 41 L. Perforations & Slots 29 -3,810 Shot -- 7 Top (ND) Btm (ND) Dens GAS LIFT, _ Top (ftKB) Btm (ftKB) (MB) (ftKB) Zone Date (sh.. Type Comment 4,931 9,376 9,378 5,922.5 5,923.8 Lower Kalubik, 4/30/1984 4.0 SQZ'd Squeezed; 4 "Dresser Atlas 2F -11 GASLIFT, 7,483 9,451 9,464 5,971.8 5,980.4 C-4, 2F -11 12/23/1987 8.0 APERF 21/8" EnerJet 9,506 9,508 6,008.9 6,010.2 UNIT B, 2F -11 4/30/1984 4.0 SQZ'd Squeezed; 4" Dresser Atlas i 9543 9,564 6,034.6 6,049.4 A -5, 2F -11 5/4/1984 4.0 IPERF 5" Geo Vann Tubing G GAS9 8 9,585 9,618 6,064.1 6,086.7 A -4, 2F -11 5/4/1984 4.0 IPERF 5" Geo Vann Tubing G 9,630 9,640 6,095.6 6,103.0 A -4, 2F -11 5/4/1984 4.0 IPERF 5" Geo Vann Tubing G Cement Squeezes - - - - - -- Top Depth Btm Depth PBR, 9,330 - (ND) (TVD) Top (ftKB) Btm (868), (ftKB) (ftKB) Description Start Date Comment PACKER, 8,344 �� 9,376.0 9,378.0 5,9225 5,923.8 Cement Squeeze 4 /30/1984 9,506.0 9,508.0 6,0089 6,010.2 Cement Squeeze 4 /30/1984 Notes: General & Safety ill End Date Annotation TBG PUNCH, t 7/16/2007 NOTE: ELINE CALIPER VERIFIED HISTORICAL TIGHT SPOT @ 9600, POSSIBLE CSG DMG 9,354 ^ 8/8/2009 NOTE: ENCOUNTERED OBSTRUCTION © 6400' SLM is 10/12/2010 NOTE: View Schematic w/ Alaska Schematic9.0 NIPPLE, 9,301 5/15/2012 NOTE: GLM @ 7583' ELMD on caliper log run 5/15/2012. This is 100' deeper than tbg detail on 5/3/84. It 909.9.372 SOZd, 9,3769,378 Cement, 9,376 CEMENT, 8,351 " APERF, 9,451 -9,464 l,m SOZ'Q 9,506 -9,508 - Cement, 9,506 IPERF, 9,5439,584 CEMENT, 9,351 Mandrel Details _ - Top Depth Top Port IPERF, (TVD) Inc' OD Valve Latch Size TRO Run 9,585 -9,616 ( Stn Top (ftKB) MB) (1 Make Model (in) Sew Type Type (in) (psi) Run Date Com... 1 2122.3 1,916.6 51.59 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 7/6/2012 9,630 -9,640 IPERF, 2 4,930.9 3,520.0 53.50 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 7/6/2012 3 7,483.0 4,839.2 59.12 MMH FMHO 1 GAS LIFT DMY 'BK 0.000 0.0 7/5/2012 4 9,288.1 5,868.5 53.92 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 7/7/2012 FI514.9,757 ' 1 PRODUCTION. 29- 10,137 TD (2F -11), 10,160 2F -11 Pre -Rig Well Work Summary DATE SUMMARY • • 5/12/12 BRUSH & FLUSH/ GAUGE TO 2.80" TO D -NIP @ 9361' RKB, DRIFT WITH 2.62" DMY WHIPSTOCK TO TAG KNOW OBSTRUCTION @ 9549' SLM. NO SAMPLE. READY FOR E -LINE. 5/15/12 RIH W/ EXTENDED REACH 24 -ARM CALIPER. LOG FROM 9527' TO SURFACE. WELL LEFT SHUT IN AND TURNED OVER TO DSO. 5/16/12 LOG 7" CASING FOR CEMENT BOND FROM 9530' TO TUBING TAIL. LOG SHOWS WELL BONDED 7" CASING. WELL LEFT SHUT IN AND TURNED OVER TO DSO. 5/17/12 RIH WITH GYRO DATA LOGGING TOOLS AND PERFORM A GYRO SURVEY FROM SURFACE TO 9510' INCLUDING A COLLAR LOCATOR. MEASURE SHUT IN BOTTOM HOLE PRESSURE SURVEY @ DEPTHS OF 9550' & 9403' PRESSURE / TEMP @ 9550' = PRESS 2087 / TEMP 157 PRESSURE / TEMP © 9403' = PRESS 2046 / TEMP 156 6/22/12 LOCATED TBG TAIL © 9364' SLM / 9372' RKB. TAGGED © 9558' SLM. MEASURED BHP © 9542' SLM: 2176 PSI. COMPLETE. 6/28/12 PERFORM GYRO SURVEY TO 9525' ELM, HAD TROUBLE GETTING DOWN WITH 1.8" O.D. GYRODATA GYRO TOOL DUE TO DEVIATION. HAD TO RUN AT HIGH SPEEDS TO GET TO MAX DEPTH. 6/30/12 PERFORMED 24 -ARM CALIPER FROM 9562' TO TUBING TAIL. LOG CORRELATED TO CBL DATED 4 -20 -1984. 7/2/12 PERFORATE w/ 2', 6SPF, 60 DEG PHASING GUN LOADED WITH HALLIBURTON BH CHARGES IN THE MIDDLE OF 10' PUP JOINT LOCATED ABOVE THE CAMCO D NIPPLE @ 9361'. PERFORATIONS FROM 9354' - 9356'. 7/4/12 BRUSH & FLUSH SCSSSV @ 2009' RKB, PERFORM NO FLOW CLOSURE TEST FOR 30 MIN;PASS, IN PROGRESS. 7/5/12 PULLED GLVs @ 4930' & 7483' RKB, SET DV @ 7483' RKB, IN PROGRESS. 7/6/12 PULLED GLV @ 2122' RKB, SET DVs @ 2122' RKB & 4930' RKB, ATTEMPTED TO PULL OV @ 9288' RKB ( POSS. DEBRIS AROUND LATCH ) AND INADVERTENTLY PULLED DV © 4930' RKB. IN PROGRESS 7/7/12 PULLED OV © 9288' RKB, SET DV @ 4930' RKB, PUMPED 203 BBLS DIESEL DN IA, SET DV @ 9288' RKB, PERFORM MITIA TO 2500;PASS, LEFT LRS TO MIT OA TO 1800 PSI ( PASSED ) SEE ATTACHED PUMP REPORT FOR INJECTIVITY TEST. READY FOR CTU PENDING RESULTS OF INJECTIVITY TEST. 8/26/12 TAGGED FILL @ 9569' RKB ( EST. 71' OF FILL ) W/ 2.5 CENT. AND SAMPLE BAILER. READY FOR SBHP. 8/30/12 ATTEMPT TO PERFORM STATIC AND SAT DOWN © 9024' SLM. DRIFTED WITH 5' x 2.5" BLR TO 9558' SLM; MEASURED BHP ( 3124 psi ) @ 9550' RKB. 8/31/12 T POT - PASSED. T PPPOT- PASSED. IC POT - PASSED. IC PPPOT- FAILED. TORQUED IC LDS TO 500FT #'S; UNABLE TO MAINTAIN PRESSURE ON IC PO. 9/13/12 MILLED D- NIPPLE AT 9361' RKB, DRY DRIFTED TBG TO TAG AT 9600' CTMD. WELL FREEZE PROTECTED TO 2000' ND. JOB IN PROGRESS. 9/14/12 PERFORMED SQUEEZE WITH 15.8 PPG NEAT CLASS G CEMENT. PLACED APPROXIMATELY_ 7 BBLS OF CEMENT BEHIND PIPE. ACHIEVED 1500 PSI SQUEEZE PRESSURE. WASHED TOP OF CEMENT DOWN TO 9540' KB. MAINTAINED 1:1 RETURNS THROUGHOUT JOB. FREEZE PROTECTED TO 2000' ND. BLED IA TO 0 PSI BUILT UP TO 56 PSI IN 10 HOURS. JOB IN PROGRESS. (PIPE PINHOLED ON REEL 2700' FROM END) 9/15/12 LOCATED TBG TAIL @ 9365' SLM, 9372' RKB. TAGGED TOC @ 9525' SLM. IN PROGRESS. 9/16/12 SET 17 POUND NEAT CLASS G KICK OFF PLUG FROM 9532 TO 9345' KB. ACHIEVED 1200 PSI SQUEEZE PRESSURE INSTANTLY. SQUEEZED NO CEMENT BEHIND PIPE. FREEZE PROTECTED WELL. JOB COMPLETE. 9/19/12 OBTAIN CORR. OFF OF GLM @ 9288' RKB. TAGGED TOC © 9351' RKB. OBTAIN GOOD P.T. ON TBG. TO 1500 PSI, BLEED TO ZERO AND MONITORED FOR 30 MIN. FUNCTION TESTED SSSV. READY FOR E -LINE. 9/23/12 PERFORMED WEATHERFORD WRP SET. CORRELATED LOG TO TUBING TALLY AND SET WRP MID - ELEMTN @ 9320'. CCL STOP DEPTH = 9309.1; CCL TO MID ELEMENT = 10.92'. 9/25/12 (AC): TREE & TUBING HEAD ADAPTER SWAP. T PPPOT- PASSED. WILL RETURN PRESSURE TEST TREE & IA. 9/26/12 (AC EVAL) MIT TREE - PASSED @ 3000PSI; MITOA- PASSED @ 1800PSI; DDT -OA- INCONCLUSIVE. OPENED V. NO LEAKS DISCOVERED ON TREE. 9/27/12 PULLED WRP @ 9312' SLM. S FLUID PACK IA. READY FOR BPV. 9/27/12 (PRE -CTD) PT & DD TEST ON MV (PASSED), SV (PASSED), SSV (PASSED), SSSV (PASSED), OPEN SSSV. pi 2 ‘`) 7G WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 8, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 NN Ep N\.. 4 9 2013. RE: Multifinger Imaging Tool (MIT): 2F -11 5a Run Date: 10/7/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2F -11 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50- 029 - 21095 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907-273-3535 klinton.wood @halliburton.com Date: 10 2 Signed: 1 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. September 28, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 %MME° jU.. 0g2.D1` RE: Plug Setting Record: 2F -11 Run Date: 9/23/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2F -11 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 21095 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com Date: 0 Z 2 Signed: ��� • L2 t .. • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. July 3, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 % WED JUL ': g RE: Perforating Record: 2F -11 Run Date: 7/2/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2F -11 Digital Data (LAS), Digital Log file 1 CD Rom 50- 029 - 21095 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: _ . Signed: / ', r /V; • ; ..;y, WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. July 2, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 SCANNED JUL RE: Multifinger Imaging Tool (MIT) : 2F -11 Run Date: 6/30/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2F -11 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50- 029 - 21095 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: • Signed: i w - ._? • ks,t_o,t WELL LOG TRANSMITTAL • To: Alaska Oil and Gas Conservation Comm. May 18, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 SCANNED JUL 0 9 2013 RE: Radial Cement Bond Log: 2F -11 Run Date: 5/16/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2F -11 Data in LAS format, Digital Log Image files 1 CD Rom 50- 029 - 21095 -00 Cement Bond Log 1 Color Log 50- 029 - 21095 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: t (o Signed: 2� X65 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. May 17, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 SrRHtiEtt ,lU Z i3 RE: Multifinger Imaging Tool (MIT) : 2F -11 Run Date: 5/15/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2F -11 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50- 029 - 21095 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: 42. Signed: RALIA-c13 • • ZILE CIT AELASEA, SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COM1tIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Dan Venhaus CTD Engineer 041 ConocoPhillips Alaska, Inc. P.O Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk Oil Pool, 2F -11 Sundry Number: 312 -240 Dear Mr. Peirce: JUL 9 2012 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount G I Commissioner DATED this ( day of July, 2012. Encl. STATE OF ALASKA Y"v _ . . ALIA OIL AND GAS CONSERVATION COM4ION a• 1 V APPLICATION FOR SUNDRY APPROVALS '1 20 AAC 25.280 1. Type of Request: Abandon r Rug for Redrill j . Perforate New Pool r Repair w ell r Change Approved R -ogram r Suspend I- Rug Perforations �' Perforate fl Rill Tubing r Time Extension r Operational Shutdow n r Re -enter Susp. Well f°- Stimulate r Alter casing j— Other: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory f '" 184 -041 - 3. Address: Stratigraphic r Service ("" 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 " 50- 029 - 21095 -00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No l - 2F -11 - 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25657 - Kuparuk River Field / Kuparuk River Oil Pool - 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10160 6488 10047' 6404' 9757' Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 110' 110' SURFACE 3781 9.625 3810' 2860' PRODUCTION 10108 7 10137' 6471' Perforation Depth MD ( 9386 -9378, 9451 -9464, Perforation Depth TVD (ft): 5923 -5924, 5972 -5980, Tubing Size: I 1E r Tubing MD (ft): 9506 -9508, 9543 -9564, 9585 -9618, 9630 -9640 6009 -6010, 6035 -6049, 6064 -6087, 6096 -6103 3.5 1 72 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) JU ,t / Z PACKER - BAKER FHL RETRIEVABLE PACKER MD= 9344 TVD= 5902 9 2012 SSSV - BAKER FVL SSSV MD =2010 TVD =1844 12. Attachments: Description Summary of Proposal pt 13. Well Class after proposed work: ® ��✓ p� Detailed Operations Program r BOP Sketch r Exploratory r Development 17 ` Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 7/16/2012 Oil r Gas r WDSPL r Suspended go • 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Dan Venhaus @ 263 -4372 Printed Name Dan Venhaus Title: CTD Engineer Signature / Phone: 263 -4372 Date t -21- / Z Commission Use Only Sundry N� r Ay° Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test I'` Mechanical Integrity Test r Location Clearance r Other: 3000 pi " , o P tt' s l "�r,'cf'iii 9 l-e;/vf 1`"rcl -fa fib, F-' 25,11 Z (e)(i) f'r PivC Subsequent Form Required: /" t' 1 f 5 /O --4 � — APPROVED BY 7 ' r� Approved by: 1/44:7 COMMISSIONER THE COMMISSION Date: vi d fil z- »z.o ORIGINAL Submi in Duplicate ii. • • KRU 2F -11 CTD Summary for P1ug ing Sundry (10 -403) Summary of Operations: Well 2F -11 is a Kuparuk A- sand /C -sand production well equipped with 31/2" tubing and 7" production casing. Three proposed A -sand CTD laterals will increase reservoir exposure and probe the southern periphery of 2F pad. Prior to drilling, the existing perfs in 2F -11 will be squeezed with cement to provide a means to kick out of the 7" casing. A cement retainer will be set above a known obstruction in the casing. between the A and C sand perforations. The A -sand perforations will be permanently abandoned by bullheading cement through the • retainer and the C -sand perfs will be squeezed above the retainer. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1) to plug the perfs in this manner. After plugging off the existing perfs with cement, a pilot hole will be drilled through the cement to top of cement retainer. A mechanical whipstock will be set in the pilot hole at the planned kickoff point. The 2F -11A sidetrack will exit the 7" casing at 9503' MD and will target the upper A4 sand south of the existing well with a 4000' lateral. The hole will be completed with a 2%" slotted liner to the TD of 13,500' MD with an aluminum billet at 9900' MD. The 2F -1 1AL1 lateral will kick off from the aluminum billet at 9900' MD and will target the A5 sand above the first lateral with a 3650' lateral. The hole will be completed with a 2%" slotted liner to the TD of 13,500' MD with an aluminum billet at 9850' MD. The 2F -1 1AL2 lateral will kick off from the aluminum billet at 9850' MD and will target the lower A4 sand below the first lateral with an 955' lateral. The hole will be completed with a 21/2" slotted liner to the TD of 10,805' MD with the final liner top located just inside the 31/2" tubing at 9360' MD. ' r' ` 646 �O Wt(( W� i!r le b (P 5bileef ft'"' 4 cK i "tai CTD Drill and Complete 2F -11A Laterals: August 2012 c '1(4144 1 , Pre -CTD Work r o acto (€5" MJ l j ►. k, , fr�r�cd. 1L�rw Au 1. RU slickline. Install dummy GLV's. Load & test IA and OA 2. Perform injectivity test. /e Ptt4. J 3. RU e -line. Perf holes in 31" tubing tail at 9354' MD. RD e -line. /// '4/e 4. RU coil. Mill out D- nipple at 9361' to 2.80" ID. 5. RU coil. Set inflatable cement retainer in 7 "@ 9530' MD. Squeeze A -sand perfs with cement thru retainer. Unsting from retainer, squeeze C -sand perfs above retainer. Leave cement top at 9345' MD above tubing tail perfs. RD coil. 6. RU slickline. Tag top of cement. RD slickline. r .t /5 0 1 , S , 7. Prep site for Nabors CDR2 -AC, including setting BPV 2 h V-s n o h Rig Work A; h / ttt l � /` P A- 1. MIRU Nabors CDR2 -AC rig using 2" coil tubing. NU 7- 1/16" BOPE, test. 2. 2F -11A Sidetrack (upper A4 sand, south) a. Drill 2.80" high -side pilot hole through cement to 9530' MD'. b. Drift pilot hole with whipstock dummy c. Set whipstock at 9503' MD with high -side orientation. d. Mill 2.80" window at 9503' MD. '\ e. Drill 2.70" x 3" bi- center lateral to TD of 13,500' MD f. Run 21/2" slotted liner with an aluminum billet from TD up to 9900' MD P Page 1 of 2 June 26, 2012 FINAL , ' • • 3. 2F -11 AL 1 Lateral (A5 sand, south) a. Kick off aluminum billet at 9900' MD b. Drill 2.70" x 3" bi- center lateral to TD of 13,500' MD c. Run 2 slotted liner with an aluminum billet from TD up to 9850' MD 4. 2F -11AL2 Lateral (Lower A4 sand, south) a. Kick off of the aluminum billet at 9850' MD b. Drill 2.70" x 3" bi- center lateral to TD of 10,805' MD c. Run 2 slotted liner from TD up to 9360' MD, up inside the 31" tubing tail 5. Freeze protect. Set BPV, ND BOPE. RDMO Nabors CRD2 -AC. Post -Rig Work 1. Pull BPV 2. Obtain static BHP. Install GLV's. 3. Put well on production Page 2 of 2 June 26, 2012 FINAL KUP 2F -11 ConocoPhillips Well Attributes Max Angle & MD TD Alaska, Inc Wellbore API /UWI Field Name Well Status !nci (°) M D (ftKB) Act Btm (ftKB) 500292109500 KUPARUK RIVER UNIT PROD 61.50 ( 5,950.00 10,160.0 Comment H2S (ppm) Date Annotation End Date KB (k) Rig Release Date Well conr9: - 2F 6/23/2012 910 34 AM SSSV: TRDP 45 10/5/2011 Last WO: 33.01 4/10/1984 Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date CasinLast Tag: g SLM Strings 9,558.0 6/22/2012 Rev Reason: TAG ninam 6/23/2012 HANGER, 24 "�• _- i' !) Casing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) _. String Wt... String ._ String Top Thrd t CONDUCTOR 16 15.062 30.0 110.0 110.0 62.50 H WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.921 29.3 3,810.0 2,860.3 36.00 J - 55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 29.0 10,137.2 6,470.7 26.00 J -55 BTC Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING I 31/2 I 2 .992 23.7 I 9,373.9 I 5,921.2 9 I J - 55 EUE8RD 'Completion Details Top Depth (TVD) Topincl Nomi... Top (ftKB) (ftKB) (1 Item Description Comment ID (in) 23.7 23.7 -0.29 HANGER FMC GEN II TUBING HANGER 3.500 2,009.8 1,843.6 47.43 SAFETY VLV BAKER FVL SAFETY VALVE 2.810 7,483.0 4,839.2 59.12 GASLIFT MMH FMHO 2.875 coNDUCroR,_. 9,330.1 5,893.8 51.89 PBR BAKER PBR 3.000 30.770 9,34a8 5,902.3 51.79 PACKER BAKER FHL RETRIEVABLE PACKER 3.000 9,360.9 5,912.9 50.22 NIPPLE CAMCO D NIPPLE NO GO 2.750 SAFETY VLV, _: 9,372.4 5,920.2 50.15 SOS VANN GUN RELEASE 1.810 2,010 i %`. Other In Hole ireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top Inc! Top (ftKB) (ftKB) 11 Description Comment Run Date ID (in) GAS LIFT. _ c 9,757 6,189.5 42.30 FISH 5" Vann Gun 272.67 long 5/4/1984 2,122 ` Perforations & Slots 4 Shot Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (ch... Type Comment , 9,376 9,378 5,922.5 5,923.8 LowerKalubik, 4/30/1984 4.0 SQZ'd Squeezed; 4" Dresser Atlas 2F -11 SURFACE, 1 l 9,451 9,464 5,971.8 5,980.4 C-4, 2F -11 12/23/1987 8.0 APERF 2 1/8" EnerJet zs - 3,eio 9,506 9,508 6,008.9 6,010.2 UNIT B, 2F -11 4/30/1984 4.0 SQZ'd Squeezed; 4" Dresser Atlas GAS LIFT, 9,543 9,564 6,034.6 6,049.4 A -5, 2F -11 5/4/1984 4.0 IPERF 5" Geo Vann Tubing G 4,931 t• - . 9,585 9,618 6,064.1 6,086.7 A-4, 2F -11 5/4/1984 4.0 IPERF 5" Geo Vann Tubing G 9,630 9,6401 6,095.6 6,103.01A -4, 2F -11 5/4/1984 4.0 IPERF 5" Geo Vann Tubing G GASLIFT, 7,483 _-. Cement Squeezes Top Depth Btm Depth (TVD) (TVD) Top (ftKB) Btm (ftKB) (ftKB) (MB) Description Start Date Comment GAS 912 8 c . -; 9,376.0 9,378.0 5,922.5 5,923.8 Cement Squeeze 4/30/1984 -- 9,506.0 9,508.0 6,008.9 6,010.2 Cement Squeeze 4/30/1984 '7 a.,«.`,:. 0,11:: , c y :1a,, \a;; End Date Annotation __. 7/16/2007 NOTE: ELINE CALIPER VERIFIED HISTORICAL TIGHT SPOT @ 9600', POSSIBLE CSG DMG PBR, 9.330 7/28/2007 NOTE: TREE IS ONLY RATED FOR 3000PSI PACKER, 9344 ' 8/8/2009 NOTE: ENCOUNTERED OBSTRUCTION @ 6400 SLM ' G �� 10 " " /1 " 2//010 NOTE: View Schematic w/ Alaska Schematic9.0 12 NOTE: GLM @ 7583' ELMD on caliper log run 5/15/2012. This is 100' deeper than tbg detail on 5/3/84. NIPPLE, 9,361 a.. ' �,`( -- .._reef- hones 93 5 5O5, 9372 SOZ'Q _ _ 8,3789,378 - Cement, 9,378 APERF, 9,451 -9,464 - SOZ'd, `° _ 9,506-9,508 -'� -. i Cement, nt, 9,508 -' ..Z_ 6 r0 ,e vii" r-e .f , r + .-t - t 9, 3o IPERF, 1= _HE 9,5439,564 vrmi IPERF. III Mandrel Details 9,585 -9,618 Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) ( °) Make Model (in) Sery Type Type ( (psi) Run Date Com... IPERF, 1 2,122.3 1,916.6 51.59 MMH FMHO 1 GAS LIFT GLV BK 0.156 1,351.0 9/10/2001 9,630.9,640 2 4,930.9 3,520.0 53.50 MMH FMHO 1 GAS LIFT GLV BK 0.156 1,325.0 9/10/2001 3 7,483.0 4,839.2 59.12 MMH FMHO 1 GAS LIFT GLV BK 0.188 1,338.0 9/10/2001 FISH, 9,757 --411110 4 9,288.1 5,868.5 53.92 MMH FMHO 1 GAS LIFT OV BK 0.250 0.0 9/10/2001 PRODUCTION, 29- 10,137 1 TD, 10,160 2F -11A Proposed CTD Sidetrack , 3 -1/2" Baker FVL @ 2010' MD .. ■ 3 -1/2" 9.3# J -55 EUE 8rd Tubing to surface 16" 62# H -40 in. shoe @ 110' MI MD 3 -1/2" Camco FHMO gas lift mandrels @ 2122, 4931, 7483, 9288 9 -5/8" 36# J -55 shoe @3810'MD Baker PBR @ 9330' MD (3" ID) 1!=1 Baker FHL packer @ 9344' MD (3.0" ID) • _, 3 -1/2" Camco D landing nipple @ 9361' MD (2.75" min ID, to be • Squeeze perfs ,' - 1 1 milled out to 2.80" pre -rig) 9376' - 9378' MD 3 -1/2" tubing tail @ 9372' RKB 2.80" pilot hole , through cement I C -sand perfs 9435' 9489' MD == ITop of Whipstock @ 9503' MD Squeeze perfs 9506' - 9508' MD a IBP @ 9530 to serve as — I 2F -11 AL1 (A5 sand) bottom for cement � 3" openhole, TD = 13500' MD \ 2 -3/8" slotted liner Liner top @ 9850' MD A -sand perfs 9543' • . • 9564' MD 9585' - 9618' MD 9630' - 9640' MD Cement/ \ 2F -11A (upper A4 sand) .1 Fill. TD =13500 MD Potential Casing Alum billet @ 9900' MD damage @ 9600'MD Unknown i 2F -11 AL2 (lower A4 sand) due to TD = 10550'! MD inability to I Liner top @ 9360' MD work past obstruction. 7 "26 #J -55 shoe @ 10137' MD • • Page l of 1 Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS (IPBRD) Type Work Code in RBDMS 1. hen a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). 2. On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accu racy. Thanks, Steve D. file: //F: \Dai1y_Document Record \Procedures_Instructions \FW INTENT PLUG for RE- DRI... 4/6/2012 • • • Colombie, Jody J (DOA) From: Eller, J Gary [ J.Gary.Eller @conocophillips.com] Sent: Friday, July 06, 2012 11:33 AM To: Ferguson, Victoria L (DOA) Cc: Schwartz, Guy L (DOA); Colombie, Jody J (DOA) Subject: RE: 2F -11 status Victoria — Thanks much for your help. I sincerely apologize for rushing you folks. -Gary From: Ferguson, Victoria L (DOA) F mailto :victoria.ferquson@alaska.govl Sent: Friday, July 06, 2012 11:29 AM To: Eller, J Gary Cc: Schwartz, Guy L (DOA); Colombie, Jody J (DOA) Subject: [EXTERNAL]RE: 2F -11 status Gary, You have verbal approval to proceed with 2F -11 (Sundry 312 -240) — plug perforations. Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave, Ste 100 Anchorage, AK 99501 Work: (907)793 -1247 victoria.ferquson aC�alaska.gov From: Eller, J Gary jmailto: J. Gary.Eller(aconocophillips.com]. Sent: Friday, July 06, 2012 11:25 AM To: Ferguson, Victoria L (DOA) Subject: RE: 2F -11 status Victoria — As we discussed, 2F -11 is equipped with a 3000 psi MAWP tree so we'll test the coiled tubing BOPE to 3000 psi. -Gary From: Ferguson, Victoria L (DOA) j mailto :victoria.ferquson©alaska.gov] Sent: Friday, July 06, 2012 11:07 AM To: Eller, J Gary Subject: [EXTERNAL]FW: 2F -11 status What will you be testing the BOPEs to? From: Colombie, Jody J (DOA) Sent: Friday, July 06, 2012 10:57 AM To: Ferguson, Victoria L (DOA) Subject: FW: 2F -11 status 1 • • • fyi From: Eller, J Gary f mailto :J.Gary.Eller@ conocophillips.coml Sent: Friday, July 06, 2012 10:50 AM To: Colombie, Jody J (DOA) Cc: Allsup- Drake, Sharon K Subject: RE: 2F -11 status Jodie — Gary Eller with ConocoPhillips here. As you know, we're trying to prep 2F -11 for CTD operations with Nabors CDR2. That rig has been knocking things out quicker than expected; the laterals we just finished drilling in 2K -14 took 7 days less time than expected. Bottom line is that were having trouble keeping ahead of them, so we'd like to be able to cement 2F -11 on Monday (July 9) if at all possible. -Gary Eller ConocoPhillips CTD Engineer From: Allsup- Drake, Sharon K Sent: Friday, July 06, 2012 10:40 AM To: Eller, 3 Gary Subject: FW: 2F -11 status Gary — See note below. Thank you, Sharon 263 -4612 From: Colombie, Jody J (DOA) fmailto :iody.colombie0alaska.govl Sent: Friday, July 06, 2012 10:39 AM To: Allsup- Drake, Sharon K Cc: Ferguson, Victoria L (DOA) Subject: [EXTERNAL]RE: 2F -11 status Sharon, Samantha is on vacation. I need a justification from the engineer. 403 says you don't need until 7/18/12. Thanks Jody From: Allsup- Drake, Sharon K [mailto:Sharon.K. Allsup- Drake@conocophillips.coml Sent: Friday, July 06, 2012 10:35 AM To: Colombie, Jody J (DOA) Subject: 2F -11 status Jody — I called Samantha yesterday afternoon and left a message but haven't heard back yet. Can you tell me the status of 2F -11? We will definitely need it before this weekend. Thank you, Sharon 263 -4612 2 • n chilli Co ocoP ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 23, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~` Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • r ~+'~`~~ ko ~~ ~ I' Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped October 16, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, ~~ ~~. ~~~~~ ~~~r rt ~ 20~i8 MJ Lov and ConocoPhillips Well Integrity Projects Supervisor ,, • ~ ConocoPhillips Alaska lnc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field r)atR± 10/22/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2F-02 183-188 20" NA 20" NA 2.21 10/16/2008 2F-03 183-187 20" NA 20" NA 2.23 10/16/2008 2F-05X 196-203 7" NA 7" NA 1.7 10/16/2008 2F-06 184-019 18" NA 18" NA 1.72 10/16/2008 2F-11 184-041 .20" NA 20" NA 2.22 10/16/2008 ZF-13 183-156 12" NA 12" NA 6.8 10/16/2008 2F-14 183-159 7" NA 7" NA 4.25 10/16/2008 2F-18 196-178 5" NA 5" NA 11.9 10/16/2008 2F-19 196-201 6" NA 6" NA 1.7 10/16/2008 06/08/07 -.-...,.. ." Schlumbergel' NO. 4286 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 1 ], 20m . ~NtD JDN 1 4 20D7 ¡\3r¡e¡!;i¡~ on~j (;18~1 COfj~. G\,!\,jfim¡~î!!or¡ Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~v Field: Kuparuk }CJ4-0~1 Well Job# Log Description BL Color CD Date 2L-321 11629010 MULTI-FINGER CASING INSPECTION 05/12/07 1 2C-16 11629008 PPROF/LDL 05/10/07 1 2G-11 11638863 PRODUCTION PROFILE 05/05/07 1 1 C-125 N/A MEM INJECTION PROFILE 05/05/07 1 2D-13 11638861 PRODUCTION PROFILE 05/03/07 1 2D-08 11638862 PRODUCTION PROFILE 05/04/07 1 2G-09 11638864 PRODUCTION PROFILE 05/06/07 1 2N-349A 11629004 RST/ WFL 05/04/07 1 3H-19 11638867 PRODUCTION PROFILE 05/09/07 1 1Q-10 11628771 MEM PRODUCTION PROFILE 05/03/07 1 1E-11 11629012 INJECTION PROFILE 05/14/07 1 2L-321 11665439 USIT 05/25/07 1 2V -OBA 11629013 PMIT 05/15/07 1 1 J-160 11632704 PRODUCTION PROFILE 03/19/07 1 1H-07 11665436 SBHP SURVEY 05/20/07 1 2F-11 11665434 PRODUCTION PROFILE 05/19/07 1 2X-07 11665433 INJECTION PROFILE 05/18/07 1 1B-01 11665432 PRODUCTION PROFILE 05/17/07 1 2X-01 11637338 INJECTION PROFILE 05/15/07 1 2Z-29 11665438 PRODUCTION PROFILE 05/22/07 1 1 H-22 11637339 INJECTION PROFILE 05/16/07 1 1 Y -11 11632708 INJECTION PROFILE OS/23/07 1 1G-03 11637336 INJECTION PROFILE 05/14/07 1 1A-23 11665443 MEM PRODUCTION PROFILE OS/29/07 1 1F-08 11665435 SBHP SURVEY OS/20/07 1 1J-170 11632709 INJECTION PROFILE OS/24/07 1 10-109 N/A INJECTION PROFILE 05/13/07 1 2M-24 11665440 SBHP SURVEY OS/28/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . · ~'" STATE OF ALASKA "-"' ALAS. OILAND GAS CONSERVATION COMN,._ ION REPORT OF SUNDRY WELL OPERATIONS !. Operations performed: Operation Shutdown _ Stimulate__~ Plugging Pull tubinc~ _ Alter casincj _ Repair well _ Other _ 2. Name of oPerator: 5. Type of Well: 6. Datum of elavafion (DF or KB feet): ARCO Alaska, Inc. Develop. ment X. 127' RKE 13. Address: Exploratory ___, 7. Unit or Property: P.O. Box 100360 Stratagrapic __~ Anchorage, AK 99510-0360 Service __~ Kuparuk River Unit 4. Location of well at surface: 8. Well number: 155' FNL, 1450' FEL, Sec 33, 'I'11N, R9E, UM 2F-11 At top of productive interval: 9. Permit number/approval number: 1387' FSL, 1415' FEL, Sec 34, T11N, R9E, UM 84-41 At effective depth: 10. APl number: 1180' FSL, 1110' FEL, Sec 34 T11N, R9E, UM 50-029-21095-00 Af total depth: 11. Field/Pool: 1160' FSL, 1091' FEL, Sec 34, T11 N, RgE, UM Kuparuk River Field / OII Pool 12. Present well condition summary Total Depth: measured 10137 feet Plugs (measured) None true vertical . 6460 feet Effective Depfl measured 10047 feet Junk (measured) None true vertical 6394 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 110' 16" 225 Sx Cold Set II ' 110' 110' SurfaCe 3786' 9-5/8" 1050 Sx AS III & 3810° 2855' 780 Sx Class G Production 10113' 7" 350 Sx Class G & 10137' 6460' 250 Sx AS I Uner Perforation Depth measured 9376'-9378';9451 '-9464';9506'-9508';9543'-9564'; 9585'-9618'; 9630'-9640' true vertiCal 5911'-5912';5961'-5970';5998'-6000';6024'-6039';6054'-6077';6086'-6093' · Tubing (size, grade, and measured depth) 3.5", 9.3 Ib/ft, J-55 @ 9374' Packers and SSSV (type and measured depth) ..,.'.:: ;: ~. , ..~.. -;..;. Packer: Baker FHL @ 9344'; SSSV: Baker FVL @ 2010' 13, Stimulation or cement squeeze summary Fracture stimulate "A" sand on 5/28/98, Intervals ITeated (measured) 9543' -9564' Treatment description including volumes used and final pressure Pumped 169,209 lbs of 16/20, & 12/18 ceramic prolopant into formation, fp was 5900 psi. 14. Represenfitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf water-Bbl Casing Pressure Tubing Pressure Prior to well operation 621 498 222 1296 138 Subsequent to operation 642 603 283 1086 143 15. Attachments MIT form 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations __X Oil_X Gas _ Suspended _ Service _ 17. I hereby~certity that the foregoing is true and correct to the best of my knowledge. Signed/1[/~/~/~~ Title: Production Engineering Supervisor Date ~/~/~ SUBMIT IN DUPUCA~,~ Form 10-404 Re~ .8 _ __ ~=LL SERVICE REPORT 2F-11(4-1)) WELL JOB SCOPE JOB NUMBER 2F-11 FRAC, FRAC SUPPORT 0609981313.4 UNIT NUMBER DATE O5/28/98 DAY 4 FIELD ESTIMATE DAILY WORK 'A' SAND RE-FRAC. OPERATION COMPLETE I SUCCESSFUL I KEY PERSON ~ Yes 0 No ~ Yes 0 No DS-YOKUM AFC# ICC# I DAILY COST ACCUM COST KD2215 230DS28FL $150,411 $182,918 InitiaITbg IFinalTbg I Initial IA I Final IA I Initial CA IFinal CA ITTL Size 0PSII 200PSII 500PSII 500PSII 200PSII 600PSII 0.000 " SUPERVISOR SMITH Signed Min ID I Depth 0.000" I 0 FT DALLY SUMMARY IPUMPED 'a' SAND RE'FRAC' SCREENED OUT 29 BBLS' INTO 10 PPA STAGE' 170'000# IN THE FORMATION' LEFT24,690# IN THE WELLBORE. TIME LOG ENTRY 07:35 HELD SAFETY MEETING. 07:50 PRESSURE TESTED TREATING LINE TO 10,500#. 08:23 START BREAKDOWN STAGE, 30 BPM 120 BBLS. 50# DEL. XL GW. TBG=7432 CSG=2771 08:36 START SCOUR STAGE, 15 BPM 1 PPA 16/20 75 BBLS. TBG=5365 CSG=2716 08:42 START CONDITIONING STAGE, 15 BPM 50 BBLS 50# DEL. XL GW. TBG=5429 CSG=2755 08:45 START SCOUR STAGE, 15 BPM 2 PPA 16/20 75 BBLS. TBG=5452 CSG=2792 08:50 START FLUSH, 15 BPM 50 BBLS 50# DEL. XL GW. TBG=5550 CSG=2797 08:53 START FLUSH 15 BPM 130 BBLS SW. TBG=5520 CSG=2271 09:02 SHUTDOWN, ISIP=2457 09:40 START DISPLACEMENT, 5 BPM 95 BBLS 50# DEL. XL GW. TBG=3451 CSG=2616 09:58 INCREASE RATE TO 15 BPM, START DATAFRAC. 5 BBLS 50# DEL. XL GW. TBG=3529 CSG=2631 09:59 START FLUSH STAGE. 15 BPM 100 BBLS 50# DEL. XL GW. TBG=5905 CDG=2838 10:05 SHUTDOWN ISIP=2673 10:40 START PAD, 5 BPM 95 BBLS 50# DEL. XL GW. TBG=3529 CSG=2631 10:57 START PAD, 15 BPM 405 BBLS 50# DEL. XL GW. TBG=5680 CSG=2786 11:24 START 2 PPA 16/20 STAGE 200 BBLS 15 BPM 50# DEL. XL GW. TBG=5493 CSG=2761 11:39 START 6 PPA 12/18 STAGE 800 BBLS 15 BPM 50# DEL. XL GW. TBG=5182 CSG=2720 12:31 START 10 PPA 12/18 STAGE 29 BBLS 15 BPM 40# DEL. XL GW, SCREENED OUT. TBG=6787 CSG=2785 SECURED WELL, BLED CASING TO 500#. RIG DOWN. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $500.00 $1,440.00 APC $8,000.00 $22,500.00 ARCO $0.00 $700.00 DOWELL $140,411.40 $146,231.40 HALL I B U RTO N $0.00 $ 5,947.00 LITTLE RED $1,500.00 $6,100.00 3:OTAL FIELD ESTIMATE $150,411.40 $182,918.40 ARCO Alaska, In¢ Post Offic;.~ ~ .,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 28, 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. WELL %q-'ql., 2F-11 <~-I 5=1 --2F- 14 'g'q-I'Zl 2G-02 ~-q---2U-01 ACT.ION Stimulate Stimulate Stimulate Stimulate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Sr. Engineer Kuparuk Petroleum Engineering RECEIVED SEP 2 9 t99 .0il.& Gas Cons. gommiss'~o~ ~chorage ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany AR38-6003-C STATE OF ALASKA ' /.- ~ OIL AND GAS ~RVATION COMMI,.,,.,~ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate ~ Plugging Perforate _ Pull tubing Alter casing Repair well Other__ 5. Type of Well: 6. Datum elevation (DF or KB) 2. Name of Operator ARCO Alaska. Inc. _ 3. Address P. O. Box 100360, Anchorage, AK 99510 Development ~; Exploratory _ RKB 127' Stratigraphic _ 7. Unit or Property name Service _ Kuparuk River Unit 8. Well number 2F-11 9. Permit number/approval number 84-41 10. APl number 5g-029-2109500 11. Field/Pool Kuparuk River Oil Pool 4. Location of well at surface 155' FNL, 1450' FEL, SEC. 33, T11N, R9E, UM At top of productive interval 1387' FSL, 1415' FEL, SEC. 34, Tll At effective depth 1180' FSL, 1110' FEL, SEC. 34, T11 At total depth 1160' FSL, 1091' FEL, SEC. 34~ Tll 12. Present well condition summary Total Depth: measured Plugs (measured) true vertical N, R9E, UM N, R9E, UM Nr R9E~ UM 10137' feet 6460' feet Effective depth: measured 10047' feet Junk (measured) true vertical 6394' feet Casing Length Size Structural Conductor Surface 1 1 0' 1 6" Intermediate 381 0' 9 5/8" Production 1 01 3 7' 7" Liner Perforation depth: measured 9451 '-9464', true vertical 5961 '-5970', Cemented 780 SX AS III 350 SX CLASS G 9543'-9564', 6024'-6039', Tubing (size, grade, and measured depth) 3 1/2:J-55 9.3 #/FT., EUE 8RD IPC, 9374' Packers and SSSV (type and measured depth) SSSV: BAKER FVL 2010', PACKER: BAKER FHL 9344' 9585'-9618', 6054'-6078', 13. Stimulation or cement squeeze summary Measured depth True vertical depth 110' 110' 3810' 2855' 10137' 6460' 9630'-9640' 6086'-6094' RECEIVED 14. Fracture stimulation Intervals treated (measured) ,~,JasJ(a 0il & Gas Cons. Commission C and A sands 9451'-9640' MD Anchorage Treatment description including volumes used and final pressure Placed 24M lbs 16/20 and 173M lbs 12/18 carbolite in formation. Final pressure 7900 psi. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 900 /800 0 800 150 1200/~900 50 1000 160 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 Sicjned' ~~ ~° ~ Title Senior Engineer Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company WELL IPBDT .OF-l~ ~NTRA-C~oR REMARKS ..... FIELD - DISTRICT- STATE OPERATION AT REPORT TIME WELL SERVICE REPORT DAYS DATE I I [ 7_?..~ '.. /'ZY3: !3~, ~" 13tz' /Lo8 ' !S/~, 20/3 .~i KE~tlVE~ i--] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather ITemP'Report o~. I Chill Factor I Visibility .... JWind Vel. ISigne~ ~ STATE OF ALASKA ALASKA OILAND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIOI I 1. Type of Request: Operation 'Shutdown Pull tubing Alter casing Stimulate X Plugging Perforate __ 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 Location of well at surface 155' FNL, 1450' FEL, Sec. 33, T11N, R9E, At top of productive interval 1387' FSL, 1415' FEL, Sec. 34, T11N, At effective depth 1180' FSL, 1110' FEL, Sec. 34, T11N, At total depth 1160' FSL, 1091' FEL, Sec. 34~ T11N, 12. Present well condition summary Total Depth: measured true vertical UM R9E, UM R9E, UM R9E, UM 1 01 3 7' feet Plugs (measured) 6460' feet 6. Datum elevation (DF or KB) RKB 127' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2F-11 Producer 9. Permit number/approval number 84-41 ./ .~- 10. APl number 5o-029-2109500 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 1 0047' feet Junk (measured) true vertical 6394' feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 110' 16" 3810' 9-5/8" 780SxA.S. III 1 01 3 7' 7" 350 Sx Class "G" Measured depth True vertical depth 110' 110' 3810' 2855' 10137' 6460' measured 9451 '-9464', 9543'-9564', 9585'-9618', 9630'-9640' MD true vertical 5960'-5969', 6025'-6039', 6053'-6077', 6086'-6093' TVD Tubing (size, grade, and measured depth) 3 1,2", J-55 9.3 #/ft., EUE 8rd ,PC, 9374' !~i~J,~'~V ~ Packers and SSSV (type and measured depth) SSSV: Baker FVL 2010', Packer: Baker FHL 9344' 13. Stimulation or cement squeeze summary 14. Hydraullically fractured well with gelled water and 16/20 Carbolite proppant. ~.'-,!~.sl<~. Oil & Gas r;ons. - - Intervals treated (measured) ~...~, Treatment description including volumes used and final pressure Pumped 106300 #16/20 Carbolite, 1479 bbl gelled water; last pressure = 4900 psi Reoresentative Daily Averaoe Production or Iniection Data - Oil-Bbl Gas-Mcr 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 X 427 444 0 1200 psi 113 psi 1363 1502 0 1400 psi 178psi 16. 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. Si~ned ~'~.,~ ~ ~)~~~gTitle Sr. Operations Engineer Form 10-404 Re~ 06/15/88 SUBMIT IN DUPLICATE ARCO Alaska, Inc Subsidiary of Atlantic Richfield Company WELL ~ITRACTOR REMARKS WELL SERVICE REPORT JOPERATION AT REPORT TIME /.s"-.s" ? .. · /&,z. [-'1 CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather I Temp' I Chill Fact°r I Visibility IWind Vel'Report OF "F miles 1. Type of Request: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Operation Shutdown__ Stimulate X Plugging Perforate Pull tubing Alter casing Repair well Pull tubing 5. Type of Well: Development X Exploratory _ Stratigraphic _ 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 155' FNL, 1450' FEL, Sec. 33, T11N, R9E, UM At top of productive interval 1387' FSL, 1415' FEL, Sec. 34, T11N, R9E, UM At effective depth 1180' FSL, 1110' FEL, Sec. 34, T11N, R9E, UM At total depth 1160' FSL, 1091' FEL, Sec. 34, T11N, R9E, UM 1 0137' feet 6460' feet 1 0047' feet 6394' feet Size Cemented 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Other -- Casing Length Structural Conductor Surface I 1 0' Intermediate 3 81 0' Plugs (measured) 6. Datum elevation (DF or KB) RKB 127' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2F-11 Producer 9. Permit number/approval number 84-41 /~/z. ~ '~- ,., ~-_ 10. APl number 5o-02~)-2109500 11. Field/Pool Kuparuk River Oil Pool Junk (measured) I 6" 9-5/8" 780 Sx A.S. III Measured depth True vertical depth Production 1 01 3 7' 7" 350 Sx Class "G" Liner Perforation depth: measured 9451 '-9464', 9543'-9564', 9585'-961 8', 9630'-9640' MD 5960'-5969', 6025'-6039', 6053'-6077', 6086'-6093' TVD Tubing (size, grade, and measured depth) 3 1/2", J-55 9.3 #/ft., EUE 8rd IPC, 9374' Packers and SSSV (type and measured depth) 110' 3810' 1 01 37' true vertical 110' 2855' 6460' ~,k.~~' ,~ : ....... SSSV: Baker FVL 2010', Packer: Baker FHL 9344' 13. Attachments Description summary of proposal _ Hydraulically fracture the A & C Sand with 105000 # of 1 14. Estimated date for commencing operation July 4, 1989 16. If proposal was verbally approved Name of approver Date approved Detailed operation program _ BOP sketch_ 6/20 Mesh proppant and Gelled Water 15. 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. Si~ned ./~ ~-'~ ~ ./~.~_-f~ai,tz'~ Title Sr. Operations Engineer FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test_ Location clearance__ Mechanical Integrity Test_ Subsequent form require 10-//~'z/ ORIGINAL SIGNED By LONNIE C. SMITH IApproval No. Approved Copy Returned Approved by the order of the Commission Commissioner Date Form 10-403 Rev 5/03/89 SUBMIT IN TRIPLICATE ' Messrs Lyden and Wade' June 27, 1989 Page 2: Kuparuk Well 2F-11 'A' Sand Re-Fracture Procedure I. Obtain a 24 hour well test. Install Sonic Sand Detector (SSD) probe. . 1 MIRU Slickline unit. RIH with tubing end Iocator and tag fill. Pull GLV's at 2122', 4931', 7483', and 9288' and run DVs. RIH with Standing Valve and set in Camco 'D' nipple. Pressure test tubing to 4500 psi to ensure DVs are set. RIH and pull SV. 4. RDMO Slickline. If less than 50 feet of rathole is discovered during the pre-frac wireline operations, a CTU cleanout may be required. Consult with Operations Engineering to determine if the CTU is necessary. 5. MIRU fracture equipment. Install "Tree Saver". o . Carry out all quality control procedures (Onsite Operations Engineering). The specific procedures will depend on the vendor selected. Check Carbo-Lite for fines due to excessive handling. Obtain a sample of the Carbo-Lite and the gelled water with breaker and from the pad and slurry stages. Record the proppant weight before and after the treatment. Pump fracture treatment per the attached schedule. Record the 5, 10, and 15 minute pressures following the ISIP. Expected wellhead treating pressure: WHTPE = 4200 psig Fracture Gradient = 0.70 psi/ft (6000' TVD) Tubing Friction -- 300 psi/1000 ft (9374' MD) @25 BPM * If treating pressure during the job exceeds 6000 psi, reduce rate to a minimum of 15 BPM. If pressure exceeds 6500 psi, shut down job and confer with Engineering. 8. Rig down frac equipment. Follow attached flowback schedule. 1 After well has completed flowback, obtain 24 hour well test. Contact Operations Engineering for a new gas lift design when necessary. KUPARUK WELL 2F-11 'A° & 'C' SAND REFRACTURE PUMP SCHEDULE GELLED WATER FRACTURE TREATMENT 6/20189 ST, aC-& FLUID CLF_AN VCLUME PUMP RATE PROP. ~. PROPPANT PROPPANT WT DIRTY VOLUME HIT PERFS DESCRIPTION BBI_S BPM PIG DESCRIPTION LBS STG/CUM BBLS 1 GW PRE-PAD 200.0 25 0 - - ............................................... SHUT DOWN FOR ISIP 2 GWPAD 675.0 25 0 16/20 M CARBO-LITE 0 3 GWw/2 PPG 59.7 25 2 16/20 M CARBO-LITE 5018 4 GWw/4 PPG 63.8 25 4 16/20 M CARBO-LITE 10712 5 GWw/6 PPG 67.2 25 6 16/20 M CARBO-LITE 1 6940 6 GWw/8 PPG 66.5 25 8 16/20 M CARBO-LITE 22357 7 GW w/10 PPG 62.5 25 1 0 16/20 M CARBO-LITE 26237 8 GW w/12 PPG 45.8 25 1 2 16/20 M CARBO-LITE 23076 9 SUCK DIESEL FLUSH 83.0 +SV 2 5 0 - - 0 0 2OO/ 2OO 85 675/ 875 285 65/ 940 960 75/ 1015 1025 85/ 1100 1100 90/ 1190 1185 90/ 1280 1275 70/ 1350 1365 83/ 1433 1435 16/20 M CARBO-LITE = 104340 IRS TOTAL GELLED WATER = 1314.1 BI~.S TOTAL MUSOL = 0.0 BI~.S TOTAL DIESEL = 49.9 BBLS TOTALSUCK DIESEL= 83.0 BBLS +SV Stage 1 is Gelled Water. Stage 2 is Gelled Water with 40 lbs/lO00 gal silica flour and enough breaker for a 6 hour break. Stages 3 through 8 are Gelled Water with 6 hour breaker and WITHOUT silica flour. Stages 1 through 4 will also contain 5% Arctic Diesel by volume for additional fluid loss control. Stage 9 should include a volume adjustment for surface equipment between the wellhead and densitometer. Stages 3 through 9 are scheduled to pump at 25 BPM. However, if treating pressure dictates, decrease to 20 BPM. This job is intentionally underflushed by 2 bbl. The blender tub should be bypassed at flush. All fluids should be maintained to at least 100 F on the surface. REC IV L J U L - 7 Alsska Oi! & ~a~ Oons. KUPARUK WELL 2F-11 'A' & 'C' SAND REFRACTURE PUMP SCHEDULE GELLED WATER FRACTURE TREATMENT 6~20/89 STAC-E. FLUID Ct. EAN VOLUME PUMP RATE PROP. CONC. PROPPANT PROPPANT WT DIRTY VOLUME HIT PERFS DESCRIPTION BBLS B PM PPG DESCRIPTION LBS STG/CUM BBLS 1 GW PRE-PAD 200.0 2 5 0 - - ............................................... SHUT DOWN FOR ISIP 2 GWPAD 675.0 25 0 16/20 M CARBO-LITE 0 3 GWw/2 PPG 59.7 25 2 16/20 M CARBO-LITE 5018 4 GWw/4 PPG 63.8 25 4 16/20 M CARBO-LITE 1071 2 5 GWw/6 PPG 67.2 25 6 16/20 M CARBO-LITE 1 6940 6 GWw/8 PPG 66.5 25 8 16/20 M CARBO-LITE 22357 7 GW w/10 PPG 62.5 25 1 0 16120 M CARBO-LITE 26237 8 GW w/12 PPG 45.8 25 1 2 16/20 M CARBO-LITE 23076 9 SLICK DIESEL FLUSH 83.0 +SV 2 5 0 - - 0 0 2O0/ 2OO 85 675/ 875 285 65/ 940 960 75/ 1015 1025 85/ 1100 1100 901 1190 1185 90/ 1280 1275 70/ 1350 1365 83/ 1433 1435 16/20 M CARBO-LITE = 104340 IRS TOTAL GELLED WATER = 1314.1 BBLS TOTAL MUSOL = 0.0 BBLS TOTAL DIESEL = 49.9 BBLS TOTAL SUCK DIESEL = 83.0 BBLS +SV Stage 1 is Gelled Water. Stage 2 is Gelled Water with 40 lbs/lO00 gal silica flour and enough breaker for a 6 hour txeak. Stages 3 through 8 are Gelled Water with 6 hour breaker and WITHOUT silica flour. Stages 1 through 4 will also contain 5% Arctic Diesel by volume for additional fluid loss control. Stage 9 should include a volume adjuslment for surface equipment between the wellhead and densitometer. Stages 3 through 9 are scheduled to pump at 25 BPM. However, if treating pressure dictates, decrease to 20 BPM. This job is intentionally underflushed by 2 bbl. The blender tub should be bypassed at flush. All fluids should be maintaJned to at least 100 F on the surface. KUPARUK WELL 2F-11 'A° & 'C' SAND REFRACTURE PUMP SCHEDULE GELLED WATER FRACTURE TREATMENT 6/20/89 ST,~C~ FLUID CLEAN VOLUME PUMP RATE PROP. ~. PROPPANT PROPPANT WT DESCRIPTION BBLS BPM PPG DESCRIPTION LBS DIRTY VOLUME HIT PERFS STG/CUM BBLS 1 GW PRE-PAD 200.0 25 0 - - ............................................... SHUT DOWN FOR ISIP 2 GWPAD 675.0 25 0 16/20 M CARBO-LITE 0 3 GWw/2 PPG 59.7 25 2 16/20 M CARBO-LITE 5018 4 GWwl4 PPG 63.8 25 4 16/20 M CARBO-LITE 1071 2 5 GWw/6 PPG 67.2 25 6 16120 M CARBO-LITE 16940 6 GWw/8 PPG 66.5 25 8 16/20 M CARBO-LITE 22357 7 GW w/10 PPG 62.5 25 1 0 16/20 M CARBO-LITE 26237 8 GW w/12 PPG 45.8 25 1 2 16120 M CARBO-LITE 23076 9 SUCK DIESEL FLUSH 83.0 +SV 25 0 - - 0 0 200/ 200 85 675/ 875 285 65/ 94O 96O 75/ 1015 1025 85/ 1100 1100 90/ 1190 1185 90/ 1280 1275 7O/ 1350 1365 83/ 1433 1435 16/20 M CARBO-LITE = 104340 LBS TOTN. GELLED WATER = 1314.1 BBLS TOTAL MUSOL = 0.0 BBLS TOTN. DIESEL = 49.9 BELLS TOTALSUCK DIESEL= 83.0 BBLS +SV Stage 1 is Gelled Water, Stage 2 is Gelled Water with 40 lbs/1000 gal silica flour and enough breaker for a 6 hour break. Stages 3 through 8 are Gelled Water with 6 hour breaker and WITHOUT silica flour, Stages 1 through 4 will also contain 5% Arctic Diesel by volume for additional fluid loss control. Stage 9 should include a volume adjustment for surface equipment between the wellhead and densitometer. Stages 3 through 9 are scheduled to pump at 25 BPM. However, if treating pressure dictates, decrease to 20 BPM. This job is intentionally underflushed by 2 bbl. The blender tub should be bypassed at flush, All fluids should be maintained to at least 100 F on the surface. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown Pull tubing Alter casing Stimulate __ Plugging Perforate X 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 155' FNL, 1450' FEL, Sec. 33, T11N, R9E, UM At top of productive interval 1387' FSL, 1415' FEL, Sec. 34, T11 N, At effective depth 1180' FSL, 1110' FEL, Sec. 34, T11 N, At total depth 1160' FSL, 1091' FEL, Sec. 34, T11 N, R9E, UM R9E, UM R9E, UM 12. Present well condition summary Total Depth: measured 10 true vertical 64 1 37' feet 60' feet Plugs (measured) 6. Datum elevation (DF or KB) RKB 127' 7. Unit or Property name Kuparuk River Unit 8. Well number ;~F-11 Producer 9. Permit nur. nber/approval ~4-41 ,/~--:z~ I10. APl number 5o-029-21 09500 11. Field/Pool Kuparuk River Oil Pool feet number Effective depth: measured 10047' feet true vertical 6394' feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 110' 16" 3810' 9-5/8" 780 SxA.S. III 1 01 3 7' 7" 350 Sx Class "G" measured 9451'-9464', true ve~ical 5960'-5969', 9543'-9564', 6025'-6039', Measured depth True vertical depth 110' 110' 3810' 2855' 10137' 6460' 9585'-9618', 6053'-6077', 9630'-9640' 6086'-6093' MD Tubing (size, grade, and measured depth) 3 1/2", J-55 9.3 Cf/ft., EUE 8rd IPC, 9374' Packers and SSSV (type and measured depth) SSSV: Baker FVL 2010', Packer: Baker FHL 9344' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description includin~l volumes used and final pressure 14. Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 29O 154 0 45O 299 152 0 500 125 145 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 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. SUBMIT IN DUPLICATE Alaska, Inc. Subsidiary of Atlantic Richfield Company REMARKS WELL SERVICE REPORT /OPERATION AT REEORT TIME CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK WeatherITemp'Report °FI I Chill Fact°r i Visibility j OF miles Wind Vel. .. .~EMARKS CONTINUED: DESCRIPTION DAILY ACCUM. TOTAL CAMCO ' 'offs _~ ~,~ ? ,,SCHLUMBERGER ,.. '/[/~,~.. Od ' : ;' ~ .. I~RESSER-ATLAS DOWELL HALLIBURTON ARCTIC COIL TUBING _ FRACMASTER . B. J. HUGHES Roustabouts Diesel Methanol ' ' Supervision Pre-Job Safety Meeting .. AFE TOTAL FIELD ESTIMATE ~'o STATE OF ALASKA ALASK. ,)IL AND GAS CONSERVATION COMM,.~SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator : ARCO Alaska, Inc, 3. Address P.0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 155' FNL, 1450' FEL, Sec. 33, T11N, R9E, UM At top of productive interval 1387' FSL, 1415' FEL, Sec. 34, T11N, R9E, UM A~[:~'¢~ti~t~e, PT110''-"- ---'- "- FEL, Sec. 34, TllN, RgE, UM A~Lt%t~d~t~, 1091' FEL, Sec. 34, T11N, R9E, UM 5. Datum elevation (DF or KB) RKB 127' 6. Unit or Property name Kuparuk River Unit 7. Well number 8. Permit number 50-- feet 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 10137' 6460' feet feet 10047' 6394' feet feet Casing Length Size Structural 110' 16" Conductor Surface 3810' 9-5/8" Intermediate 10137 ' 7" Production Liner Perforation depth: measured true vertical Plugs (measured) Junk(measured) , Cemented Measured depth True Vertical depth 110' 110' 780 Sx A.S. III 3810' 2885' 350 Sx Class "G" 10137' 6460' 9543'-9564' 9585' -9618' 9630' -9640' MD 6025' -6039' 6053' -6077' 6086' -6093' TVD Tubing (size, grade and measured depth) 3 1/2", J-55, 9.3 #/ft., EUE 8rd IPC, 9374' Packers and SSSV (type and measured depth) SSSV: Baker FVL 2010', Packer: Baker FHL 9344', 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch [] Perforate C Sand from 9451' MD to 9464' MD @ 8 SPF. 13. Estimated date for commencing operation 12/23/87 14. If proposal was verbally approved Name of approver Date approved 15' ' hereby'~rtify that the f°reg°in¢ is true an'd' 'c'°~'ect t° thZst °f mY kn°wledge Signed, _ . _ ~_./7,,~ ~-~Title ~,~~~, Date Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Approved Copy Ret~rnecl / ~ /'-'j LONNIE C. SMITH Approved by Commissioner IApproval No. by order of the commission Date Form 10-403 Rev 124-85 Submit in triplicate(~ STATE OF ALASKA ALASK~ OIL AND GAS CONSERVATION COMM..~ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate t Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator ARCO A'laska, ]:nc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 155' FNL, 1450' FEL, Sec. 33, T11N, R9E, At top of productive interval 1387' FSL, 1415' FEL, Sec. 34, T11N, R9E, At effective depth 1180' FSL, 1110' FEL, Sec. 34, T11N, R9E, At total depth 1160' FSL, 1091' FEL, Sec. 34, T11N, R9E, 11. Present well condition summary Total depth: measured true vertical 10137' 6460' feet feet 5. Datum elevation (DF or KB) /,~/ RKB 127' Fe 6. Unit or Property name Kuparuk River Unit 7. Well number 2F-11 8. Approval number 9. APl n(~2rrC_e~1095_00 50-- 10. Pool Kuparuk River 0il Pool Plugs (measured) Effective depth: measured true vertical 10047' feet 6394' feet Junk (measured) Casing Length Structural Conductor Surface 110' Intermediate 3810' Production 10137' Liner Perforation depth: measured true vertical Tubing (size, grade and measured depth) Size 16" 9-5/8" 7" Cemented Measured depth True Vertical depth 110' 110' 780 Sx A.S. III 3810' 2855' 350 Sx Class "G" 10137' 6460' 9543'-9564' MD 9585' -9618' MD, 9630' -9640' MD 6025' -6039' TVD 6053' -6077' TVD, 6086' -6093' TVD 3-1/2", J-55, 9.3 #/ft., EUE 8rd IPC, 9374' Packers and SSSV (type and measured depth) SSSV' Baker FVL 2010' Packer: Baker FHL 9344' 12. Stimulation or cement squeeze summary Intervals treated (measured) 9543' - 9564' 9585' - 9618' 9630' - 9640' Treatment description including volumes used and final pressure See attachment 13. Representative Daily Average Production or Injection Data~2Sk2O~ Oil-Bbl Gas-Mcf Water~Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 110 89 0 1250 110 220 130 0 1250 105 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge FoSi gj ;~.404 R~ev.~V~.l~5 ~%'~t~%t~ Title Date ,2"}/~/-~ ~ Submit in Duplicate /g-~-70 ~ $?F C: C'~ M H E N T 5' I:: T N A I... C::3 ;£ T · . ' STATE OF ALASKA ALASi',,.. OIL AND GAS CONSERVATION COMN ,SION APPLICATION FOR SUNDRY APPROVALS % fee f' 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging ~ Stimulate [] Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator ARCO A'la_~ka_ Thc 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 155' FNL, 1450' FEL, Sec. 33, T11N, RgE, At top of productive interval 1387' FSL, 1415' FEL, Sec. 34, T11N, RgE, At effective depth 1180' FSL, 1110' FEL, Sec. 34, T11N, R9E, At total depth 1160' FSL, 109I' FEL, Sec. 34: T11N: R9E_. 11. Present well condition summary Total depth: measured 10137' feet true vertical 6460' feet Plugs (measured) 5. Datum elevation (DF or KB) RKB 127' 6. Unit or Property name Ku.naruk River Unit 7. Well number 2F-11 8. Permit number 9. APl number 50-- 029-21095-00 10. Pool Kuparuk River Oil RI CEIVED Pool Effective depth: measured 10047' feet true vertical 6394' feet Casing Length Size Structural Conductor Surface I10' 16" Intermediate 3810' 9-5/8" Production 10137' 7" Liner Perforation depth: measured true vertical Tubing (size, grade and measured depth) Junk (measured) Alaska 0il & Gas Cons, Cornmissioii Anchorage Cemented Measured depth True Vertical depth 110' 110' 780 Sx A.S. III 3810' 2855' 350 Sx Class "G" 10137' 6460' 9543'-9564' MD 9585'-9618' MD, 9630'-9640' MD 6025'-6039' TVD 6053'-6077' TVD, 6086'-6093' TVD 3-1/2", J-55, 9.3 #/ft., EUE 8rd IPC, 9374' Packers and SSSV (type and measured depth) SSSV: Baker FVL 2010', Packer- Baker FHL 9344' 12.Attachments Description summary of proposal I~ Detailed operations program [] BOP sketch [] Hydraulically fracture A Sand with 1RoIlrl~ ?fl/4rl m~h rnrOnnnn+ nnR C:lla~l n4~ · - .... rr .... --''-- ~-, i~..,~,.~ ~ i~.,.-,.~,.,. 13. Estimated date for commencing operation February 15, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /z~ ¢,7/~ /~ ../~/1."'~-~x~ Title ,;[~.~ ~¢._.~,_.w._.~--~. , · Commission Use Only Conditions of approval Approved by Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Commissioner I Approval No..~ .~ /~ by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate ARCO Alaska, Inc. i Post Office bvx 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 R I.".'i T U I';,.' i"-! T 0 ' 'ri::.:,.*.,:' ,-.,. ,? H :I: 'f' 'f' I::' ):.'." I'::lii; C E :1: I::"1" A t4 D F:' F:..' IE 5' L-." tJ I:;.: IE I:;:lii; I::' C117'f' ;!;' ' ( (:i i'-! Ii;; (:.'. ()F:' Y [) F Iii: A C': I"1 ) I... Y iU. I!:: ,.? 'f' (] 17 (;,~i.J [:..' TU 17 N T I-'i ]. i",l ,. ) ARCO Alaska, Inc/ Post Office box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 D A I' E · 0 5 -- ~ 55-- 8 5 'FF:~Ai,~£'I-ilTTAL N0:5t 86 ARCO AI_A'e':'' INC ,..- I, i-i A T'¥ N: I::'E C 0 R I) S [:: L. Ii:_' 1:;; I< A l" 0-- 1 t i 5 B I::'.0. BOX i'30360 ANCHORAGE, Al< · , .;. i f' 1:;: A N.S' H I I"T [: D I"1 [.'". R r:.'-. W ]: T H A I:;: I:T. 'TI'I Iii: F 0 I... I... 0 W I N [, ": E: C E I F' T AND F~I:Z'¥UF~N'ON['; SI(;-NIZD I ]' IE M.'.'.,', ;:'1_ EiA,:;'IE ACI< ?~OWI...IZI)G E C[IF:'Y Iii:"' THIS 'f'F;~AN6"MITTAL, ,,I.%F'",/SE:QUENC, E OF:' Ii:VENTS ' b, [:. L.. 0 I", I,' r-:. I-, ..~ (',', 4 -'-2 i i1=..-7 RUN L. YNES " ........ ' ..... '"' -"',.,5 i1-=-7 RI.'ZTF<IF_VE L_YL!ES I:;:I!:'C. OF;:DI!:F;,'? 04 .... 22'"'85 iG'-4 LYNIT:¢ I:::RE:?5'LJI:;:I:i: BOMBS'-"PBU (')4-2t -8'.:5 i (; 5 .S'l.'{l..ll::' 'C' SAND 04-'26 c ,:.' iL--2 'C' SANDS ONLY I::'BU 04-2t -85 iL-2 'C'SAND F'BU 04-25-85 1(D 6 TAg FILL/5'BI-IP (.)~ ,.~--_.o,.~ ' .[I..1.., ~.,I--IF' A SANDS 04--i 6--85 iQ-,7- TAG F"' " .... " ' ' ~ -~ .! 2 A -- t ¢ Ii'.' I-'1F' ,34 -~-.. '* --. ''~ - ,.,':: .,":: 7A-4 XBHF' 04-'22-'8"~ :?A-5 i=ALL OFF TE. ST (')4-2t-85 ::.!A-5 FrAI_L. OF"'F 'fE:';'T 04-'''~''~-°''z,.,.... c,_, ;:.:'. A -' 7 ..S' Ii'.' i"1F' 0 4 _,:.. ,2,o -- _ ,.,..,° ~.: ") { ~..I:-1''~. E/LINE SF:'IN/T[:L '" "": '" I...EAi< DEFECTION 'C'SAND 04-'t 6-85 ;?C-4 F'BII ,.3 ~_".~ I¢ - o,.'; .~ -i- ~.'.. 'f ~.~ ?. ['. - 4 F' B U 04 -' 25 -' 8 '5 2C,-5 I:;~t. JN TOI--(QUIE TLJRN/AHIEI:;:AI)AS 04-2t-85 .'.::(2-]; PBU-PUI_L TOR(;~UE Tt. JF:N/ .:.! C- 1 4 2. C -. t 4 '2 D - 2 2I)-- i 0 2D-i0 AMr-i:RAI)A BOMBS "'~ i',.tJJ'~ TORQUE TUF;:N/AMEF;:ADAY PBU-F:'ULL. TOI:;;[,!UE. TURN/ AMl."'; I:;:A D A BOHf-~S I."<UN 'FORC~L!E TUF~N/AHF'-.I:~ADA,'g F;:tJH TORQUE 'I't..II:~N/AHI:"'I:~ADA,.S' i:'I'.';LI--I:'[.II..L TOR(..'.'~UE TUI"<N/ AHEF;:AD~ I"; 0 H I-'¢,.? PB[J F:' Ii; U F"BU F'I'.';LI F'BU PBLJ F:' B U PBLJ · F:'BU ACKNOWLEI)GEI): I) R I L L I N C. ._'~ I-"- C' ..... ~t.,I..,~ I,., ~(- t'l 0 B I I._ ..,,. ..... . ~ ,* N/.i.' I< L,L I::.h',', 2F'-6 2 F --8 2F-8 2F'-t i 2F-ii 2 l.'; - t 2 (.; - 1 7.(.';- 8 2G--8 ":: E C Ii"' I F' T 7.,, C t.J 1:;'. R I I: R .* :) & 04-23-85 04--2i -85 04 -' ''') 5Y . C.~ 04-'2t '"':' -' c) .,) 04-.2i -85 4 --" '"'') TM C.', 03 -' ''~ r., -. c: ~ 04-" i 9-85 O4-20-.85 04- t 8-85 04- i ';~ '" ~''' '~ -' C) .J 04- t 7-°':;,., ., () 4 ..... i,.,° _. ::>,., .,~'; 03-'2t -85 O3-22-85 0 l' I S OF~' ~.$ [)l IS CAMCO CAMCO CAt, CO CAM[:[) CAMCO CAMCO [)TIS C;A?iCO CA>iCO [)TIS OTIS CAMCO CAMCO BA"r, El? E X X 0 N · x- F'H I I... I... l F:'."7 (] l L_ · :,,:- J, I:;: A T I--I H E I_ L BA~--.' ER/TOI';:QUF ]'URN OT.~ '~ S BA~(ER/TOI:~QUE (]TZ:f BAK ER I'LJRN BA~< ER/TORQUE 'I'UF;~N (]TIS CAMCO CAMCO CAMCO OTiS Alask~ Oii& Gas r,, ,,uric. C'orrJmts~tor, OTIS ~r:-~ .... ' DATE ' ' *STATE OF ALASKA ~,e .S' 0 H I * U N I 0 N I< , TUL. I i'~/VAULI" ARCO Alaska, Inc.' Post Office Bux 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Harch 7, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2F-11 Dear Mr. Chatterton' Enclosed is the Well Completion Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU4/L218 Enclosure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany /~,nchorage · -~-~'" STATE Of ALASKA ALASKA .. AND GAS CONSERVATION C'( ./ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-41 · 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21095 4. Location of well at surface 9. Unit or Lease Name 155' FNL, 1450' FEL, Sec.33, T11N, R9E, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1338' FSL, 1122' FEL, Sec.34, TllN, R9E, UM 2F-11 At Total Depth 11. Field and Pool 1004' FSL, 769' FEL, Sec.34, TllN, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 125' RKBI ADL 25657, ALK 2583 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore I 16. No. of Completions 04/01/84 04/08/84 05/05/84 N/A feet MS LI 1 17. Total Depth (M D+TVD) 18. Plug Back Depth (MD+TVD)19. Directional Survey I 20. Depth where SSSV set { 21. Thickness of Permafrost 10160'MD,6477'TVD 10047'MD,7172'TVD YES [] NO [] 2010 feet MD 1400' (approx) 22. Type Electric or Other Logs Run DI L/SFL/SP/GR/Cal/FDC/CNL, GR/CBL/CCL, Gyro, Temp. Log 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 110' 24" 225 sx Cold Set II 9-5/8" 36.0# J-55 Surf 3810' 12-1/4" 1050 sx AS Ill & 780 sx Class G 7" 26.0# J-55 Surf 10137' 8-1/2" 350 sx Class "G" & 250 .x 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) 9543' - 9640' w/4 spf 3-1/2" 9374' 9344' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 9506' - 9508' 150 ~X Class G 9376' - 9378' 150 sx Class G See Addendum for --rae~.Hre .qf'im, llm~-inn K~,rnmmrv 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE JGAS-OILRATIO TEST PERIOD II~ Flow Tubing Casing Pressure 'CALCULATED.~ OIL-BBL GAS-MGF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED 1 3 !985 Alaska Oil & Gas Cons. Commission Anchorage Form 10~,07 GRU4/WC57 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ii-,.~: .~.: : -:".: ~.-':.? ~. (~EOI~0~i~Ji~A¥11(~I~'~ .... · ...... , .... ............. ' .... ' ....... :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 Upper Sand 9450' 5960' N/A Base UPper sand 9462' ', 5969' Top Lower Sand 9521' 6009' Base LOwer Sand 9696' 6134' . . . _ . 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge (~~ ~L Associate Engineer ,~.4~~- Signed ~ Title Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal,-water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage.cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ADDENDUM WELL: 9/10/s4 9/25/84 2F-11 FRACTURE STIMULATION SUMMARY AFE: 403938 10,030' PBTD Rn temp log f/9700'-9220', did not tag btm due to Vann gun fsh in hole. Begin Frac Work At: 1410 hrs, 9/24/84 Dowell frac'd Kuparuk "A" sand perforations 9543'-9563', 9585'-9618' and 9630'-9640' in 6 stages per 9/20/84 procedure using 90° diesel, P-20, YE4PSD gel/wtr; slick diesel; and 100# 12-20 sand. Pressured annulus to 1500 psi with diesel. Test lines to 5000 psi; OK. Pumped 40 bbls 90° diesel @ 11BPM, 5000 psi. 1. 20 bbls gelled wtr @ 12 BPM, 5000 psi 2. 24 bbls gelled wtr w/ 1 ppg 100 mesh @ 12 BPM, 5050 psi (1000# 100 mesh) 3. 65 bbls gelled wtr @ 14 BPM, 4870 psi 4. 24 bbls gelled wtr w/2 ppg 12-20 @ 15 BPM, 4500 psi (2000# 12-20) 5. 43 bbls gelled wtr w/7 ppg 12-20 @ 15 BPM, 4200 psi (12,642# 12-20) 6. Displ w/20 bbl gelled wtr & 21 bbls diesel @ 15 BPM, 5000 psi Screened out w/50 bbl displm't remaining. Pumped 1000# 100 mesh & 1416# 12-20 in formation leaving 13,225# 12-20 in casing. Load to recover 61 bbls of diesel and 196 bbls of wtr. Job complete at 1502 hrs, 9/24/84. 10/05/84 9732' PBTD "A" Sand Perf's: 9543'-9563', 9585'-9618', and 9630'-9640' RU CTU, tst BOP & tbg to 4000 psi; OK. RIH w/CT while circ'g gel/diesel @ .2 BPM. Tag fill @ ±530'. Inc rate to 1.75 BPM, wsh hard fill to 590'. Circ out & reduce rate back to .2 BPM & cont RIH. Inc rate to 2.8 BPM & start Nh @ 350 scf/min @ 9000'. Wsh thru heavy fill to ±9638',Zend of CT. Wsh sand to 50' increments, circ hole cln. Displ w/cln diesel while POOH. RD, secure well. RECEIVED Alaska uil & G~.~s C(;ns, Commission A,qcllor~cje ADDENDUM WELL: 2F-11 10/18/84 10/19/84 10/20/84 thru 10/22/84 10/29/84 9732' PBTD, SI f/sd settling "A" Sand Perfs: 9543'-9563', 9585'-9618' & 9630'-9640' RIH w/CTU pmp'g .2 BPM. Increase rate to 2.2 BPM & start 350 scf/min N~ @ 9450'. CO to 9732', wrk CT back to tbg tail, circ cl~ · on btm w/gel/diesel Displ while POOH w/cln diesel. (Total pmp'd = 336 diesel, rec'd 316 bbls.) 9732' PBTD, Flwng for Clnup "A" sand perfs 9543'-63', 9585'-618' & 9630'-40'. RU SL. Tst BOP & lub to 2500 psi, ok. RIH w/2" bailer. Tag fill @ 4916', bailed to ±4925' thru bridge. Stuck bailer & wk free. POOH, RD, secure. Flowed f/clnup. Rec 108 bbl @ 450 FTP. 9732' PBTD, Well SI Cont flowing well @ 450 psi FTP; rec'd. RU S/L, tst BOP & lub to 2500 psi; OK. RIH w/bailer; unable to get below 4868', POOH. Bailer coated w/heavy visc oil, RD S/L, secure. SI, flowed well @ 200 psi FTP; rec'd 78 bbls. Spot & RU unit, tst lub to 2500 psi. TIH w/bailer to 4827'; ti stopped @ 4827', POOH, rec'd small amt of sand/oil in bailer. RD unit. RU CTU, RIH w/CT, pmp'g diesel @ min rate (2 BPM), holding ±500 psi back press w/choke. Tag btm @ 9747'. Inc pmp rate to 1.2 BPM, 3800+ psi. POOH, displ'g tbg w/diesel. Pmp 127 bbls diesel, rec 157 bbls. Well made 50 bbls during operation. SI well, RD CTU, secure well. Starting Camco equip. RU & tst lub w/2500 psi. RIH w/gage ring to 9724'. RD WL unit & secure well. 8623' PBTD RU CTU, gel up diesel, press tst to 4000 psi. GIH w/i-i/4" CT pmp'g @ 0.2 BPM to 7000'. Start 400 scf of N2 & increase pmp rate to 1.7 BPM @ 4000 psi. Cont in hole to 8365'. Pull back into tbg tail, CO hole by taking 50' increments to TD @ 8623', CBU. Switch to diesel & SI N_. Circ on btm. SI well, RD Pmp'd 295 bbls of gel/d~esel, 100 bbls of diesel & 8~,00 scf of N2. Total rtns = 400+ bbls. Well SI f/sd settle. Drilling Superintendent RECEIVED MAR 1 !985 Alaska 0ii & Gas Cons. Co~rmssion Anchora~3e Date ARCO Alaska, Inc~- .... Post Offic~ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Date: 02/19/85 Transmittal No: 5055 RETURN TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B ///0. Box 100360 chorage, AK 99510 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. BHP Reports/Static Reports CAMCO ~01/ iA-10 28/85 iA-10//02/07/85 1G-4 z01/24/85 2F-11/01/29-30/85 OTIS 2x-9~- 01/25/85 2X-10~ 01/27/85 1C-6~~- 01/28/85 1E-5 ~.~ 01/30/85 1E-30/~ 02/07/85 Receipt Acknowledged: B. Currier BPAE Chevron. D&M · .,2 :,~ ,,,' .:.!' ~" ' . Date: DISTRIBUTION ~\ncliorag~ Drilling W. Pasher State of AK ~i Geology G. Phillips Sohio Mobil Phillips Oil Union NSK Drill Clerk J. Rathmell Well Files ARCO AIs.~ka. In(:. is a sub,~idia~y O! AtlantlcRich~ieldCompan), ARCO Alaska. Inc...-~ '-_'-: :: -~' 3[ '- ....... t.- o.~ ] C, · -. . _ : - . .,.~..-....'..... '.; .; ",..":',,. S':'- 277 5637 Date: 8/16/84 Transmittal No: 4686 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-11Z5B P.O. Box 100360 Anchorage, AK 99510 .. ~ransmitted herewith are the following items. Please acknowledge receipt ~and return one signed copy of this transmittal. PBU SURVEYS/Pressure Analysis lC-1 Static BHP 4/12/84 Camco lC-5 " " 4/13/84 " lC-6 Gas Disp. 5/16/84 Otis lC-7 PBU 4/20a21 Camco 1C-9~Falloff Test 4/29/84 " lC-lO~-~_" " 5/06784 " 1D-1 Static BHP 4/19/84 " 1D-5 Falloff Test 4/29/84 Otis 1E-12 Flow BHP/GLV 7/01/8484 Camco 1E-17 Static BHP 1/8-11/84 Otis 1E-18 " " 1/03/84 " 1E-24 Injectivity 6/21-22/84 " 2F-8 T Log PBU 5/06/84 Otis 2F-11 Initial PBU 5/22/84 Camco 2F-12 Initial Well 5/15/84 '-' 2F-13 " " 5/14/84 Ot±s 2F-14 PBU 5/03/84 " 2F-15 PBU State 4/26/84 /cat Receipt. Acknowledged: B. Adams Camco DISTRIBUTION Date: ...... W.V. Pasher 4. ~. bml[n '; F.G. Baker P. Baxter BPAE Drilling Geology Mobil G. Phillips Phillips Oil J.J. Rathmell State of Alaska , Sohio Union Chevron NSK Operations R&D Well Miles REV. I RENUMBER ALL WELL~ PER NSK DRILLING.(180° ROTATION OF NUMBERING ) REV. 2 CHANGE ALL ELEV.; CHANGE BASIS OF ELEV. NOTE 05 4o 06 30 07 2O 08 t0 92.0 ~0 .0 28 27 ~4 BASIS: OF PAD ELEV. IS O.G. ELEV.-tNTERPOLATED FROM S R" 8 F- 12-303~ -' PHASE II ~BUILT CONDUCTQRS DRIL! AS' LDCATED IN PROTRACTED SECTION 33 TOWNSHIP II N.,RANGE ,BASIS OF LOCATION IS ~NUME~S C~E-2 N.E.~ 2:C MIDDLE PER LHD ASS~IATES. 30 OUILT ?_,F CONDUCTORS LOCATIONS' WELL 9 Y: 5,948~8'~6.91 X= 517,761.38 37' FN L WELL I0 Y:5,948,787.73 X= 517,771.51 96' FNL WELL [I y=5,94a,728.56 x: 517,781.64 .... ~_--1.55' FNL [ 517,791.81 ~-.~ 214' FNL WELL 13 Y =5,948,622-.31 X= ~i7~516.04 261 FN L W~14 Y: 5,9~, 681.31 x= 517~505.85 202'FNL ~ 15 Y= 5,~8,7~- 50 X, 517,495.75 143'FNL W~ 16 Y = 5,~8,799.60 X = 517~5.~ 8~' FNL DAVID RLUCCl 5276 .! HEREBY CERTIFY THAT I REGISTERED AND LICENSED SU~iNG IN THE STATE Lot. 70° 16'17. I0 15" Long. 149° 51'?.2.870" 1470' FEL Lat. 70° 16'1 (~. 5192" Long. 149°5['22.580" 1460' FEL I_at. 70° 16'15.9370'' Long. 149°51' 22.289" 1450' FEL Lat. 70° 16' 15.35 4-4." Long. 149°51 '21.997" 1440' FEr_ Lat.70° 16'14.89 80" Long. 149° 51 '30.029" 1716 ' FEL Lat. 70° 16'15.4.786" Lo nc. 149 o 51 ' 3 0.3 Z?.." 177_6' FEL Lat. 70016' 16. 0610" L~ng, 149 °51' 30.61 I" 1756' FEL Lot.70° 16'I 6.64.?.6" Long. 149°51'30-905" 174'6' FEL AM PROPERLY TO PRACTICE L.AND OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE UNDER, MI' DIRECT SUPERVISION AN[:) THAT ALL DETAILS ARE CORRECT AS OF NOV. 5,1983. :52 THIS 3a .. T. IIN. T. ION. ARCO Alaska, Inc. Kuparuk Project ......... -North SioDe Drilling "..__.._D_RI LL SITE 2'F ..' ) 'CONDUCTOR--AS "BUILT LOCATIONS date' 11'9' 8 3 scale' I": 400' ARCO Alaska, Ir Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 June 5, 1984 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT' 2F-11 Dear Mr. Chatterton' Enclosed are the well completion report and gyroscopic survey for the subject well. If you have any questions, please call me at 263-4944. Sincerely, 'J. Gruber Associate Engineer JG:tw GRU7/L80 Enclosure RECEIVF. D JI. JN 0 F~ ]984 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ' ' · '----' STATE OF ALASKA .-- -- ~ ' ALASK ....... AND GAS CONSERVATION ~. .~IISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] .. 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-41 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21095 4. Location of well at surface 9. Unit or Lease Name 155' FNL, 1450' FEL, Sec.33, TllN, R9E, UM ~.LOCATiONS~ Kuparuk River Unit At Top Producing Intervalil| VERIFIED ] 10. Well Number 1338' FSL, 1122' FEL, Sec.34, T11N, R9E, UNt ~./: 2F-11 At Total Depth t Surf"~'----II¢I 11. Field and Pool 1004' FSL, 769' FEL, Sec.34, T11N, RgE, UM [B'H'~t Kuparuk River Field , 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i l Pool 125' RKB] ADL 25657, ALK 2583 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 04/01/84 04/08/84 05/05/84 N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 1 21. Thickness of Permafrost 10160'MD,6477'TVD 10047'MD,7172'TVD YES [] NO [] 2010 feet MDI 1400' (approx) . 22. Type Electric or Other Logs Run D IL/SFL/SP/GR/Cal/FDC/CNL, GR/CBL/CCL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 110' 24" 225 sx Cold Set II 9-5/8" 36.0# J-55 Surf 3810' 12-1/4" 1050 sx AS Ill & 780 sx Class G 7" 26.0# J-55 Surf 10137' 8-1/2" 350 sx Class "G" & 250 Dx 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) 9543' - 9640' w/4 spf 3-1/2" 9374' 9344' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 9506' - 9508' 150 sx Class G 9376' - 9378' 150 sx Cla,%5 (~ 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MOF WATER-BBL CHOKE SIZE GAS-OI L RATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (corr) Press. 24-HOUR RATE m~; 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None -- REC[IVED J U N 0 8 1984 Alaska 0il & Gas Cons. Commission Anchorage ,, Form 10-407 GRUT/WC23 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ;-;.-':~;~-:--;,~i :-~ ;;: ;:"-*_ ~'"I~O~O~:~'C.,~Ai~I~-~I~ i-':?,!~%--''- :: ::: ~:i~:.~..; ~':':. i~:---;~.,?'.-.",!~.~i~?~-~'---~'.' ~ ;.~? ~-'.:;FO'~'M~,T.~bN'T'ES~-S.:.., ':"--"' . · . · . . · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, andtime of each phase. . . . _ : .Top UPper Sand 9450" '" 5960' N/A BaSe Upper Sand ..9462~- _ - . 5969. · Top Lower Sand : ~ ?-9521~ : 6009' ' : .... Base Lower Sand .'-:9696~ 61:34' . .. . . · · - ; . : ,: - .~ , , . .. : ~. : . . : · · . . ., . . 31. LIST OF ATTACHMENTS Drilling History; Completion.Summary; GyrOscooic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my kn°wledge · . - / -z, ............. .... INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. 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 (G L) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- 'jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". ARCO 011 and Gas Company Well History - Ini~l Report - Dally Inelmatlone: Prepare and submit the "lnltlll Rli=~rt" on th~ first Wldlllldly Ifil! · weft II Dally work prior to Ipuddlng ahould bt summmtzed on the form giving InClUllV~ dliel only, Field Alaska County. pldl~ or ~,,-ou~t North Slope Borough ILea~e or Unit I ~L #25657 ITItle Drill, Complete & Perforate Kuparuk River Alaska all 2F-11 Auth. or W.O. no. A~g 602477 Operator IARCO W.,, 56.24% Prior sretUl If I W.O. ARCO Alaska, Inc. Spudded or W.O. begun Spudded Date and depth as of 8:00 a.m. 4/02/84 mD~ia [Hour 4/1/84 0330 Hfs 4/03/84 4/04/84 4/o5/84 4/06/84 Complete record for each day reported 16" @ 110' 2323', (2228'), TIH Wt. 9.5, PV 16, YP 14, PH 9, WL 10.2, Sol 6 Accept rig @ 0030 hrs, 4/1/84. NU diverter lns. S~ud wall @ 0330 hfs, 4/1/84. Drl, DD & surv 12¼" hole to 2323', TOM to . chg BHA, TIH. 677', 4.5°, S61.OE, 677 TVD, 7 VS, 3S, 6E 1037', 16.8°, S52.5E, 1030 TVD, 74 VS, 43S, 60E 1187', 21.8°, S53.5E, 1172 TVD, 124VS, 73S, 100E 16" @ 110' 3825', (1502'), Rn'g 9-5/8" csg Wt. 9.8, PV 19, YP 16, PH 9, WL 9.7, Sol 1 TIH, wsh & rm 2085'-2323', drl 12¼" hole to 3825' short trip, C&C, TOH. RU to rn 9-5/8" csg. , CBU, 10 std 9-5/8" @ 3810' 4106', (101'), Drlg Wt. 8.5, PV 7, YP 8, PH 11.5, WL 15, Sol 2 C&C hole, M&P 1050 sxs AS III cmt w/¼{ cellophane/sk, followed by 780 sxs Class "G" cmt w/2.0% D-31 + 2.0% D-46. Displ cmt using rig pmp. Bumped plug. CIP 11:12 hfs 4-3-84. ND 20" diverter. Perform top Job, NU & tst BOPE. TIH w/BHA, DO FC @ 3727', CO cmt + 10' new hole. Conduct formation tst to 12.5 EMW. Drl f/3835'-4106'. 9-5/8" @ 3810' 5915', (1809'), Drlg Wt. 9.1, PV 15, YP 14, PH 10.0, wL 9.8, Sol 6 Drl & surv to 5915'. 4249', 53.9°, S57½E, 3121, 2531VS, 1295S, 2050E 4863', 53.6°, S58E, 3300, 2665 VS, 1425S, 2256E 5491', 56.9°, S59E, 3851, 3424 VS, 1820S, 2906E 9-5/8" @ 3810' 8215', (2300'), Drlg Wt. 9.2, PV 13, YP 7, PH 9.0, WL 8.2, Sol 7 Drl & surv to 7970'. 5803', 59°, S57E, 4016, 3688 VS, 19615, 3130E 6552', 60.7°, S55½E, 4387, 4339 VS, 2318S, 3674E 7461', 58.9°, S$O½E, 4843, 5125 VS, 2793S, 4300E 7864', 57°, S46½E, 5057, 5464 VS, 3020S, 4556E The above is correct Signature ] Data For form preparation ~nd distribution, see Procedures Mandil, ~ectlon 10, Drilling, Pages 86 and 87. RECEIVED 5/16/84 JUN 0 8 I984 AR3B-459-1-D Alaska Oil & Gas Cons. Commission Anchorage Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report h'latructions: Preoare 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 suspenOed for an indefimte or appreciable length of time. On workovers when an official test ~s not required upon completion, report completion and representative test data Jn blocks provided The "Final Report" form may be used tor reporting the entire operation iff space ~s available. I Accounting cost center code Oistrict ICounty or Parish Slate Alaska North Slope Borough [ Alaska Field ILease or Un,t Well no. Kuparuk River ADL #25657 2F-1i Aulh. or W.O. no. ITM AFE 602477 Drill, Complete & Perforate Operator ARCO Alaska, Inc. Spudded or W.O. begun AR.Co. W.~. 56.24% Date 4/1/84 Spudded Date and depth as of 8:00 a.rn Complete record for each day reported 4/11/84 4/07/84 thru 4/09/84 I1'otal number of wells (actlYe or machve) on th~s COSt center prior tO pluggmg and abandonment of this well Hour Prior status if a W.O. 0330 tits. 7" @ 10,137' 10,047' PBTD, 10,160' TD, RR 10.3 ppg NaC1/NaBr Fin rn'g 259 + 2 pup jts, 7", 26#, J-55 HF-ERW BT&C csg w/FC @ 10,047', FS @ 10,137' Att to circ& recip, csg stuck @ 10,137'. M&P 350 sx Cl "G" w/3% KC1, .8% D-60 & .2% D-46. Displ w/385 bbls 10.2 NaC1/NaBr using rig pmps. Unable to recip csg, lost ±100 bbls fluid while pmp'g spacer. Bump plug. CIP @ 1015 hrs, 4/10/84. Instl pack-off & est to 3000 psi. NU companion flange. RR @ 1500 hrs, 4/10/84. Well dn sqz'd & Arctic Pak'd._ . 9-5/8" @ 3810' 10,160', (1945'), TIH Wt. 10.3 PV 17, YP 15 PH 9.0, WL 6.6, Sol 14 Drl to 9810', 12 std short trip, circ f/logs, POOH. RU & rn DIL/SFL/SP/GR/ CAL/~DC/CNL f/9766'-9250' & DIL/SFL/GR f/9791'-3811'. TIH to 9-5/8" shoe, circ. TIH, drl to 10,160'. 4/10/84 9-5/8" @ 3810' 10,160', (0'), Rn'g 7" csg Wt. 10.3, PV 17, YP 11, PH 9.0, WL 6.9, Sol 12 C&C mud, POOH. RU to rn 7". 10,085', 37°, S43-1/2E, 6466 TVD, 7145 VS, 4175S, 5799E Old TD New TD Released rig Oate 1500 Hrs. Classifi_catioes (oil. gas, etc.) Oil Producing method Flowing Potential test data PB Deoth 10,160' Kind o, 4/10/84 Type completion (single. dual. etc.) Single Of!iclal reservoir name(s) Kuparuk Sands 10,047' Rotary 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 Grawty Allowable Elfective date corrected The above is correct Sig ...... ~I~J-~ ~'~-~"x,,,,~' ,~/.~1 loafs Title 5/16/84 Drilltn[ Superintendent For form preparation and distribution, ~ AR3B-459-3-C JUN 0 8 ]984 INurnber all daily well history forms conseculiYely I Page no. 2F-11 COMPLETION SUMMARY RU Dresser-Atlas/Sperry-Sun. ND lower tree assembly. Ran gauge ring/JB/GR/CBL/CCL; poor bond. Ran Gyro f/surface to 9950'. Reran Gyro f/2600' - 9950'. RD Dresser-Atlas/Sperry-Sun. NU lower tree assembly. Secured well. Accepted rig @ 2100 hrs, 04/26/84. ND BOPE. NU tree & tstd to 3000 psi - ok. Perf'd 9506' - 9508' w/4 spf. RIH & stuck ret @ 7300' RIH & tagged retainer @ 7316'; milled out. Ran gauge ring/JB to 9700'. ~IH w/cmt ret & stuck @ 9549'; unable to work free. Set retainer & POH. RIH w/another cmt retainer & set @ 9420'WLM. RIH w/DP & tagged retainer @ 9422'. Sting into ret. Tstd ann to 1000 - ok. Established inj rate @ 2 BPM @ 2600 psi - unsting. Pumped & squeezed 150 sx Class G cmt. Perf'f 9376' - 9378' w/4 spf. Ran gauge ring/JB to 9418'WLM. RIH & set retainer @ 9216'DPM. Pumped & squeezed 150 sx Class G cmt. WOC. RIH & tagged retainer @ 9210' & drilled on it. Drld cmt below retainer & drld to squeezed perfs. Tagged 2nd retainer @ 9~19'. Tstd sqz perfs to 1500 psi - ok. Drld 2nd retainer & drld cmt to 9530 Tstd sqz perfs to 1500 psi - ok. Drld cmt. Tagged btm retainer @ 9560' ~ drld. RIH to PBTD. Ran 3-1/2" completion assy w/tail @ 9374', pkr @ 9344' & SSSV @ 2010'. ND BOPE. NU tree & tstd to 3000 psi - ok. Disp well w/diesel & Kuparuk crude. Tstd tbg & pkr to 3000 psi - ok. Tstd annulus to 2500 psi - ok. Dropped bar & perf'd the following interval: 9543' - 9640' w/4 spf. Flowed well to clean up. SI well. Dropped ball & released guns. Set BPV. Secured well & released rig @ 0400 hrs, 05/05/84. GRU7/CS23'tw RECEIVED JUN 0 a lg 4 Alaska Oil & GaB Cons. Commission Anchorage ARCO ALASKA, INC. PAD 2F, WELL NO: 11 SIGMA-GYRO dOB NO: AO584Z0264 ......... KUI~.'~UK..FIELD, NORTH .SLOPE, ALASKA SIGMA GYRO, 0-9700 MD, SIJRVEYOR: F'EFFERKORN/JAHN SIGMA 175 NO: 662, PROBE NO: 50 DATE RUN: 14-MAY-84 FORESIGHT: N9 44W SURVEY TAKEN FROM WELLHEAD VERTICAL SECTION CALC:ULAT N PL.I ~I~ECT ION: S RECORD OF SI..IRVEY RADII; I,J:~,: OF CL!RVATURE METH!~!O ARCO ALA.SKA, I NC PAD 2F, WELL NO: 11 $IGMA-GYRCm KLIPARUK FIELD, NORTH SLOPE, ALASKA C:OMPUTAT I ON JnB NFl." A0584Z(')264~ ............................... -'i:I'~'- ............... [mATE 14: 06: 26 24-MAY-84 PAGE NO. 1. TRUE MEASURED DRIFT DRIFT COLIRSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S I_1 R E DOGLEG DEPTH. ANr~LE DIRECTION L~NQ. TH.. DEPTH SECTION TVD C iD 0 R D I N A T E.~ DISTANCE DIRECTION SEVERIT FEET D M D M FEET FEET FEET FEET FEET ' ~'EET D M ..... ~i-~ 7~'~iOF 0~ 100. 200. :300. ( 400. 600. 700. · 8;00. 900. 0 0 0 0 0 6 N 5(]) O.E 0 21 N 6 19 E 0 23 N 48 23 E 0 22 N 61 54 E 0 36 $ 84 2'-7 E 3 14 S 66 58 E 5 54 $ 64 18 E 10 0 S 61 42 ~ 13 10 $ 60 20 E 1000. 16 I1S 60 52 e 1100. 19 42 S 63 37 E 1200. 23 20 S 61 8 E 1~00. 2~ 39 S 6,0 28 E 1400. 28 28 S 64 6 E 1500. 31 46 $ 65 17 E 1600. 35 0 $ 65 7 E 1700. 37 59 $ 64 54 E 1.8.00 ~0 ~4 ~ 64 16. E 1~00. 44 ~ S 63 46 E O. O. 00 0.00 -125.00 O. O0 O. O0 100. 100.00 0.02 -25.00 0.06 N 0.07 E 100. 200.00 --0.02 75.00 0.40 N 0.25 E 100. 300.00 -0.11 175.00 0..96 N 0.54 E 100. 400.00 O. 11 275.00 1.32 N 1.06 E 100. 0.6.9 374.9. '-?. 1 .48 N I . o ~' o,_, E 100. :3.80 474..9:3 0.66 N 5.11 E 100. 11 .62 574 .60 ~°. 62 c.._, 1°~. 36 E 100. ~._ :31 67:3 62 8 ~0 S 24 68 E 100. 45.27 771.57 18.63 $ 42.24 E 10~ 1 10 10~ 100. 499..99 599.93 699.60 798~.62 896.57 99:3.3 "'~:'~ 1088. ~:' 1181.43 1¢)0. 1447,96 100. 15:31.45 100. 1611.84 100 1687.06 100. 1762.75 1 1 2: 273. 13 1322.96 327.25 1406.45 385.7-9 1486.84 ~48, 40 1564,06 515.12 1637.75 2.4£) N 51 45 E 0.36 5.15 N 8'2 :::7 ".',' 12.64 $ 78 2 E 2.67 26.24 '.S 70 10 E 4. 11 46.17 $ 66 12 E 3.1c',., ~I I I~ 05 E i:~: 24 E ' .50 E 71.42 ._-..'"' 64 1:3 E 3.02 102.20 ¢'~, 63 37 E ..~ 62. 13:3.. 87 ._,c. 6:3 18 E 3.74. 1,:,( .29 $ 62 43 E :z.33 ~z...,'~'"'=. 77 '.3 6v-'~ :':::q ..... E :~ ' 2/-, ,.,, ,.... ........, .: .... E z. 7.-. 91 63 0 E 3.35 · .3.. L) S 6:3 E 3 148 31:3 295.80 E ' .~'.89 22 .2:3 173 4:3 c; 34.9 6.9 E :3.'.'? 0. '"'--' c. . . .... : ....... 63 2:7 E 2. ¢.,":;' ~(~ ~!.... 6.9'-'") .=.'-' 407. (.'.)6 E 453 ,· 85 $ 63 4.5 E 2 · ...... 94 · ?."'.¢¢~ 30 c- 467 81 E .~,'., . c- 63 47 E 3 27 ......... .,.:. 1 4:_--: .... 2000. 47 41S 63 16 E 2100. 51 31 S 61 52 E 2200. 57 37 S 61 34 E 2300 57 2 S 60 24 E 2400. 56 48 S 60 28 E 100, 1832.30 100. 18-97.10 100. 1955.05 100. 2009.04 100· 2063.63 586.12 1707.30 661.58 1772.10 742.44 1830.05 8~6.13 1884.04 -90-9.53 1.938.63 :262.3:3 S ._,.. ~, 1 A E 2.97 41 c- .=ic.,,c,, 68 E · ._l~ ._ . .. · · ':::--:6 00 ~ 671 39 E 376. ,o,c: ~ 74.~. ~'~0 E 41:.3.17 S 817.8.9 E · _,='-~.~'-. '-'=-'..., S 6:3 45 E :3.55 .... 66.9.37 $ 63 37 E 3..98 7~1'). 77 c.._. 63 25 E 6. lC) 834 '-"-' c. 63 10 E 1 14 , ,:,,.", ._, ,. .91':' ~c~ :3 62 55 E 0 24 2500. 56 41 S 60 26 E 2600. 56 45 $ 60 13 E 2700. 56 45 S ~,Of 8 E 28~0. 56 27 S 60 7 E 2.900. 56 17 S 60 4 E 100. 100. 100. 100. 100. 2118.47 992.75 19.93.47 217:3.34 1075.97 2048.34 2228.17 1159.23 2103.17 2283.22 1242.36 2158.22 2338.61 13:25.28 2213.61 n.=,9 ~c, c. o;/0 ,/-'-' E 1002 13 $ 62 43 E 0 ~(')0. '"' '- '-'~=. 62 .. ,:, 0:3 96:3. '.." 5 E 10,:,._, 66 '.3 :32 E 0.1 .='~,~'" R'- c- -- ....-,z.. ,. Y ,., 1¢)?,5. :::0. E 1169,22 c.._, 62 Z:," E 0.07 =~'"',9.9 $ 1108 1:3 E 1..'5z..64 :3 62 1:3 E 0 30 /-,2.=; .=:0 ¢' 11,c:0.36 E 1.:,,:.,~ o.~ c. 62 5 E 0 17 ARCO ALASKA, INC. F'AD 2F, WELL NO: 11 SIGMA-GYRO KUPARUK FIELD· NORTH SLOPE, ALASKA JOB NO: AO584Z0264 COMPUTAT I T I ME DATE 14: 06: 26 24-MAY-84 TRUE MEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N O U L A R C L 0 .E: U R E DOGLEC DEPTH. ANGLE DIRECTION I_ENGTH DEPTH SECTION TVD C 0 0 R D I N A T E $ DISTAN~iE ]iIRECTION___._S..E_?.ER..!T FEET D M D M FEET FEET FEET FEET FEET FEET D M DG/100F ,3000. 56 6 S 59 39 E ..... 100._. 2394.25 1408.05 2269.25 3100. 55 3~ S 5~ 2~ E 100· 2450.35 14~0.55 2325.35 3200. 55 44 $ 59 24 E 100· 2506.72 1572.92 2381.72 3300· 55 30 S 5~ 8 E 100. 2563.19 1655.20 2438.1~ 3400. 55 31S 58 59 E 100. 2619.81 1737.41 2494.81 667 '-'~" · ..'._- ._~ 1252.21 E 141~.,. .~-~' ......... _$_61 __..~. E c~. :q'~ 70$~.16 S 1323 ~ E 1501.59 .~-: S 61 49 E 0.47 751·16 S 1394.74 E 158~.15 ~ 61 42 E 0. 11 73~:.34 E; 1465,~.8 E 16~,~,,~,1 _~_..~.~ .~ E 0,.~:2 '-'-~=. 72 ¢' 1536 37 E 1748 97 . ,~ .... , o . . S 61 27 E 0 12 3500. 55 33 S 58 56 E 3600. 55 3 S 58 53 E 3700. 54 43 S 58 46 E 3800. 54 18 $ 58.46 E 3~00. 54 46 $ 58 21E 4000. 54 21 $ 57 53 E 4100. 54 2 S 57 12 E 4200. 53 29 $ 57 18 E 4300. 53 30 S 57 5 E 4400. 54 4 S 56 43 E 100. 2676.3~ 181'~.61 2551.33~ 878.22 S 1606.97 E 1831.2~ S 6.1 21 E .,.0.¢!5 100. 2733.32 1901.61 2608.32 920.67 S 1677.37 E 1W13.43 S 61 14 E 0.50 100. 27~0.84 1~83.22 2665.84 W63.01 S 1747.36 E 1$795.16 S 61 8 E 0.35 100. 2848. ~0 2064.45 2723. ~0 1005.23 100. 2~06.~2 2145·73 2781.~2 1047.72 S 1886.47 E 2157.89 S 60 57 E 0.58 ~:'~, .. ~ ~zi~.~ '~,~~,~i~~ 65 E 223'~ 27 '.~ 60 5~ E 0 ~¢~ ~,0~. 4~ ~..N 1 t~'~ '~. 08 E 2:320.23 10~ ~"~ ~ ~J '~";~ '~:"~;':"' S 60 44 E 0.64 ~ ~ ~ '~ ' I'~ ''~ ' '!'''4: -~ ~ ~ ,- ::'~ -- , 10~,~08~...,4 ~-~,,~t~.~",~:,~.~Z.,:.:-~ .... ~L,~,..~~.:8,. ~.91 E 2400.74 S 60 37 E 0.56 100. ._-~~'~,.5~,6~ ._,0,~-.10 1~~:~., ~.06 E ,._,:,1 51 S 60 24 E 0.64 ....... '" J¢.~, 2642. ~.0 $ 60 ~ .7'....~ . 4500 53 50 S 56 46 E 100. .~259.96 2,630.41 ~:134 9b 1.,~,(~ 8~ $ ~94,67 ~ 4600 53 32 ~-' 56 43 E 100 331'.~ 18 2710.94 3194.18 1353 .~9 .~ 2362. '" 0,~ E '='~'" 6:3 '.S 60 11 E O. 30 4700. ~ 21 S 5~ 5q E 100. 3~8.75 ~TE~l.21 325~.75 l~C~7.Exl .....~ ~q29 ~3 E 2~02 c,~°'-' c:~ 60 5 E O. 20 ~800., .53. 29.. S 5650 E lOO. 3.4.38,;34 2.87.1,45 381:3,3.4 14.~1, Z9 ~ ~.,.~.6 .~ 's'~2, '~'T, ~... (~!).. 0 E 0.14 .............................. ~., . .~ ......... ~. ,,~ = ~ ~ 295 ~ ~A~ 84 S ~,=-~ R5 . 4~00. 53 35 A ~,6 45 E 100 ~,4~7 78 I 3372.78 1 ......... ..... ~,J~ ~..,o~. ~ E 2963.2S) c- 59 54 E 0. !2 · _ 2 49 E 0 26 5000 53 ..50 ~.. 5~ ~9 E 1 ~).0 :~,,.:~.~s~/· . 97'~0..~,.~.,.:33~° .- ~ :3431 , 97. $.,,.~0=" ..(?.. 8 263 1 ...... ,.22 E :3043, 7/-,_ .:," 5'. : ...... 5100 53 42 S 56 18 E 100 3616 08 3113 01 3491 08 1574 64 c. 2/-,98 46 E 3124 c, 44 E 0.31 .. '" = ?,~ S 5~ :3~ E 0 56 5200. 54 12 S 5b 0 E 100, 3674.92 31~4.85 3549.'22 1619.68 S ~76.:,,60 E 3204.'- ~ . 1:,6c, 96 c. c~6 E ~,, 36 S 59 33 E 58~0 57 ~ ~ ~,5 48 E 10~. 3731.34 3276 38 ~606.34 ~ = .., ~'~'~'~.:,.:,~, ~.-,o~ 5400. 57 0 S 55 24 E 100. 3785.74 3360.29 ..~660.74 3:371.0o o ..; ~7 E 0..3._, ....... ?" .~7 15 E 2 0:3 5600· .~.~ 12 '.S 54 48 E 100 38'22.75 3529.23 3767 75 180?Y.'~l S 3041 c, 4 E 35:3'.~. ~ :.3 59 . ::: 0~/ 38 c~. ~, c. ~9 5700. 59 6 S 54 54 E 100. 3944.03 ._61~.._ 1. 03 1859.~__ S o112.04 E ~/-.2~__ ~.18 ._. ~. S/ E 0.13 ' . ~ ..,. ~ ~ 84 ' _ . . ......... ~999.., ~ .;8 s 54 54 E ~ r~o. :'~5.24 ~7oo, ~8 3870.24 ........ .;~..,~..7.~ '.~ ..... ~a.~.82.,~:2~ E .... .~,~7.;~.2..~ ................ ~..~..~.,~ ~ ....... ~...,~ 5~00. 61 1°,_. S 54 24 E 100. 4044.78 3787.84 ~c71S~.78~.. 1~~._8. ~, ~ S c,~._..~'~'5c' 16 E 37S)7.45 S ~o~. ..... 57 E 2 05 ARCO ALASKA, INC. F'AD 2F, WELL NO: 11 SIGMA-GYRO KUPARUK FIELD, NORTH SLOPE, ALASKA C:OMPUTAT I ON ,_lOB NO: AO584ZC)264 TIME DATE 14: (1)6: 2/:. 24-MAY-84 PAGE NO. TRUE MEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N O U L A R C: L 0 S U R E DOGLEG DEPTH. ANGLE DIRECTION ~N!~.T~ DEPTH SECTION TVD C: 0 0 R D I N A T E S DISTANCE DIRECTION SEVERIT FEET D M D M FEET FEET FEET FEET FEET FEET D M DG/IOOF .6000, .61 12 S 54 12 E 6100. 61 6 S 52 18 E 6200. 61 12 S 54 18 E 6300. 61 18 S 54 0 E ',400. 61 0 S 53 48 E ~.~0.0 ~.0 .36 $ 5' 48 E 6600. 60 36 S 53 27 E 67£)0. 60 24 ¢'~, 53 7 E 100· 4092, R,o._ _ 3875.50 3967 . ,=,'~,_~ 2¢)10_ .13 '.3 ~,~'~'-'~._,~,. '~ E :38:_--:4 . :34 S 58 50 E 0 .20 100. 4141 .13 3'.--Y63 . £)6 4016.1 ~._ 2062 .54 S ._~o~'~'~.~. 54 E 3972.0~: S~.=,8. 43 E ' i .67 100. 4189..39 4050.63 4A64. :39 2114.8.9 :_-] 3464.77 E 4059.24 S 58 36 E 1.75 100. 4237 .4.9 4138.2.9 411 = ~- . 49 2166.23 S ~-:z53.=,._ . 83 E 4.146.. 65 S 58 30 E 0.28 .. 100. 4285.74 4225.86 4160.74 2217.84 S :3606.6.1 E 4233.96 S 58 25 E O,'35 100. 4334.52 4313.14 4209.52 2269.40 S 36.77.05 E 4320.9:3 S 58 19 E 0.40 100 .... 4383 61 4400 24 4258 61 '...'32'- 1 .07 S 3747.19 E 4407' ._.1° S ~8 100. 4432 86 4487.24 4307 86 2373.10 c. .~m~ . . ~ . ..... ,....6 96 E 4494 5~ S 58 ........ 'y. 11 S 3RR6 64 E 4._~1 17 58 ";'. E 0 25 ,/',800~ ~,O. 24, $ 5~ 2ZI...E 1.0.0, ...4.4~2,.~..5',. 4574, 16 4357. -'-5 '-'~'-'=.. .~'-' ':' 6900. 60 24 E; 53 24 E 100· 4531.65 4661.08 4406.65 2476.95 S 3956.44 E 4C,67. o4~' ~'~ '='~,7 =-~,7 E 0.0o' iiIlIIlIlilIi 0/ o .") /. ., , .... .7000. 59 30 S 52 48 E I 4.581.7 ~-~. :~6 E 4754 09 S 57 52 E I 04 7100. 59 6 S 52 36 E l O~l~l~ 4632.~ 4,:,.:,Y 73 0. 2~.06 E '-"-"~. S 57 46 E 44 73o0. lz s 3o E E S010. 0S E 0.1 7400 .S lo0.-'. B SC,. 6 0'Z ............ (i:0q 7500. ~ 0 S 52 .~:0 4837,9? 5176,59 4712.97 ~,~'9 87 S 4eE.6,6(.E ~,!o!.,7:-., o. .................... ..(_~.:.~e0 .....-67 13 S 57 '21 E 0.34 7600. 59 0 S 52 6 E 100. 4889.47 5262.22 4764.47 2842.29 S 4434.42 E .s~' ' . 7700. 57 54 S 51 48 E 100. 4.941.80 5347 33 4816.~'r) -)~.o~ ~ ._ ~ . o~ ~c.~.,.82 A 4501 ~3 E 5351.98 S 57 15 E 1.1~ ~,04~ 99 5515 26 4924.99 ~,oo~ 29 ~' 7900 56 54 S 51 24 E 100. = ~ ~.. ~.. .:. 4633.34 E 5519.39 ~' 57 5 E 0.26 8000 .'9.5 36 .S 51 18 E 100 , ............ 5105.55 5.=;,98.24 ,w."';'""(", ,:, .,, ._,..,==' 3051 ,22 '-'.=,. ........ 4698.28 .... E 5AA2, · ........................................ 12 S 57 0 E 1 ... ........... 30 8100 == .. ~ o~.. ~ oo.,. 60 5037.04 3102.81 S 4762.67 E ., :,o-,. 23 .., . · :;,~, 36 S 51 18 E 100. ~-~' 04 ~_~,r, =/'~'" ¢' 56, 55 E 0 00 8200· 5.5 36 S 51 36 E 100 5218.54 5762· 96 .~)93 54 3154 24 S 4827 · _ . · · · · · ~:. 5o~= '-,.', ?9 = ~'"'q~ ~'/', ~ M~''''° 55 .'.x 5/~ 46 E 8300 55 36 A ~1 E 10,0, 5275.04 ~,-,~,, ~,-, ~ 1;,0.04 3205,49 S 0 00 · ... -r,--,. ~. · · =, Q"~ g 00 .=, 2(') A 10 :32.=, 7 09 S 42._ 6.62 E = ~' 1 0 6.., ........... · _, 8400. 56 12 S 51 18 E 100. .~.~1.10 .... .',: ' .~ . 8500. .=-,5 6 S 51 12 E 100. 5R87.=~' 5021.01 E 6013.20 S 56 37 E 1.10 - -.~,~, ~ ~9,~....77 ~' 5 ~ '- 5 ~ 8600. 54 30 S 51 12 E 100. ._44._.17 6091. ,94 ..5'-~'~,F~._,~...17 J3~9.97 '.3 ..,0,_4,70 E 6074.55 S 56:3:3 E 0.60 ~700. 53 54 S=;, 1 24 E 100. M50~:. 66 6172.89 M~'"~' . 7~. - ~,c. ..... · .~c..66 3410 68 S 5147.99 E 61 ~ :32 56 ~8 E 0.62 · J4o7 3461,12 10 85 E 6255.58 S 56 24 E 0,47 880.0, 5.8 30 S 51 6 E 100 55i, 2 86 ~ = '~ m ~ m ................... '~ ~ · ............................................. . c, 4;~7 48 3511 60 c. 5273 ~8 E 6R.;:S =.-, c- 56 20 E 0.22 8700, 53 18 S 51 0 E 100 5622.48 6333.43 = ~ - ARCO AL~A, INC PAD 2F, WELL NO: I1 SIGMA-GYRO KUPARUK FIELD, NORTH SLOPE, ALASKA TRUE dOB NO: AO584Z0264 ............ CD~IP. UTATI. ON ............... ~AGE NO.. TIME DATE 14:06:26 24-MAY-84 MEASURED DRIFT DRIFT [:OURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R [: L 0 S U R E DOGLEG DEPT~_~_ ANGLE DIRECTION LF_NG_TM._ DEPTH SECTION TVD C 0 0 R D I N A T E...;~. D.I~TSNC~._. DIRECTION SEVERIT FEET D M D M FEET FEET FEET FEET FEET FEETI D M DG/IOOF .~000 53 .& S 51 0 E ...... 1_00_, .... 5~82,37 6413.32 5557,3? ~100. 52 48 S 51 0 E 100. 5742.64 6472.75 5617.64 3612.22 S 53?7.53 E 64?4.73 S 56 13 E 0.30 9200. 53 6 S 51 0 E 100. 5802.89 6572.58 5677.89 3662.44 S 5459.56 E 6574.21 S 56 9 E 0.30 ~300, 52 30 S 50 30 E ....IOQ, 5863,35 6652 03 5738,35 · 84 c; .~.~,Z~.,E ....... ~,~_ S 56 5 E 0,72 ( ~400, 48 48 S 4? 18 E 100· 5~26,75 672?,05 5801,75 :3762,64 S 5580,38 E 6730.3? S 56 I E 3,81 ~500 ~ 18 S 48 36 E 1.00 5~74 24. 6802 44 ~867 24 3811 .... ~ · · m · · .................. . . . '5~' 55 . ?600, 44 30 S 47 48 E 100 6064,45 6873 15 5?3? 45 3.B._o,.. S 5687,10 E 6874.17 S 55 51E 1 ~700, 42 18 S 45 48 E 100· 6137 10 6741 18 6012 10 "'g"= c. =~ . · , · o;v~,58 S 5737,18 E 6?42,03 .... ........................................................................................................................................................................................................................... PROJECTED TO PBTD PROJECTED TO TD ~~~~'~~~~ 101~0. 42 18 S 45 48 E 11 . 72 - FINAL CLOSURE DIRECTION: o 55 DE~o 20 MINS 27 SECS E DISTANCE: 7247.14 FEET ~ ARCO ALASKA, INC. PAD 2F, WELL NO: 1]~ SIGMA-OYRO ._lOB NO: A0584Z0264 I~,UP_L°Ii~U.L(.....F, IEI..D.., NOR,TH_...:~LOP...E ~;IGMA GYRO, 0-9700 bln, SURVEYOR: PEFFERKORN/,JAHN :3IONIA 17.5 NO: 662, PROBE NO: 50 DATE RUN: 14-MAY-B4 FOF~E$I OHT: N? 44..W, SURVEY TAKEN FROM WELi'~E~'D PAD 2F, WELL NO: 11 SIGMA-GYRO dOB NO: AO584Z0264 TIME DATE KUPARUK FIELD, NORTH SLOPE, ALASKA 14:07:37 24-MAY-84 MARKER ........ TRUE SUBSEA CODE MEASURED. VERTICAL MD-TVD VERTICAL R E C T A N O U L A R C L 0 S U R E VERTICAL NAME DEPTH .................... DEPTH DIEF DEPTH C 0 .D~.I~.N,A~,.TE.~S ~D..IS~TI~C.E DIF-~iD~I:iICK~. FEET FEET FEET FEET FEET FEET D M TOPUPRER.,SAND 94,~::t.QQ-_5960.493489.5 5835.49 3786.88S .5608.16E 6766.98 BASE UPPER SAND .9462,00 5968,59 3493.4 5843.59 3792.69 S 5614.84 E 6775.76 S 55 58 E TOP LOWER SAND 9521.00 6008.98 3512,0 5883,98 3821.07 S 5647.13 E 6818.41 S 55 55 E BASE L~WER SAND 96~6.00 ~134.20 3561.8 &009.20 3903.71..S 573~,1~ E ~.~..,~.~ ) , , . i; i I Sugges~form to be inserted in each "Actzve" well folder to d,,eck for tin~ly ccx~liance with our regulations. Operator',-We~l Nkme and Number Reports and Materials to be received by: ~--/~/7~--O(7~ Date Required Date Received Remarks · Comp letion Report Yes · ___Wel 1 History Yes ~ ~ ~g _, ~ ~ . ~ ~___ _Samples :Mud Lo9 /~/~ '"" ...... · Core Chips ...,.....¢/,E:~..,v..~ Core Doscrip~.on · Inclination Survey It~y Drill Stem Test Reports , Digitized Data y~ KUPARUK ENGINEERING Date: ~0FL~ Well Name: Transmittal DISTRIBUTION NSK Operations Dr il 1 lng Geolbgy/Keri Blueline Blueline Film Blueline & Sepia Sign & return the attached-. copy as recei4:~' of 4at.~.,,;~ ~n to: A~CO A~S~, INC. ATTN: Y~u~ ATO-1115B P.0. Box 100360 Anchorage, AK 99510 ARCO Alaska, In Post O f fice'B'~o'~O0360 Anchorage, Alaska 99510 Telephone 907 276 1215 May 15, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Enclosed are the Monthly State Reports for the following wells: 2A-1 2F-11 WSP #6I 2A-2 2F-12 WSP #5 2A-3 WSP #15I WSP #7 Oliktok Pt. #2 ' WSP #9 Thank you. Sincerely, .~~~'Area ZD~illing Engineer JBK/SH1: ih ARCO Alaska, Inc. is a Subsidiary of AtJanticRichfieldCompany RECEIVED MAY 1 819t14 Alaska 011 & Gas Cons. Commission Anchorage . STATE OF ALASKA ~/~ ,f. ' ALASK,....~.,._~N D GAS CONSERVATION C__'"~ISSION '/~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well (~x[X Workover operation [] 2. Name of operator 7. Perrn~.o~ 1 ARCO Alaska, Inc. - 3. Address 8. APl Nur~re_21095 :P. O. :Box 100360, Anchorage, AK 99510 50- 155' FNL, 1450' FEL, Sec.33, TllN, R9E, UM 9. Unit or Lease NameKuparuk River Unit 4. Location of Well at surface 5. Elevation in9fgelt (indicate KB, DF, etc.)I 6. Lease DesiqnationandSerialNo. PAD , 125' RKB ADL 25657 ALK 2583 10. Well No. 2F-11 11. Field and Pool KPK River Unit KPK River Oil Pool For the Month of. April ,8~9 12. Depth at end of month, footage drilled, fishing jo~s, directional drilling problems spud date, remarks Spudded well @ 0330 hrs, 04/01/84. Drld 12¼"'hole to 3825'. Ran, cmtd & tstd 9-~/8' csg. Performed top job. Drld 8½" hole to 10,160 TD as of 4/8/84. Ran logs. Ran, cmtd & tstd 7" csg. Displ top of 7" csg for freeze protection. Secured well and released rig @1500 hrs on 4/10/84. 13. Casing or liner run and quantities of,cement, results of pressure tests 9-5/8" 36# J-55 HFERW BTC csg w/shoe @ 3810. Cmtd w/1050 sxs Arctic Set III & 780 class "G". 7" 26# J-55 HFERW BTC csg w/shoe @ 10,137'. Cmtd w/350 sxs class "G". 14. Coring resume and brief description N/A 15. Logs run and depth where run DIL/SFL/SP/OR/CAL/FDC/CNL f/9791' to 3811'. 6. DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Alaska 0il & Gas Cons. Commission. NOTE--Repo/on~i~f~t~is required for each calendar month, regardless of the status of operations, and must be filed in/duplicate with the Alaska Oil and Gas Conservatio~Commission by the 15th of the succeeding month, unless otherwise directed. Form 10~,04 HILL/MR140 Submit in duplicate . -- KUPARUK ENGINEERING Well Name: .Type of Tape. Date Tape Number .o DISTRIBUTION "~~tate. of ~ Geoiogy/C. Smith OH LIS Sign & return the att~C~ed~ L u: copy as receipt of data. ' /~e ,',nch0ra~e turn to: ARCO A~S~, INC. ATTN: D. Fay ALLISON ATO-1115B P.0. Box 100360 Anchorage, AK 99510 Please note: Blueline, Sepia, Film, Tape, Photocopy ARCO Alaska, In~ Post Office ,~ox 100360 Anchorage, Alaska 99510-0360 . Telephone 907 276 1215 May 11, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT- 2F-11 Dear Mr. Chatterton' Enclosed is a Subsequent Sundry Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG' tw GRU7/L39 Enclosure If RECEIVED MAY ! 5 ]984 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Wel'l Surface: 155' FNL, 1450' FEL, Sec.33, TllN, RgE, UN 7. Permit No. 84-41 8. APl Number 9. onitor LeaseName 10. Well ~U~ber 2F-11 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designqtion and Serial No. _ 125' RKB IAnl 25657 ALK 2583 12. Check ApPropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: Kuparuk River Field Kuparuk River Oil Pool (Submit in Duplicate) Altering Casing [] Abandonment [] Other (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stim u late [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly 'state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 A,~C 25.105-170). RU Dresser-Atlas/Sperry-Sun. ND lower tree assembly. Ran gauge ring/JB/GR/CBL/CCL; poor bond. Ran Gyro f/surface to 9950'. Reran Gyro f/2600' - 9950'. RD Dresser-Atlas/Sperry-Sun. NU lower tree assembly. Secured well. Accepted rig @ 2100 hfs, 04/26/84. ND BOPE. NU tree & tstd to 3000 psi - ok. Perf'd 9506' - 9508' w/4 spf. RIH & stuck ret ~ 7300'. RIH & tagged retainer @ 7316'; milled out. Ran gauge ring/JB to 9700'. RIH w/cmt ret & stuck ~ 9549'; unable to work free. Set retainer & POH. RIH w/another cmt retainer & set ~ 9420'WLM. RIH w/DP & tagged retainer @ 9422'. Sting into ret. Tstd ann to 1000 psi - ok. Established inj. rate ~ 2 BPM @ 2600 psi - unsting. Pumped & squeezed 150 sx Class G cmt. Perf'd 9376' - 9378' w/4 spf. Ran gauge ! ring/JB to 9418'WLM. RIH & set retainer @ 9216' DPM. Pumped & squeezed 150 sx Class G cmt. WOC. RIH & ~ tagged retainer ~ 9210' & drilled on it. Drld cmt below retainer & drld to squeezed perfs. Tagged 2nd ~ retainer ~419'. Tstd sqz perfs to 1500 psi - ok. Drld 2nd retainer & drld cmt to 9530'. Tstd sqz perfs t~ 1500 psi - ok. Drld cmt. Tagged btm retainer ~ 9560' & drld. RIH to PBTD. Ran 3-1/2" completion assy I w/tail ~ 9374', pkr ~ 9344' & SSSV ~ 2010'. ND BOPE. NU tree & tstd to 3000 psi - ok. Disp well w/diesel ~ Kuparuk crude. Tstd tbg & pkr to 3000 psi - ok. Tstd annulus to 2500 psi - ok. Dropped bar & perf'd the following interval: 9543' - 9640' w/4 spf. Flowed well to clean up. SI well. Dropped ball & released guns. Set BPV. Secured well & released rig ~ 0400 hrs, 05/05/84. 14. I hereby certif/y~that the foregoing is true and correct to the best of my knowledge. Signed Title Area Dri 11 ing Engineer e be~'l~. '-c~~'s The spac f sion use Conditio~of Approval any: By Order of Approved by COMMISSIONER the Commission Date __ Form 10-403 Rev. 7-1-80 GRU7/SN17 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate KUPARUK ENGINEERING Well Name: Transmittal DISTRIBUTION NSK Operations Dr illing - Oeolb~_fKe~ Blueline Blueline Blueline & Sept-a~ retur~.,,~he attaCh~'~/ ''.'''' :ii ? copy as rece£zft-~f'~l~ta'v, ~ ,. , ,, ,, .~,~.~<,.- '""'":, '" ':::P:-:;:~,? .... 'o ~UI'/ ATTN: g. Fay ALLISON ATO-1115B P.0. Box 100360 Anchorage, AK 99510 KUPARUK ENGINEERING Date: Well Name: Transmittal Log Date Run ~L DISTRIB~ION - NSK Operation Blueline Dr iT1 ing Bluel ine Geology/.L. J. Bi/Se R&D Blueline D&M Blueline . F.G'. Baker ~e D.B, Schaf er Blueline G eology/Ken Film return the attached ceip~ of d copy as re -, - C V.D Return to: ARCOA~~ pasI~. Commissiort ATTN: D. Fa~C~ll~leI SON ATO-1115B P.0. Box 100360 Anchorage, AK 99510 MEMORANDUM State of Alaska ALASKA OIL AND GAS CONSERVATION CO~ilSSION TO: C. ~.~tterton Ch~-~n_.~/ ~_RU: Lonnie C. Smith Commissioner FROM: Harold R- Hawkins Petroleum Inspector~ DATE: April 6, 1984 FILE NO: D.21.8 TELEPHONE NO: SUBJECT: Witness BOPE Test on ARCO Alaska, Inc., Kuparuk River U. 2F- 11 Sec 33, TllN,R9E,U~, Permit No. 84-41. Tuesday, April 3, 1984: I left Prudhoe Bay DS 12-29, subject of ~bthe-~--~re~0~, to Kuparuk RiVer Unit 2F-11 to witness a BOPE test for ARCO. I witnessed the BOPE test and mud flow line indicators and alarm systems tests. There were no failures. I filled out an AOGCC report which is attached. In summary, I witnessed the BOPE test and mud flow line indicators and alams. The BOPE tests and alams system perfomed satisfac- torily on Parker Rig 141. Attachment 02-00IA(Rev. 10/79) ,.O_aC ,~4 4/SO STATE OF AI,ASKA ALASKA OIL a GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector Date. Wel 1 Operator .z/+/~-/~ .~,/., Location: Sec Drilling Contractor..~~/Yd~ Rig ~ /~/ Representative Permit # . . .~ ~Cas ing Set . . Representative Location, General Well Sign . General Housekeeping Reserve pit Rig ·. ./: POPE Stack ACCUI.1UI~%TO R S'Y S TEI.I llFull Charge Pr e ssure 3 / C3 ~ ps.ig ' Pressure After Closure /~00 psig 200 psig Above Precharge Attained: -- rain P~P sec Full Charge Pressure Attained: ~ min~Psec Controls: Master Remote ~/~ Blin(~. switch cov.~r Annular Preventer Pipe Rams ~P P Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Kelly and Floor Safety Valves ' Upper Kelly Lower Kelly Bal 1 Type Ins ide BOP Choke Manifold No. Valves No. 'flanges / ~ - Adjustable Chokes. llydrauically operated choke Test Time / hrs. _ Test Pressure Test Pressure Test Pressure Test Pressure Test Pressure Test Results: Failures ... Repair or Replacement of failed equipment to be made within ~ - days and' Inspector/Com.~ui'ssion office notified. Remarks: J/~Z/~ y ZT-~0 /D, / 11.,;))/,-.4?'dRf/ /~6u: ,</z,.,z-" /P/))/~'Z,Ot. Pl;PJ Distribution orig.' - AO&GCC cc - Operator cc - Supervisor · ~ 7"/y.J~r ToR/z ~/ P/P/dPI~ArD ARCO Alaska, Inr~ Post Office ,.,ox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 March 21, 1984 Mr. C. V. Chatterton Commi ss ioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2F-11 Dear Mr. Chatterton' Enclosed complete Since we approval cal 1 me a is a Sundry Notice for the subject well. We propose to this well with our workover rig. expect to start this work on May 12, 1984, your earliest will be appreciated. If you have any questions, please t 263-4970. Sincerely, Area ~D~il ling Engineer JBK/GRU6L53'tw Enclosures Alaska Oil & Gas {;~nu. Commls:;ion Ai Y., h;.}: ;i~..!]:~, ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASK~ t.,,L AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL [] OTHER ~X 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 155' FNL, 1450' FEL, 5ec.33, T11N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) 125' RKB I 6. Lease Designation and Serial No. ADL 25657 ALK 258?, 7. Permit No. 84-41 8. APl Number 029-21095 50-- 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 12. 2F-11 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) Perforate '~ Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other ~ Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [] Altering Casing [] [] Abandonment [] [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc., proposes to complete this well with the Westward Well Service Rig #1. The procedure will be as follows: 1) A mast truck will be utilized to run the CBL/VDL/GR and Gyro. 2) The rig will be moved on location; the BOPE will be nippled up and tested. 3) Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. 4) The well will be completed with 3-1/2", 9.2#/ft, J-55, BTC tubing. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. The BOP equipment will be pressure tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A.5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. Estimated Start: May 12, 1984 i4. I hereby certif,)rt~hat the foregoing is true and correct to the best of my knowledge. Signed Title Area Dril ling Engineer onuse Condition~f Approv~ any: Date Approved by COMMISSIONER Approved Copy ~etu~:ned .~1'~ . In..,, By Order of the Commission Date Form 10-403 Rev. 7-1-80 GRU6/SN26 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate _M~reh 27, 198b Mr. Jeffrey B. Kewln Area Drilling Engineer AP. CO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510 Kuparuk River Unit 2F-!! ARCO Alaska,- !nc. Permit 15o. 84-41 Surf. Loc. 155'FNL, !450'FEL, Sec.33, TI1N, RgE, UM. Btmhole Loc. 987'FSL, 8&S'F5%, Sec. 34, TllN, R9E, UM. Dear Hr. Kewin~ Enclosed ts the approved revised application for pe_rmit to drill the above referenced well. The provisions of the cover letter, dated March 20, 1984 accompanying the original approved permit are in effect for this revision. Very truly yours, _?- ?~? ? / ~'~. V. Chatterton ~ai~mn of Alaska Oi! and Gas Conse~atlon ~~ssion Ene!oeure cc: Department of Fish & Game, Habitat Section w/o enel. Department of Environmental Conservation w/o encl. ARCO Alaska, Inc. I~ Post Office E,. 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 March 21, 1984 Mr. C. V. Chatterton Commi s si oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2F-11 Dear Mr. Chatterton: Due to a change in the bottomhole location, we are resubmitting the application for Permit to Drill Kuparuk 2F-11. Enclosed are: o Diagrams showing the proposed horizontal and vertical projections of the wellbore o A proximity plat o A diagram and description of the surface hole diverter system o A diagram and description of the BOP equipment Since we estimate spudding this well on April 1, 1984, your earliest approval would be appreciated. If you have any questions, please call me at 263-4970. Sincerely, O B Kewin Area Drilling Engineer JBK/JG6L46' tw Enclosures Alaska Oit & Gas Cons. Commis$1o. Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA U~L AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL ~ DEVELOPMENT GAS [] SERVICE [] STR~i~IGRAPH lC SINGLE ZONE [] MULTIPLE ZONE [~ 9. Unit or lease name Kuparuk River Unit 10. Well number 2F-11 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 155' FNL, 1450' FEL, 5ec.33, T11N, R9E, UM At top of proposed producing interval 1387' FSL, 1415' FEL, Sec. 34, T11N, RgE, UM At total depth 987' FSL, 845' FEL, Sec. 34, T11N, R9E, UN 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. RKB 125', PAD 96' ADL 25657 ALK 2583 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 30 mi. NW of Deadhorse miles 845' ~ TD feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 10,085' MD, 6470' TVD feet 2560 19. If deviated (see 20 AAC 25.050) I KICK OFF POINT 500 feet. MAXIMUM HOLE ANGLE 55 o I 20. Anticipated pressures (see 20 AAC 25.035 (c) (2) 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool Amount $500,000 I15. Distance to nearest drilling or completed 2F-10 well 607 ~ surface feet 18. Approximate spud date 04/01/84 2773 psig@_~0OF Surface 3112 .psig@_6:].EQ__ft. TD (TVD) Proposed Casing, Liner and Cementing Program 12-1/4"I 8-1/2" SIZE Casing Weight 16" 65.5# 9-5/8" 36.0# 7" 26.0# 22. Describe proposed program: CASING AND LINER Grade Coupling H-40 Weld J-55 BTC HF-ERW J-55 BTC HF-ERW SETTING DEPTH Length M D TOP TVD 80 29' I 29' 3668 29' I 29' I 28' I 28' 10,057 MD BOTTOM TVD 109' 109' 3697'I 2839' I 10,085© 6470' I I QUANTITY OF CEMENT (include stage data) ± 200 cf 1050 sx AS III & 780 sx Class G 450 sx Class G neat ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 10,085' MD (6470' TVD). A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 9-5/8" casing will be set through the West Sak Sands at approximately 3697' MD(2839' TVD). A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure is 2773 psi. Pressure calculations are based on latest reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Selected intervals will be logged. The well will be completed with 3-1/2", 9.2#, J-55, 8rd tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be (see attached sheet) -23. I hereby certify that the foregoing is true and correct to the best of my knowledge The space below for~ommission ~ ~ CONDITIONS OF APPROVAL Samples required Mud log required ~ Directional Survey required ~YES ~NO ~YES ~O ~ ~YES ~NO Permit number APPROVED BY Form 10401 GRU6/PD17 Approval.date IAPI number SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE ~,,f~u~l.. o-~ ~ ~o /. rzcz-~.,Lz /_/ ~ J~;~o,+ by order of the Commission , Submit in triplicate PERMIT TO DRILL 2F-11 installed and tested upon completion of the job. 2F-11 will be 60' away from 2F-10 at the surface. There are no other close wellbores anywhere downhole. Top of cement for the production string will be placed at 8441'MD, approximately 800'MD above the top of the Kuparuk Sands. Reserve pit fluids will be disposed of down the 9-5/8" x 7" annulus. The 9-5/8" x 7" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. MAR 2 ? 19B4 Alask~ Oil & Gas Anchorage ~ ~ ~ '~ , ' · ~ i_ :.1,.,~'._~_ '. ;~,. ;_:._._ ~ : ~,. ~ ~ _4___ ; ..... :_~_. .............. ----i--:~i~ ·~;- -~mm~ : ~: ': } ~ I:; ~: w'- ~ . ~ ~ ]:~;'] -~--}-'t_.~-:~C'-;~--''~ ':'~' : ~; , i - : ~ : i ' ~ :- I ~ L . ~ I ~ : ~ ~ ~ . , ; ~ ' : , . · ; : , i, - , i : , ii~ ;'.i~ '~ ~ ; I~ ~ 77~ i ,~ ~ ~ i ~'i-i-i -i-~-i-~ -,':~-i Fi-r; -'rT~ '~'~ .... ''~'": ~-"~ ' ~ '~ ~ ' ~ ~ ~~. ~u~_~~_~ ..... ~ ....... ; ul'¢~ i ~ ~ . ) i i ; nnfl I~; ~000 I ~sO00; ~ ;~ ~~ff~-~ooZ ~ '. a-~Z~~ _~ ] . : , , . . I ' 7 F5:; I i l i m 6 Surface Diverter System 1. 16"-2000 psi Tankco starting head. Tankco quick connect assy. 3. 16" X 20" 2000 psi double studded adapter. 20" 2000 psi driiling spool w/lO" si de outlets. 5. 10" ball valves~ hydraulically actuated, w/lO" lines to reserve pit. Valves to open automatically upon closure of annular preventer. 6. 20" 2000 psi annular preventer. ?. 20" bell nipple. I L 1 Maintenance & Ooeration 1. Upon initial installation close annular preventer and verify 6hat ball valves have opened properly. 2. Close annular preventer and blow air through diverter lines every 12 hours. Close annular preventer in the event that gas or fluid flow to surface is detected. If necessary, manually override and close ball valve to upwind diverter line. Do not shut in we.ll un.der any circumstances. 1 6" Conductor f ANNlJLA~ ~ 9 / --'t~ BLiND 7 [ g DIAGRAM ~1 13-5/8" 5000 PSI RSRRA BOP STACK s (- l:m 2 1. 15" - 2000 psi Tanked starting head 2. 11" - 3000 psi casing head 11" - 3000 psi x !2-5/8" - 5000 psi spacer spool ¢. 12-5/B" - SO00 psi x 13-5/8" - 5000 psi drilling spool 5. 13-5/8" - 5000 psi pipe r~ms 6. 13-5/8" - 5000 psi drilling spool w/choke and kill lines 7. 13-5/8" - SO00 psi pipe rmms 8. 13-5/8" - 5000 psi blind rams g. 13-5/8" - 5000 psi annular ACCUMULATOR CAPACITY TEST '1. CHECK AND FiLL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDi~AULiC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREJJ~ OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REI~U~INING AFTER ALL UNITS ARE CLOSED WITM CF~ARGING PUMP OFF. ¢. RECORD ON NADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI RDAAINING PRESSURE. 13-5/B' BOP STACK TEST 1. FILL BOP STACX AND MANIFOLD WI'TW ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACT- ED. PREDETEIUSINE DEPTH I'HAT TEST PLUG WILL SEAT AND SEAT IN WELl. HE. AD. RUN IN LOCK DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PRE~/ENTER AND V. ALVES UP~ OF CI-'IOI~S. DON-~r T~ST AGAINST CLOSED CHOI<~S 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD'FOR 10 MINUTES. 5. INCRFJkSE PRESSURE TO i800 PSI AND HOLE FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR t/'.BJ~.I]]~S. TO ZERO PSI TO TEST VALVES. TEST R~INING UNTESTED MANIFOLD.VALVES, IF ANY, WiTH 3000 PSI UPSTREAM OF VALVE AND ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN TOP SET OF PIPE RAMS AND CLOSE BO1FOM SET OF PIPE RAMS. 10. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES BLEED TO ZERO PSi. 11. OPEN BO'i-rOM SET OF PIPE P~AMS. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND ,:Ca~MS AND RECOVER TEST PLUG. MAKE SURE MA,NIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET iN DRILLING POSiTI0N. 12. TEST STANDPIPE' VALVES TO 3000 PSi. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSi Wi,lq KOOMEY PUMP. V E P: 15. RECORD TEST INFORMATION ON BLOWOUT P.~EVENTER TEST FORM ~IGN AND SEND TO DRILLING SUPERVISOR. 16. PERFORM COMPLE'i'E BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. 1984 Gas Cons: -Commlssior~ }{arch 20, 1984 Mr. Jeffrey B. Kewin Area n~ ~ 1 ~ ~- -- ..~~g Engineer ARCO Alaska, !nc. P. O. Box 100360 Anchorage, Alaska 99510 Re: Kuparuk River Unit 2F-!1 ARCO Alaska, Inc. Permit No. 84-41 Sur. Loc. 155'F~L, !450'FEL, sec. 33, ,I~N, , ~. Btmhole Loc. t!60'FSL, 109!'FEL, Sec. 34, TllN, RgE, l~. Dear M~. Kewin: Enclosed is the approved application for permit to drill the above referenced we!!. If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Nany rivers in Alaska and their drainage systems have been classified as important for the spav~ing or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal l$ater Pollution Control Act, as amended. Prior to co,cueing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention Mr. Jeffrey B. Kuparuk River -2- March ?.0, 1984 equipment so that a repreaentattve of the Comm~.ssion may be present to witness testing of the equt. p~ent before the ~urface easing ~hoe is drilled. %~here a diverter system ia required, please al~o notify this office 24 hours prior to commencing equlp~ent.ln~ta!latton so that the CommI~sion may witness testing b~fore drilling below the ~hoe of the conductor pipe. &n the event of ~uspension or abandonment, please give this office adequate ,dvance notlf~cat~on so that we may have a witness present. Very truly yours, C. V. Chatterton Chai~an of S¥ ORDER OF T~ Alaska Oil and Gas Con~rvatlon C°~i,sion b~ Enclosure cc- Department of Fish & Ga~, Habitat $~ctton w/o encl. D~part~ent of Environmental Conservation w/o encl. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 March 13, 1984 Mr. C. V. Chatterton Commi ss ioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2F-11 Dear Mr. Chatterton: Enclosed are: ° An application for Permit to Drill Kuparuk 2F-11, along with a $100 appliCation fee ° Diagrams showing the proposed horizontal and vertical projections of the wellbore ° A proximity plat ° A diagram and description of the surface hole diverter system ° A diagram and description of the BOP equipment Since we estimate spudding this well on April 6, 1984, your earliest approval would be appreciated. If you have any questions, please call me at 263-4970. Sincerely, ~~e~ln~'~ Ar'u~ur~lling Engineer JBK/JG6L27: tw Enclosures Alaska Oil r~ Gas ;', ~, ," ' ~ ~' ,-,O,;$, '-,OITIIlllS$1011 An,~hora:qe ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~"-"~ STATE OF ALASKA ~'-'~. ALASKA L,,,... AND GAS CONSERVATION CO,,,~vllSSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL DEVELOPMENT GAS [] SERV CE [] SINGLE ZONE [] MULTIPLE ZONE 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 155' FNL, 1450' FEL, Sec.33, T11N, RgE, UM At top of proposed producing interval 1387' FSL, 1415' FEL, Sec. 34, T11N, RgE, UN At total depth 1160' FSL, 1091' FEL, Sec. 34, TllN, R9E, UM 5. Elevation in feet (indicate KB, DF etc.) RKB 125', PAD 96' 6. Lease designation and serial no. ADL 25657 ALK 2583 9. Unit or lease name Kuparuk River Unit 10. Well number 2F-11 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool 12. Bond information (see 20 AAC 25.025) Feder'al Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse miles 1091' (~ TD feet 2F-10 well 60' @ surface feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease I 18. Approximate spud date 9723' MD, 6264' TVD feet 2560 I 04/06/84 I 2773 ° 3112 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 500 feet. MAXIMUM HOLE ANGLE 55 20. Anticipated pressures (see 20 AAC 25.035 (c) (2) psig@_~0°F _psig@ 6150 Surface ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE Hole ~4" 2-1/4" i-1/2" Casing Weight 16" 65.5# 9-5/8" 36.0# 7" 26.0# 22. Describe proposed program: CASING AND LINER Grade Coupling~ H-40 I Weld J-55 I BTC HF-ERW J-55 I BTC HF-ERW Length SETTING DEPTH QUANTITY OF CEMENT MD TOP TVD 80' 29' I 29' 3668' 29' I 29' I I 28' I I 28' 9695 MD BOTTOM TVD 109' 109' 3697'12839' 9723'16264' I I (include stage data) ± 200 cf 1050 sx AS III & 780 sx Class G 450 sx Class G neat ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 9723' MD (6264' TVD). A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 9-5/8" casing will be set through the West Sak Sands at approximately 3697' MD(2839' TVD). A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure is 2773 psi. Pressure ca]culations are based on latest reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Selected intervals will be logged. The well will be completed with 3-1/2", 9.2#, J-55, 8rd tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be (see attached sheet) 23. I hereby~ that the foregoing is true and correct to the best of my knowledge SIGNED //~____~____----¢_.4.~'/~ TITLE Area Drilling Engineer The space/~v~ f~ (Z~m~'sion use' Samples required []YES Permit number APPROVED BY Form 10401 GRUE/PD12 Mud Icg required I-lYES [~O Approval date CONDITIONS OF APPROVAL ' Directional Survey required.~ ' ' APl number ~¢..ES []NO 50- O ?--~ SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE March 20, 1984 by order of the Commission Submit in triplicate PERMIT TO DRILL 2F-11 installed and tested upon completion of the job. 2F-11 will be 60' away from 2F-10 at the surface. There are no other close wellbores anywhere downhole. Top of cement for the production string will be placed at 8441'MD, approximately 800'MD above the top of the Kuparuk Sands. Reserve pit fluids will be disposed of down the 9-5/8" x 7" annulus. The 9-5/8" x 7" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. PERMI:T TO DRILL 2F-11 installed and tested upon completion of the job. 2F-11 will be 60' away from 2F-lO at the surface. There are no other close wellbores anywhere downhole. Top of cement for the production string will be placed at 8441'MD, approximately 800'MD above the top of the Kuparuk Sands. Reserve pit fluids will be disposed of down the 9-5/8" x 7" annulus. The 9-5/8" x 7" annulus will be left with a non-freezing fluid during any interruptions in ~he disposal process. -- ~ ' ~ '--~/~ ~ ~~ · ' '-~-'~r-~-~---~ ~ -~-~-~-f---/4- f- ...... f ................ : ............. : ..... · ~ ~_~L~ , ~ : ~.~_ ~ ~: ....... ~__~_s~ -~t~----?.-~ .... ~- -'4 ..... ~ .......... ~ .......... ~ ...... ~-''--~ .... ~ ~ I :+.4, ..... ...... .......................... ----T~]~~]~i~'~ '. ~T~~]: : 7 : ~ . ~ ; ~ , ; ~, ~ ; ~ : : ~ ; : , , · , ~ ; i i i : ! , -----; ~ ~ : ' ~ TVfl~:5~fl~ F~B~51~B;B~/=B'.: : : : ; , , ~ ! ; , ; , : ' ! ~ ~ ~ : ' ~ . . - . ~ : ; : ; ~ : ~ ; , ; : : ; , , . . . ~ , , . , . ~ ~ : ~ , : ~ ~ ~ ~ ~, : , , . ~ , ~ : ', ~ ~ ~ : , : . , ~ ~ ~ ~ ii ~:': ~T-, '~ ..... ' ' : T ' ~ ~ ' ~ . ~ i . ~ . : , ' , ! i i . ; ~ : ,- . ,' , ~ ~ ........ ~ ~ ~ ; , ' ; : ! '; iii ~ ~ ~ i ' ~, , !, : : ,: ~ , ~ , , .... , '. I : : ~ ' ; : : : ~ ; : , ~ ~ ~ ' : ~ ' i ' ' : ~ ; i : ~ , . ~ ~ ~ ~ ~ , , - , , . I ~ ; ~ ; ' I : : : ! - I , ' . ' ~ ' : : : ~ , . I ' ' ~~: : i ; : T '. i : : i : i i : ; ' : ~: i _ ; : ',_i .... : ; --: : ~. ;:, ~~ ~ ~ :~ ! :~ ~ i~ i:.: , ~ : '-~ ~ ~:.,_: ~'.':~i~ i: : : : : : s : . . : · - , Surface Diverter System 1. 16"-2000 psi Tankco starting head. 2. Tankco quick connect assy. 3. 16" X 20" 2000 psi double studded adapter. 4. 20" 2000 psi drilling spool w/10" side outlets. 5. 10" ball valves, hydraulically actuated, w/lO" lines to reserve pit. Valves to open automatically upon closure of annular preventer. 6. 20" 2000 psi annular preventer. 7. 20" bell nipple.. ii Maintenance & Operation 1. Upon initial installation close annular preventer and verify l~hat ball valves have opened properly. 2. Close annular preventer and blow air through diverter lines every 12 hours. 3. Close annular preventer in the event that gas or fluid t~low to surface is detected. If necessary, manually override and close ball valve to upwind diverter line. Do not shut in well under any circumstances. 1 6" Conductor PRE'VE,N~ 9 '! DIAGRAM ~1 i3-5/8" 5000 PSI RSRRA BOP STACK 1. 16" - 2000 psi Tankco starting beau 2. 11" - 3000 psi casing head 3. 11" - 3000 psi x 13-5/8" - 5000 psi spacer spool 4. 13-5/8" - 5000 psi x 13-5/8" - 5000 psi drilling spool 5, 13-5/8" - 5000 psi pipe rams 6. 13-5/8" - 5000 psi drilling spool w/choke and kill lines 7. 13-5/8" - 5000 psi pipe r~ms 8. 13-5/8" - 5000 psi blind rams 9. 13-5/8" - 5000 psi annular ACCUMULATOR CAPAC]TY TEST BLIND P!PE ~ S 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE WHAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF I"HE REGULATOR.' 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE R~AINING AFTER ALL UNITS ARE CLOSED WITH CHARG1NG PUMP OFF. 4. RECORD ON NADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 13-5/8" BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECX THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACT- E'D. PREDETERMINE DEPTH I~HAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAJ). RUN IN LOCK DOWN SCREWS IN HEAD. 3, CLOSE ANNULAR PREVENTER AND V~&J~'V~S UPS~ O1~ CI-]O~S, DON~'T TEST AGAINST CLOSED CHOI<ES. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR lO M I NUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLE FOR 10 MINUTES. BLEED TO ZERO PSI, 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS, 7. INCREASE PRESSURE TO 3000 PSi AND HOLD FOR 8. ~.~'PRESS~ DOM4~ OF CItOKE ISOLATION VAL.V~S. TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD.VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND ZERO PSI DOWNSTREAH. BLEED SYSTEM TD ZERO PSI. 9. OPEN TOP SET OF PIPE RAMS AND CLOSE BOTTOM SET OF PIPE RAMS. lO. INCREASE PRESSURE TO 3000 PSi AND HOLD FOR lO MINUTES BLEED TO ZERO PSi. 11. OPEN BOTTOM SET OF PIPE RgJ~.S. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. i2. OPEN BLIND RA~qS AND RECDVER TEST PLUG. rAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE S~--F iN DRILLING POSITION. 13. TEST STANDPIPE VALVES TD 3000 PSi. 14. TEST KELLY COCKS AND INSIDE BOP TO $000 PSI WiTH KOOMEY PUMP. 15. RECORD TEST iNFORMATiON ON BLOWOUT PREVENTER TEST FORM SiGN AND SEND TO DRILL.lNG SUPE.qV!SDR. 16, PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (1) Fee (2) Loc ('2 thru 8) '(8) (3) Admin (9/thru 11) (10 and 11) (12 thru 20) (5) BOPE ,,,.U,e~ ., ,.~,..: fq (21 thru 24) Company Lease & Well No. YES NO 1. Is the permit fee attached .......................................... (~/~ / · 2. Is well to be located in a defined pool ........... ~ ........ , ........ 3. Is well located proper distance from property line .................. 4. Is well.located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is well bore plat included ............... ~K/'L 7. Is operator the only affected party ................................. 'i!~ ..... 8. Can permit be approved before ten-day wait .......................... 9. Does operator ha~e a bond in force .................................. L 10 Is a conservation order needed ...................................... ' 11. Is administrative approval needed ................................... REMARKs 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... Is a diverter system required .................................... ~ Are necessary diagrams ~f diverter a~d BO~'equipment attached ,, ~ Does BOPE have sufficient pressure rating - Test to 7~ psig .. Does the choke manifold comply w/API RP-53 (Feb. 78) .................. Additional requirements ............................................. Additional Remarks: CD Geo logy: Engin~,~e,r,i~: HWK _~ LCS,,'c~, WVA ~ JKT ~ HJH ~-~-~-~ rev: 12/08/83 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE (,::' ,I/ ~ ~ O ,~,' i CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. /< ~ ~ ITEM APPROVE DATE YES NO REMARKS (1) Fee :~,~ ...... .:-I thru 8) (3) Admin .~ "J.~?~'~:~,,:> ~ (~' thru 11) (10 and 11) (12 thru 20) (21 thru Is operator the only affected party ................................. Can permit be approved before ten-day wait .......................... ~ 1. Is the permit fee attached ............ · e······m·e·e~e··e··········e 2. Is well to be located in a defined pool ............ ........ ~ ....... 3. Is well located proper distance from property line ............. 4. Is well located proper distance from other wells ............... 5. Is sufficient undedicated acreage available in this pool ...... 6. Is well to be deviated and is well bore plat included .............. 7. 9 Does operator have a bond in force · eeeeeeeeeeeeeeeeeeeeeeeelleee.eeee ~,,~, 10. Is a conservation order needed ...................................... 11. Is administrative approval needed ........................ .......... 12. Is conductor string provided ................................... f~ 13. Is enough cement used to circulate on'condugtor an~ ;urfac~ .... f~f , 14. Will cement tie in surface and intermediate or production strings ... ~/~. 15. Will cement cover all known productive horizons ..................... ~. 16. Will surface casing protect fresh water zones ..... 17. Will all casing give adequate safety in collapse, tension and burst.. ~ .~' 18. Is this well to be kicked off from an existing wellbore ............. 19. Is old wellbore abandonment procedure included on 10-403 ............ 20. Is adequate well bore separation proposed ........................... ~ 21. 22. 23. 24. 25. Is a diverter system required'· ...................................... Are necessary diagrams of diverter and BOP equipment attached ''i;''' Does BOPE have sufficient pressure rating - Test to ~i~q~JD ps . ..~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. Additional requirements ............................................. Additional Remarks: Geology: Engir~e~r. ing: HW-K ~ LC~S ~ BEW HJH WVA ~ JK ~'~-~ INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. bis TAPE VERIFICATION LISTING VP 010,WO~ VERIFICATION L~MTING PAOE 1 * REEL HEADER ** E~VICF NAME :EDIT ATE :B4/04/~7 RYGYN : EEL NAME :~EFL ID ONTTNUATInN # O~MFNTS :LIRRARY TAPE * TAPE HEADER ** ERVICF NAME :FDTT ATE ~84/04/27 RIGTN :0000 APE NAME ONTINI~ATI~N # RKVTOUS T~PE OMMFN~S :LIBRARY TAPE ********** EOF ********** * FTLE WEAD~R ** ~ILE NAME :EDIT E~VICF NA~E : ERS~ON # : 'ATE : A~I~U~ LENGTH : 1024 'ILE TYP~ R~VTOUS FILE * INFbR~A?ION RECORDS ItNIT TYPE CATE SIZE CODE 000 000 016 065 000 000 005 065 000 000 008 065 000 000 002 065 OhO 000 004 065 000 000 002 065 000 000 008 065 000 000 006 065 000 000 004 065 VP 01.0,F102 VERIFICATION LISTING PAGE 2 *********************************************************************************** SCHI.,U~BERGE~ ALASKA COMPUTING CENTER ***********************************************************************************O~PANY = ATLANTIC RICHFIELD COMPANY ELL = 2Fo~! IELD = KUPARUK OUNTY = NORTH sLOPE BOROUGH TAT~ = A~,ASK~ OB ~t.IMBER AT ACC: 69118 UN #1, DATE L~GGED: 8-APR-84 DP I HGH ASI~G = 9,6~5" ~ 3~11' ' BIT SIZE = ~,5" TO 9810' YPE FLUID = X-C POLYMER ENSIT¥ : 10,3 LB/G R~ = 3.050 ~ 65,0 D~ ISCOSITY = 37.0 S R~F : 3,~50 ~ 65,0 DF 'H = 8,5 R~C = ~.840 ~ 65 0 DF 'LI..JID LOSS = 6,1 C3 R, AT BHT : ~,454 ~ 1.4~o0 DF 'ATR~X SANDSTONE ******************************************************************************** VP 01.0.~0~ VE~IFICA?ION LISTING PAGE 3 * DATA FORMAT RECORD ** HTRY ~LoCKS TYPE SIZE 4 1 8 9 0 ATUM SPEC?F?CATIOM NMM SERVICE SMRVICE IP O~D~R # LOG TYP~ EPT FT 0 FLU DI[, OHM~ ? 0 LD ~IL OH~ 7 12 L~ DII, OH~M 7 0 R DIL ~API 7 PHI FD~ PU 42 6~ RHO FDN ~/C3 42 44 HO5 FDM G/C3 42 35 CML FD~ CPS ~2 34 CNL FD~ 'ALI FDN TN 42 28 'R~T ~DN 42 42 NRA FDN 42 PEPR CODE 66 73 65 66 AP! ~P! FILE CLASS ~OD NO. 0 0 0 0 0 0 46 0 0 0 0 0 0 0 0 32 0 0 2 0 0 0 0 0 ! 0 0 02 0 0 03 0 0 3 0 0 0 0 ~ ~2 0 0 ENTRY 1 60 ,I~N 0 SIZE PROCESS SAMPLE LEYEL 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 O 4 0 4 0 4 0 ~EPR CODE 68 68 68 68 6~ 68 68 68 68 68 68 6~ 68 :* DAT~ ** ,EPT 9~3~.5000 SFI,I] iP -3],~000 ~R ~HOB ~ N N IRAT ~, 801 C b · 8~ mN~A ~EPT 9~,00i~8000 SFI,U ;P 24 . 44 GR IHOB ~ 4688 NCNb IRAT 3,4883 RNRA )EPT 9700.0000 SFLU ;P -2~.0000 GR ~HOB 2.~137 NCNL IRAT 3. 754 RNRA )EPT 9600.~000 SFI,U ;P -37.~000 GR 7578 IED 3tR:5000 NPHI 480~.0000 FCNL 3.8~5 ~,7578 TLD 318.5000 NPHI 4~08.0000 FCNL ~.8~5 GR ~,64~6 ~11,81~5 "PHI 1869.0000 FCNL 4.~875 26.~656 52.53t3 NPMI 2.70~ ILM 43.~6 7 DRHO 1~.5000 99 DRHO 1~61.0000 CALI 318,5000 '~.3047 IbM 47,7539 DRHO 446.0000 CALI 111,8125 17 ~594 II,,M 2,~668 1,, 562 8,5000 0,., 80 8,7266 ~,4,~60 8,.. 31 20 156 VP 010.N02 VERIFICATION LTSTING PAGE 4 HOB 2,~703 NCNb RAT 2,~897 RNRA EPT 9500,0000 SFLU P -12,5000 ~os ~.4551 ~CNL R~T ~.0805 RNRA EPT 9~00 OO00 SFLU P - 25:7500 HOB 2,3535 ~ICNL RAT 3,~496 DNRA EPT 9300.0000 SFLU P -22,7656 GR HOB ~,3086 NCNb RAT 4,~9~4 DNRA P. -27253~3 GR ~OB 2.3066 NCNb R~T 4,0391 'EPT 9i00,0000 ~P 24,0000 ~OB ~.~832 NCNb 'R~T 3.5742 PN~A 'EPT 900n 0000 ~FLU P,, 20.~5 ~HOB 2.~0 NCNb fRAT ], ~5 RN'RA ~EPT 8gO0,O000 SFI.,U ;P -29,~500 ~HOB 2,4355 NCNb {RAT ~.]379 ;P~. 17.7656 ~R IHOB ~,4746 MCML ~RAT 3.~910 RNRA )EPT 8 00,0000 ~p 20.7500 ~HOB 2 3789 NCNb ~R~T ~.43~6 PNRA )EPT 860~ 0000 SFLU ~P -25 7500 ~HOB ~ 31~5 ~RAT 3 6641 DN~A )~PT B~00.O()00 SFLU 2726,0000 FCML 3.1953 4,0898 XLD ]05,6875 MPMI 2144,0000 FCNL ].1250 ~R ~31!6250 NPNI 1755 0000 FCNL 4,6016 2,7480 YLD ~.14,3750 1650 0000 FCNL 4:8594 GR 3 9043 1,74i2500 1767 0000 FCNL 4,35~6 3.0723 ~40,1250 NPHI 1787.0000 FCNb ~,~992 GR 28652 ~6317500 NPHI iff91 0000 FCNL 6914 GR 3.6465 7LD 153'2500 1q1~:00008223 ~RFCNb 066 12 NPH 2084,0000 FCNL ~,6641 4,6484 ~46,75~0 2058.0000 FCNL 4..0742 6 ~21,9 TLD 97 ,250 NPHI 1607 0000 FC~L 3 816.4 4.7227 853.0000 52.5313 4.2539 33.8379 686.0000 105.6875 1.4023 48,4375 381,2500 131,6250 2,3516 52,1484 339..5000 ]14.3750 3.2363 50.0000 405.7500 174.2500 2.6133 43.3i05 425,5000 24g,1250 2,5742 43.2129 4O3,0000 263,7500 3,655~ 3g.330 501.7500 153.2500 568,5000 ]21,,4375 4,0586 40,4785 504,7500 ],46.7500 44,67 42~.0000 97,1250 4,4102 CALl IbM DRHO CA[,I DRHO CALI DRHO CALI DRHO CALI DRHO CALl IbM DRHO CALI DRHO CALI DRHO CALl DRHO C A L I DRHO CALl 8.3516 4,3164 0,0400 8,695~ I 104 g,3984 2,4297 o,o3o3 11,7656 3.3770 0.0210 10.6406 2,71~8 0,0298 9.5000 2,6133 0.0063 9.4766 3,70~2 0.05 6 10.0156 ,5301 9,0234 .5547 3,9544 -0,0005 9.6953 4,550B 0,03~7 9,6797 4.5352 VD 010,H02 VERIFICATION LIS?ING PAC, E 5 P -2n.oOnO HnB 2,4160 NCNL RAT 3.4255 EPT 8400.0000 SFT,U P -24.5000 Hn5 2.43o5 NCNL RAT 3.9852 RNRA EDT 8300.0000 ~FI,,U P -30 5000 GR HOB 2~4207 ~CNI, R.~T 3.~641 DNRA EPT 8200 0000 SFLU .P -.28'0844 HOB 2~4512 NC~L R~T ].4844 RNRA 'EDT 810O.O000 8FI, U ,P -25.5000 HOB 2 2891 NCNL 'RAT 3~0391 RNRA ,EDT 8000 0000 . .P. '25,5000 GR IHOB ~.3496 ~CN5 fReT 3,6680 ~NRA ;P -.31.,0000 ~R ~HOB ~.4375 NC~5 IRAT 3,8926 ~NRA }EPT 7~00,o000 SFLU ~P,. -14 7500 IHOB ~: 3008 MCNL {RAT ~.77]4 )~PT 7700,. 0000 ;P -8 7500 GR tHOB ~3457 NCNL {R~T 3.54~8 RNRA )EPT 7~.0000 SFLU ~P' ]965 MCNL ~HOB ~,2500 {RAT 3'1035 RN~A )EPT 7500 0000 SFLU ;p -16 ~500 ~R ~HOB ~ ~773 NCNb ~RAT 3 ~258 RNRA ~24.3750 NPH! 182R.0000 FCNL 3.4277 GR 3 5879 TLD ~30i3750 NPHI 219~ 0000 FCNL 3.6230 ~R )i06.8750 ~PHI 2296.0000 FCNL 3.7500 CR !5039 YLD lO~ 6250 NPHI 241~ 0000 FCNL ] 2617 GR 3.7813 TLD 91,8125 ~PHI 2356,0000 FCNL 3.3867 UR 3 8848 13! 3750 2019 0000 3 9238 ! NPHI. rCNL, ~R 3 8965 I[,D ~49:8'750 ~.~PHI 1733,0000 FCNL 3.6641 ~R 1 5313 ~74.3750 2138.0000 FCNL 3.5977 GR 2.0547 ~7~,6250 NPH! 181.,0000 FCNL 3.53ql 5,0234 TLD 218,0000 NPH! 205~,0000 FCNL .4629 1 5020 IbD 110 :~(6)25 {qPHl' 1791. 00 FCNL 3.7500 C~R 38.8184 533.0000 124.3750 3.6230 36.1328 606.5000 130.3750 3.6895 34.~773 612.0000 106.~750 3,5879 40.2344 74{.O000 103.6250 4.6563 32.0801 695.5000 91,8125 3.8535 43.0664 5i4.5000 131.3750 3.8398 47.6563 472.7500 ~40,8750 1,9873 46,6797 594,0000 ~.74,3750 1.91.80 42,8223 512,0000 173.6250 4,3945 4.0332 S~4,0000 218.0000 1.9248 40,0391 477.,S000 110.5625 DRHO CALl DRHO CALI DRHO CALI IbM DRHO CALl DRHO CAI, I DRHO CALl DRHO CALI DRHO DRHO CALl IbM DRHO ~ALI DRHD fALI 0 0142 10:8828 3 6855 0i0073 11 2266 3.7676 0.0034 10,6250 3,5820 0.0635 10.5000 4.5820 0,0093 10.4375 3,8945 0 0034 11~1406 3.8340 0,0771 10.4609 46 0 9~6563 1,8516 0034 :5391 4,5664 0,0547 10.0625 1.~809 0,0034 9,9141 VP 010,H02 VERIFICATION LTSTING PAGE 6 EPT 7400.0000 P -23,0000 OR HOB 2.3008 NCNb RAT 2.~672 DNRA EPT 7300.0000 SFLU P -24.2500 CR HOB 2.]887 NCNb RAT 3,2051 DNRA EPT 7200.0000 SF[.U P. '21,5000 ~R HOB 2.3613 ~CNb RAT 3.40~2 RNRA EDT 7!00.0000 SFLU P.. 26! 0000 HOB 2. 4102 NCNb RAT 3.3848 RNDA EPT 7~00 0000 SFLU P~. -2~7500 ~R HOB ?.3340 ~IC~L RAT 3,4297 RNRA EPT 6800.~05QOO SFLU RAT 3.4063 ~A 'EPT 6700,~000 SFLU .P_ -24, 844 gR 'HOB 2,~988 NCML 'R~T 3.~332 ~NRA ~EPT 6600 0000 Sf'LU ;P.. -26.~000 ~R :HOB ~,2949 NCNL IR~T 3.0859 R. NRA ~EPT 6500,0000 SFLU ;P -23,1<~00 GR ~HOB 2.... 38 NCNb ,R~T 3.2383 ~NRA )EPT 64.00 bOnO 8FI,,U IP,. -25 5000 ~R ~HOB 2 31n5 NCNb )R~T 3 ~695 RNRA 3.2461 7~,1250 259~,0000 FCNL 3.!992 GR 3.5664 9{.~875 ~PHI 2546.0000 FCNL 4.0000 CR 2 2402 ~12:3750 ~PH! 2152.0000 FCNb 4.0781 GR 154:5000 1755,0000 FCNL 3.g102 2,4473 ~03.3125 NPH! oooo PCNL 3'0391 lbo 109,3125 NPHI 2060,0000 FCNL ~.8320 GR 94.7500 NPHI 2~2~.0000 FCNL 4.0000 ~..]340 12~,o625 NPHI 0000 FCNL 2,~852 II,,D ~23,,J250 NPNI 000 FCN[,, $16,6250 2150,0000 FCN.L 3.5801 2,7012 116.0000 NPHI 2236,0000 FCNI., 3,5508 5.1055 30.175B 812.0000 78.1250 3.8340 36.0840 636,5000 9~.1875 2.445~ 39,5996 527.5000 ~12.3750 3.1387 385254 448:7500 154.5000 2,6641 40.~367 606.0000 103.3125 3.4336 29,1504 727,0000 109.3125 4,1289 40.0879 606.0000 94.7500 2.8301 4'1,8457 580,0000 121,0625 3,0762 34,~309 661,0000 123.1250 2.9805 36 8164 600:5000 $16.6250 3 0313 37 070 62~ ~000 116 0000 DRHO CALI DRHO CALX DRHO CAbI DRMO fAbI IbM DRHO CALI IbM DRHO CALl DR~O CALI DRHO CAb! DRRO CALI DRMO CALl DRHO CALl 5.1094 0,0015 9,9141 3.882.8 0.0000 9"8984 2.~711 O, 034 10.0234 3.1055 0.0703 10.4375 2. 6250 -0!0044 9 89~4 3,44~4 0.0259 9.7~09 4 0977 o2o12 9,6563 ,006 10.0156 3 0625 0:0181 9,7813 2.9453 0,0024 9'8203: 2.9785 0,0298 9.9531 VP Ol0.H0~ VE,~IFIC,.ATION LISTING PAGE 7 EPT P HOP., R~T EPT P. EPT P HOB R~T EPT P~. EPT .p 'R~T ~EPT ;P ~HOB ~EPT ~HOB IR~T )EPT ~HOB IRAT )EPT ;P ~HOB IRAT )~PT ~P 6300 o0o0 - 7 5Oo 2.3867 3.2.91 0 6200.0000 -26.5000 2,3320 3.0898 6100.0000 -25.7500 9.3320 3.2480 6000.0000 -26.2500 2.3223 3,R164 5900.0000 -28.7500 3,4453 5800 0000 -3017344 2.3047 3.1895 5700 000.0 -28:2344 ~,2773 3.65~2 5~00 ~8oo -3~ ~. oo ~ ~262 3 566 5500 0000 -3~ ~500 2 ~754 3 9805 5400.0000 -3d.4688 3.8175 SFLU NCNb SFLU NCNb ~NRA SFI, U ~R NCNb RNRA SFLU ~R NCNb ~NRA NCNb RNRA SFLU dR RNRA ~R NCNL WN~A ~FLU NCNb DNRA SFLU NCNb RNDA SFLU ~R NCNb RNRA 5300 0000 SFLU ~ ....68 NCNb ~.9043 130.3750 2048.0000 FCNL 3.7637 CR ~.5059 103.6875 NPH! 1~95 0000 WCNL 3:9316 GR 2.4961 122.4375 NPHI 2086.0000 FCNL 3.8809 114,2500 NPH! 2298.0000 FCNb 4.5586 GR 2 3789 119i6875 NPHI 1~24 0000 FCNL 3,5625 2.4551. ~0].9375 NPHI 2008,0000 FCNL 3.4453 GR 2,4395 ~07~2500 NPH! 2~04,0000 FCNL 4.6406 ~.4375 0000 1,89 '21,09 GR . 2,3281 TLD 1.01,06~5 NPHI 192 .0000 FCNL 4.9141 GR ,,500 113, NPHI 205~,~000 . .961 GR ~,2695 lbo I12,3125 NPHI 1748.0000 FCNL 3.2070 3~.0859 544.0000 130.3750 2.8301 33.9355 481.7500 103.6875 2.9707 36,7188 537.5000 122.4375 2.9609 46.8262 503 7500 114:2500 2.7910 40, 119.6875 2.9102 34,912! 582,5000 103.9375 2.7520 43,6523 453.~2500 1.07.~500 2,~906 4~,4316 449.7500 115.5000 2,6895 48'8281 391 ~:7500 101.0625 2 ~875 46 891 457 0000 113 2500 2 8047 48!2910 42! 0000 DRHO CAI, I DRHO CA[.I DRHO ! DRHO CAI, I DRHO CA£,I DRHO CAt. I DRHO CALI DRHO CALI DRHO CAI, i ILM DRHO CALl RHO CAI, 387 9,5938 2.7500 0.0200 q.9766 2.9141 0,0459 9,9922 2.8750 O938 2 6934 0!0854 9 6797 2.~535 0, 117 10,5156 2,~ 41 O, ~22 10.3047 2,6934 0,0723 9,9141 ,6563 0000 7266 .70422 ~0, 430 10,4141 2,4941 0.0288 I0.0000 VERIFICATION LISTING PAGE 8 RAT 3.~906 EPT 5~00.0000 SFT.,U P. -35 2500 ~R HOB ~:2500 ~{CNL RAT ].7734 PNRA EPT 5100.0000 p. -36.0000 GR HOB 2.2715 ~CNL R~T 3.5664 EPT 5000.0000 P. -37 5000 ~R HOB ~:~539 NCNb RIT 4.07R1 ~N~A EPT 4~00 ~000 SFt, U RAT 3.4746 4Roo oooo HOB ~,2813 RAT 3.941,8 RNRA EPT 4~0o 0000 SFLU p~ - 3~:96R7 HOB ].22~7 ~C~L 'RAT .73R3 PNRA 'EPT 4600,0000 SFI,U ;p.. -36,5000 IHOB ~.~1 ~CNL IRAT 3.,, 5 ~EPT 4500 0000 ~FLU )EPT 4,~00.,0000 SFT.,U ;p. 40,7500 ~R tHOB 2.,~441 ~IC~h IR~T 1,47~5 RNRA )EPT 4300.0000 SFLU ;p. -3~,500o GR ~HOB ..9575 NCNb ~R.AT 3.53oi PNRA )EPT 4~00 0000 ,,.I~LU ~p -42:4688 ~R 4.1484 2,7~13 99.~500 1975.0000 FC~L 4.6133 2.2266 TbD 113,3750 ~PNI 1767.0000 FCNL 4.2305 3.1641 188~.0000 FCN[, ~.BO08 7 31~5 1974.0000 FCNI., 3.4688 2,a219 97.56~5 1~25.0000 FC~L 3.9277 3,1,973 90.,~1~5 ~'PHI 1958, 000 FCNL ~.5352 3,7324 84.0625 lo9~,0000 FCNL 3.5203 3.~406 ~23, NP igO0,~625 000 FCNL ~ 5645 GR . 5879 Ti~D 9375 NP~I 0000 FCNL 3.~871 77,8125 ~PMI 1866,0000 FCNL 3,29'30 4,~328 86. 125 NPHI 112.3125 3.761.7 45.0684 427.7500 99.~500 41.7969 417.5000 113.3750 3.7695 50.4395 393,2500 8~.6875 3.3o4 39.7461 569.0000 77,31,25 4.0859 46.14~6 464.5000 97,56~5 4,371! 44,0430 431..~000 90.81~5 · 3.2949 35,5957 564.0000 8~,0625 ~.5117 49,121 533,000~ ~23.0625 5.2500 39.1..113 464.5000 86.9375 4.{992 40,0879 566.5000 7~.8125 6,5039 40.4297 DRHO CALI Ibm DRHO CALl: DRHO CALl ILW. DRHO CALI DRHO CALl DR}40 CALI ! I.,~ DRHO CALI DRHO DRHO CALl DRHO CALl DRHO 3.1,035 0.0225 10.8828 2.4453 10.4375 3.4191 0.0425 11.1641 4.1133 0 0498 10:8047 2.6387 0.0420 1~,1797 3,8594 0,00o5 ~,7266 .03 11.7656 3,46~9 0'0337 12,0078 3,9727 o,0298 12.2500 3,~.176 . 64.5 1.,4531 5,55~6 0,014:2 CP 010,H07 VERIFICATION L%$?ING PA~E 9 ?~.P734 NCNb leSO EPT 4~00.00~0 SFLU 5 P~ -4~.21~7 ~R 94 HOB 2 2734 ~CNL ~887 R~T ~0977 ~NRA ] HOB 2 !953 MCNL !P98 RAT 3'.48'24 RNRA 4 EPT 3~00.0000 SFI,U 5 P. -44.~5~0 ~R 87 HOB 2.t660 NCNb X864 R,~T 3.~164 RNRA 3 EPT 3800.0000 SFLU 46 p, -2o.2500 ~R 59 HOB 1.9834 NCNb 1379 RAT 3.9395 ~NRA 4 EPT 379~.5000 SFLU ]2 R~T 4.~695 RNRA 4 FILM TR~I[,E~ ** 'ILE N~ME :EDIT .00! E~VICE WA~E : 'ILE TYP~ : ~XT FILP NA~E : .0000 .~109 .1953 .7500 .0000 .5391 .4512 .5000 .4883 .0000 .0000 .6660 .~187 .5000 0000 '4,4i4 7188 ::x 7 ,0000 .0977 FCNI, NP~II FCNI, GR IL9 NPHI FCML NPHI FCNI., MPHI FCNL gR NPHI FCNL CR EOF ********$* 46~.7500 86.31~5 5.9]75 50.0488 531.0000 94.7500 3.3340 39.45~! 440,5000 81.5000 6.5~95 45.31~5 508.2500 87.0000 35.06~5 50.6816 310.2500 59.5000 56.6406 338,~7500 52.~187 CAI., I DRHO CALI ~L~ DRHO CAI, I DRHO CALI IbM DRHO CALI DRHO CALI 12.1250 5.37~9 0.0557 12.7266 ~.80~7 '0.0317 11,6641 5 5703 0i0088 1~ 0078 20~0!0000 0 3802 8 9766 ooo 3984 20 8!0 9687 :* TI. PE TRAILER ** ~ATE :84/04/27 'APE NAiF .. :0118 :ONTTNUATI~N # :rtl. IEXT TAPE NA~E : ~OMMFNTS :I, IRRARY TAPE :* RFEL TRAILER ** ;ERVICE MA~E :.EDIT )ATE :~4/04/~7 VP OlO.~O~ VEPlFICATION LISWING PAGE RIGIN : ONTINUAWI~N # cO1 EXT RFET, NA~E OMMFNTS :[,I~R~RY ~APE
