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184-040
1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: ______________________ Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 8725'feet None feet true vertical 6260'feet None feet Effective Depth measured 8490'feet 8152'feet true vertical 6089'feet 5848'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" J-55 8181' MD 5869' TVD Packers and SSSV (type, measured and true vertical depth) 8152' MD 1954' MD 5848' TVD 1798' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 3575' 2851' Burst Collapse Production Liner 8675' Casing Structural 6246'8704' 3540' 121'Conductor Surface Intermediate 16" 9-5/8" 80' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 184-040 50-029-21094-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025657 Kuparuk River Field/ Kuparuk River Oil Pool KRU 2F-10 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 326 Gas-Mcf MD 1290 Size 121' 4228 1264812 68 159449 177 N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 272 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Baker FHL Rtvbl. Packer SSSV: Baker FVL Sfty Vlv (locked open) James Ohlinger james.j.ohlinger@conocophillips.com (907) 265-1102Staff CTD Engineer 8278-8302', 8370-8389', 8407-8466' feet 5938-5955', 6003-6017', 6029-6072' feet Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Anne Prysunka at 8:40 am, Nov 02, 2022 Originated: Delivered to:8-Sep-22Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL #1 2F-10 50-029-21094-00 907743115 Kuparuk River Multi Finger Caliper Field & Processed 29-Aug-22 0 12345678910PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:PTD:184-040T36989Kayla JunkeDigitally signed by Kayla Junke Date: 2022.09.09 09:36:57 -08'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-08-26__Run2_15865_KRU_2F-10_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 15865 KRU 2F-10 50-029-21094-00 Caliper Survey w/ Log Data 26-Aug-22 (run 2) DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD:184-040 T36948 Kayla Junke Digitally signed by Kayla Junke Date: 2022.08.30 12:37:23 -08'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-08-20_20231_KRU_2F-10_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 20231 KRU 2F-10 50-029-21094-00 Caliper Survey w/ Log Data 20-Aug-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD:184-040 T36916 Kayla Junke Digitally signed by Kayla Junke Date: 2022.08.24 10:47:35 -08'00' Ima~ ect Well History File Cove~age 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. Organizing (done) RESCAN Well History File Identifier DIGITAL DATA [] Color items: Grayscale items: [] Poor Quality Originals: Other: Diskettes, No, Other, No/Type OVERSIZED (Scannable) [] Maps: [] Other item s scanna hie by large scanner OVERSIZED (Non-Scannable) NOTES: BY: BEVERLY Project Proofing BREN VINCEI'~R~ARIA LOWELl. '~ : Logs of various kinds [] Other DATE: ~]~ IS/ BY: BEVERLY BRE~;) SHERYL MARIA LOWELL DATE: ~'~ Scanning Preparation x 30 = . BY; BEVERLY BRE.N(~ SHERYL MARIA LOWELL Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~, YES Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES BY; BEVERLY E~REN VINCENT~ARIA LOWELL (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIREO ON AN INDiVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) ReScanned (individual page [special attention] scanmng completed) NO NO RESCANNEDBY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ General Notes or Comments about this file: Quality Checked (done) 10/25/02Rev3NOTScanned.wpd • ConocoPhillips ~~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 3, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • a \~~'~ ~p liar v; Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRL)). 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 cement was pumped October 27 and October 30, 2008. The corrosion inhibitor/sealant was pumped November 2, 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. ri a, ~ ~ r,' _ ,~ r r~~ mcere y, ~~~ ~ ~~ < _s ~ ~;; Perry in ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off 'i Report of Sundry Operations (10-404) Kuparuk Field rlatp 11 /3/2008 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 bbis ft al 2F-01 183-183 88' 13.10 21" 10/30/2008 4.68 11/2/2008 2F-04 183-190 48" NA 48" NA 25.5 11/2/2008 2F-07 184-020 10' 3.00 22" 10/27/2008 4.25 11/2/2008 2F-08 184-021 SF NA 20" NA 2.55 11/2/2008 2F-09 184-036 18" NA 18" NA 1.7 11/2/2008 2F-10 184-040 22" NA 22" NA 1.28 11!2/2008 2F-12 184-043 20" NA 20" NA 2.12 11/2/2008 2F-15 183-172 93' 10.10 10" 10/30/2008 3.82 11/2/2008 2F-16 183-177 42' 5.90 9" 10/27/2008 1.28 11/2/2008 2F -10 (PTD 1840400) failed TIFL . . Page 1 of 1 Regg, James 8 (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Thursday, September 06, 2007 9:05 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: 2F-10 (PTD 1840400) tailed TIFL Attachments: 2F-10 schematic. pdt; 2F-10 90 day TIO plot.git r:J qt 1--~\ol \(ß~ 1 Tom & Jim, Kuparuk gas lifted producer 2F-10 (PTO 1840400) tailed a TIFL on 09/05/07 and has been added to the SCP report. The TIO immediately prior to SI tor the TIFL was 150/1250/1000. I> leaking GL V is suspected. Slickline will trouble shoot the tubing leak and repair it possible. v Attached is a schematic and a 90 day TIO plot. Please let me know if you have any questions. «2F-10 schematic. pdt» «2F-10 90 day TIO plot.git» Brent Rogers Problem Wells Supervisor 659-7224 5'~NED SEP 2 7 2007 9/25/2007 day TIO plotgtf9!25/2Üü7 Internet Fiies/OLK24/2f' t1îe:l!/C /temprremporüi) . . KRU 2F-10 API: 500292109400 Well Type: PROD Anole (âJ TS: 45 deo (âJ 8277 SSSV Type: TRDP Orig 3/31/1984 Angle @ TO: 43 deg @ 8725 Completion: sssy Annular Fluid: Last W/O: Rev Reason: NEW GLD (1954-1955, Reference Loa: Ref Loa Date: Last Update: 7/26/2006 00:3.500) Last Tao: 8292' RKB TO: 8725 ftKB Last Tao Date: 7/4/2006 Max Hole Anole: 53 de ~I Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 80 80 62.85 H-40 Gas Lift SUR. CASING 9.625 0 3585 2857 36.00 J-55 Mandre/Nal\ie PROD. CASING 7.000 0 8704 6245 26.00 J-55 1 (2128-2129, I.wwi; Size Top I Bottom I TVD I Wt I Grade I Thread I 3.500 0 I 8181 I 5869 I 9.30 I J-55 I EUE 8RD I 1!_~_.iVi:iìi! @tìtt¡ltKtt~tttIml1thtt¿lèfì;%;;~&) x", }~@NTh, Interval TVD Zone Status Ft SPF Date Tvoe Comment Gas Lift 8278 - 8302 5938 - 5955 C-4,UNIT C 24 0 5/18/1998 Sqz Mandre/Nal\ie B 2 (4649-4650, 8370 - 8389 6003 - 6017 A-5 19 4 4/15/1984 IPERF 90 deg. Ph; 4" Schlum. CSG 8407 - 8466 6030 - 6072 A-4 59 4 4/15/1984 IPERF 90 deg. Ph; 4" Schlum. CSG .Stimlã Y' Gas Lift Interval I Date I Type Comment I MandrelNal\ie 8278 - 8302 5/18/1998 CEMENT 2.70" MILL IN CEMENT SHEATH 3 1~(,\11¡::¡::7¡:: (6574-6575, St MD TVD Man Man Type VMfr V Type VOD Latch Port TRO Date Vlv Mfr Run Cmnt 1 2128 1916 MMH FMHO GLV 1.0 BK 0.156 1310 7/18/2006 Gas Lift 2 4649 3521 MMH FMHO GLV 1.0 BK 0.188 1340 7/23/2006 MandrelNal\ie 3 6574 4790 MMH FMHO GLV 1.0 BTM 0.188 1333 7/18/2006 4 4 8100 5812 MMH FMHO OV 1.0 BTM 0.188 0 7/19/2006 (8100-8101, Depth TVD Tvpe Description ID 1954 1798 SSSV Baker 'FVL' 'Locked Open 9/19/90' 2.810 8138 5839 PBR Baker 3.000 PBR 8152 5849 PKR Baker 'FHL' Retr 3.000 (8138-8139, 8168 5860 NIP Cameo '0' Nipple NO GO 2.750 00:3.500) 8180 5868 SOS Cameo 2.992 8181 5869 TTL 2.992 Date I Note 6/7/1998 13000# Tree PKR MO/1212005 WAIVERED WELL: IA xOA COMMUNICATION (8152-8153, 00:6.156) NIP (8168-8169, 00:3.500) TUBING (0-8181, 00:3.500, 10:2.992) 50S (8180-8181, 00:3.500) Perf (8278-8298) - CEMENT SQUEEZE (8278-8302) m Perf m.... (8370-8389) - - - - = . ... Perf (8407-8466) .-......--. ... ........ .- "m STATE OF ALASKA '" ALAS, ~ OIL AND GAS CONSERVATION COMMISS~,_,.,I REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate X Plugging Pull tubing Alter casing Repair well Perforate 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 96' FNL, 1460' FEL, Sec. 33, T11N, R9E, UM At top of productive interval 1402' FNL, 1576' FEL, Sec. 34, T11N, At effective depth 1463' FNL, 1343' FEL, Sec. 34, T11N, At total depth 1481' FNL, 1276' FEL, Sec. 34, T11N, R9E, UM R9E, UM 12. Present well condition summary Total Depth: measured 8 7 true vertical 6 2 6. Datum elevation (DF or KB) RKB 125 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2F-10 9. Permit number/approval number 84-40 10. APl number 5o-029-21094-00 11. Field/Pool Kuparuk River Field/Oil Pool R9E, UM 25 feet 60 feet Plugs (measured) None Effective depth: measured 8 6 2 3 true vertical 61 85 feet Junk (measured) None feet Casing Length Size Structural Conductor 80' Surface 3 5 4 0' Intermediate Production 8675' 7" Liner Perforation depth: measured 8278'-8302', true vertical 5937'-5954', Cemented Measured depth True vertical depth 225 Sx CS II 121 ' 1 21' 1020 Sx AS III & 3575' 2851' 780 Sx Class G 250 Sx Class G 8 7 0 4' 6 2 4 6' & 250 Sx AS I I 6" 9-5/8" 8370'-8389', 8407'-8466' 6242'-6255', 6269'-6134' Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., J-55 @ 8181' Packers and SSSV (type and measured depth) Packer: Baker FHL @ 8152'; SSSV: Baker FVL @ 1954' (Locked out) _ _ 13. Stimulation or cement squeeze summary Fracture stimulate 'A' Sands on 6/21/97. Commission Intervals treated (measured) 8370'-8389', 8407'-8466' ,~,,, ,,.... _as _0ns. Anchorage Treatment description including volumes used and final pressure Pumped 187.8 Mlbs of 20/40 & 12/18 ceramic proppant into formation, fp was 5100 psi. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 298 291 421 1375 124 575 521 715 1385 133 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. Signed ~.f,/~"~'/_,,, f,.~(' '~"~"c~;"'Title Wells Superintendent Form "~0-404 R~v 06/15/8'~ Date SUBMIT IN DUPLICATE ARCO Alaska, Inc. ~,UPARUK RIVER UNIT '~, WELL SERVICE REPORT '~' K1(2F-10(W4-6)) WELL JOB SCOPE JOB NUMBER 2F-10 FRAC, FRAC SUPPORT 0604970927.1 DATE DAILY WORK UNIT NUMBER 06/21/97, REFRAC "A" SANDS DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 2 (~) Yes O NoI ® Yes O No DS-GALLEGOS BLACK FIELD AFC~ CC~ DAILY COST ACCUM COST ESTIMATE KD1269 230DS28FL $1 51,327 $178,631 Initial Tb.q Press Final Tb.q Press Initial Inner Ann Final Inner Ann I Initial Outer A~rl- 'J Final Outer Ann 1550 PSI 7100 PSI 700 PSI 700 PSII 200 PSI! 200 PSI DALLY SUMMARY PUMPED "A" SAND FRAC. SCREENED OUT IN 10 PPA FLAT STAGE W/187,757 LBS OF PROP INJECTED IN FORMATION (22,573 OF I I 20/40 & 165,184 OF 12/18). TIME 07:00 09:45 10'-!5 LEFT 22,236 LBS OF PROP IN TUBING / WELLBORE. MAXIMUM PRESSURE 7300 PSI W/F.G.=.83 LOG ENTRY MIRU DOWELL SCHLUMBERGER, APC & LRS. HOLD TGSM (JOB OVERVIEW, MUSTER POINT W. ELLHOUSE HINGES) - 13 ON LOCATION. SET TREESAVER & PT BACKSIDE LINES TO 4200 PSi. PT HI PRESSURE LINES TO 9000 PSI. BROUGHT IA PRESSURE UP TO 2000 PSI. 11:00 12:15 14:45 16:30 PUMP BREAKDOWN W/50# XL GW F/28 TO 15 BPM. PUMPED TOTAl OF 393 BBLS. MAXIMUM PRESSURE 7300 PSI & ENDING PRESSURE 3373 PSI. ISIP = 2059 PS! (F.G.= .'?9) SD FOR CLOSURE. PULSED 2 BBLS TWICE. MONITOR PRESSURE. PUMP DATAFRAC W/50# XL GW F/5 TO 15 BPM. PUMPED TOTAL OF 238 BBLS. MAXIMUM PRESSURE 5100 PSI & ENDING PRESSURE 3597 PSI. ISIP = 2311 PSI (F.G.=.83). SD & MONITOR PRESSURE F/CLOSURE. DETERMINE CLOSURE @ 17 MINUTES (ADJUST PAD F/485 TO 580 BBLS). PUMP FRAC W/50# XL GW F/5 TO 15 BPM. SCREENED OUT IN EXTENDED 10 PPA STAGE (ADDED 50 BBLS TO10 PPA FLAT DESIGN). MAXIMUM PRESSURE 7100 PSI. PUMPED TOTAL OF 1700 BBLS. PUMPED 209,993 LBS OF PROP (22,573 LBS 20/40 & 187,420 LBS 12/18). INJECTED 187,757 LBS OF PROP IN FORMATION W/10 PPA OF 12/18 @ PERFS. LEFT 22,236 LBS OF PROP IN WELLBORE/TUBING. STARTED RD. DEPRESSURED IA TO 500 PSI (BUILT BACK TO 700 PSI) & RD LRS. REMOVED TREESAVER (ALL CUPS RETURNEDI. CONTINUE RD. RD COMPLETE W/DS LEAVING LOCATION. NOTIFIED DSO, TURN OVER TO PRODUCTION AWAITING CTU CLEANOUT. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $945.00 APC $8,400.00 $8,400.00 ARCO $300.00 $300.00 DOWELL $135,527.00 $135,527.00 HALLI BURTON $0.00 $6,562.00 LITTLE RED $7,100.00 $9,960.00 U-I $0.00 $16,937.00 TOTAL FIELD ESTIMATE $151,327.00 $178,631.00 ARCO Alaska, In/ 'O .~Subsidiary of Atlantic Richfield Company ?.,¥- I~ ITRACTOR ~ REMARKS IFIELD- DISTRICT, STATE IOPERATIO, N, AT REPORT TIME CC"; "-'"--' WELL SERVICE REPORT DAYS i DAT ~ ?_,:50 IH lo [-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Temp' 1Chill Fact°r I VisibilityJWindVel'Report OF OF miles KUPARUK WELL 2F-10 'A° & 'C° SAND REFRACTURE PUMP SCHEDULE GELLED WATER FRACTURE TREATMENT 6120/89 ST, aGE. FLUID CLEAN VOLUME PUMP RATE PROP. CONC. PROPPANT PROPPANT WT DIRTY VOLUME HIT PERFS DESCRIPTION BBLS BPM PPG DESCRIPTION LBS STG/CUM BBLS 1 GW PRE-PAD 175.0 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 10712 5 GWw/6 PPG 67.2 25 6 16120 M CARBO-LITE 16940 6 GWwl8 PPG 70.2 25 8 16/20 M C^RBO-LITE 23599 7 GW wi10 PPG 65.9 25 1 0 16/20 M CARBO-LITE 27694 8 GW w/12 PPG 42.5 25 1 2 16/20 M CARBO-LITE 21428 9 SLICK DIESEL FLUSH 73.0 +SV 2 5 0 - - 0 0 175/175 75 675/ 850 250 65/ 915 925 75/ 990 990 85/ 1075 1065 95/ 1170 1150 95/ 1265 1245 65/ 1330 1340 73/ 1403 1405 16120 M CARBO-LITE = 105391 LBS TOT,N. GELLED WATER = 1294.2 BBLS TOTAL MUSOL = 0.0 BBLS TOT,N_ DIESEL = 48.7 BBLS TOTAL SUCK DIESEL = 73.0 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 intentionaJly undedlushed by 2 bbl. The blender tub should be bypassed at flush. All fluids should be maintained to at least 100 F on the surface. RECEIVED J U L - ? ~qi! & Gas Cons. Coi'~:,n~o ...... ,, KUPARUK WELL 2F-10 'A' & 'C' SAND REFRACTURE PUMP SCHEDULE GELLED WATER FRACTURE TREATMENT 6~20/89 STAGE FLUID CLEAN VOLUME PUMP RATE PROP. CONC. PROPPANT PROPPANT WI' DIRIY VOLUME HIT PERFS DESCRIPT[~ BBLS BPM PPG DESCRIPTION LBS STG/CUM BBLS 1 GW PRE-PAD 175.0 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 16940 6 GWw/8 PPG 70,2 25 8 16/20 M CARBO-LITE 23599 7 GW w/10 PPG 65,9 25 1 0 16/20 M CARBO-LITE 27694 8 GW w/12 PPG 42.5 25 1 2 16/20 M CARB(~LITE 21428 9 SUCK DIESEL FLUSH 73.0 +SV 25 0 - - 0 0 175/ 175 75 675/ 850 250 65/ 915 925 751 990 990 85/ 1075 1065 95/ 1170 1150 95/ 1265 1245 65/ 1330 1340 73/ 1403 1405 16/20 M CARBO-LITE = 105391 LBS TOTAL GELLED WATER = 1294.2 BBLS TOTAL MUSOL = 0.0 BBLS TOTAL DIESEL = 48.7 BBLS TOTAL SUCK DIESEL = 73,0 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 bi:d. The blender tub should be bypassed at flush. All fluids should be maintained to at least 100 F on the surface.. R E C E iV J U L - 7 _&tssks Oi~ & ISas Cons. Com;'nissia-.;: Ar~',t~orage KUPARUK WELL 2F-10 °A' & 'C' SAND REFRACTURE PUMP SCHEDULE GELLED WATER FRACTURE TREATMENT 6~20~89 ST/~ FLUID (3_F_,N~IVOLUME PUMP RATE PROP. ~. PROPPNNIT PROPPANT WT DESCRIPTION BBLS BPM PPG DESCRIPTION LBS DIRTY VOLUME HIT PERFS STG/CUM BBLS 1 GW PRE-PAD 175.0 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 10712 5 GW w/6 PPG 67.2 25 6 16/20 M CARBO-LITE 16940 6 GWw/8 PPG 70.2 25 8 16/20 M CARBO-LITE 23599 7 GW w/10 PPG 65.9 25 1 0 16/20 M CARBO-LITE 27694 8 GW w/12 PPG 42.5 25 1 2 16/20 M CARBO-LITE 21428 9 SLICK DIESEL FLUSH 73.0 +SV 2 5 0 - - 0 0 175/ 175 75 675/ 85O 25O 65/ 91 5 925 751 990 990 851 1075 1065 95/ 1170 1150 95/ 1265 1245 65/ 1330 1340 73/ 1403 1405 16/20 M CARBO-LITE = 105391 IRS TOT/~I_ GELLED WATER = 1294.2 BBLS TOTAL MUSOL = 0.0 BBLS TOTAL DIESEL = 48.7 BBLS TOTAL SUCK DIESEL = 73.0 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 intentionaJly 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 ~ OIL AND GAS C,C~SERVATI~ OOMMi,.~31ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Operation Shutdown __ Stimulate X Plugging Perforate Pull tubing Alter casing Repair well Pull tubing Other 2. Name of Operator ARCO Alaska. Ins. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service Location of well at surface 96' FNL, 1460' FEL, Sec. 33, T11N, R9E At top of productive interval 1402' FNL, 1576' FEL, Sec. 34, T11N, R9E At effective depth 1450' FNL, 1425' FEL, Sec. 34, T11N, R9E At total depth 1481' FNL, 1296' FEL, Sec. 34, T11N, R9E 12. Present well condition summary Total Depth: measured true vertical 8 7 2 5' feet 6 2 61 ' feet Plugs (measured) 6. Datum elevation (DF or KB) RKB 127' 7. Unit or Property name Kuparuk River Unit 8. Well number 2F-10 Producer 9. Permit number/approval number ~4-40 10. APl number ,50-029-21 07700 11. Field/Pool Kuparuk River Oil Pool feet Effective depth: measured 8 6 23' feet true vertical 6186' feet Junk (measured) Casing Length Structural Conductor Surface 8 O' Intermediate 3 5 7 5' Production 8 7 0 4' Liner Perforation depth: measured 8278 '-8302', true vertical 5938'-5955', Size Cemented 1 6" 9-5/8" 1020 Sx A.S. III 7" 250 Sx Class "G" 8370'-8389', 6003'-6017', Measured depth 80' 3575' 8704' 8407'-8466' MD 6030'-6073' TVD Tubing (size, grade, and measured depth) 3 1/2", J-55 9.3 #/ft., EUE 8rd IPC, 818' Packers and SSSV (type and measured depth) SSSV: Baker FVL 1954', Packer: Baker FHL 8152' True vertical depth 80' 2851' 6245' 13. Attachments Description summary of proposal _ Hydraulically fracture the A & C Sand with 105000# of 1 14. Estimated date for commencing operation 7/2/8~) 16. If proposal was verbally approved Name of approver Date approved Detailed operation program _ BOP sketch_ 6/20 Mesh proppant and Gilled 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. Signed ./~d~/--~ ,4~ .~~.¢'~ Title Sr. Operations Engineer FOR COMMISSION USE ONLY Date .("/~ ~/~; Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance m Mechanical Integrity Test _ Subsequent form require ORIGINAL SIGNED BY LONNIE C. SMITH Approved by the order of the Commission IApproval No. Approved Cop~. Returned Commissioner Date Form 10-403 Rev 5/03/89 SUBMIT IN TRIPLICATE Messr~ Lyden and Wad6' June 27, 1989 Page $ Kuparuk Well 2F-10 'A' Sand Re-Fracture Procedure 1. Obtain a 24 hour well test. Install Sonic Sand Detector (SSD) probe. , . MIRU Slickline unit. RIH with tubing end Iocator and tag fill. Pull GLV's at 2128', 4649', 6574', and 8100' 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". , . 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 = 3900 psig Fracture Gradient = 0.70 psi/ft Tubing Friction = 300 psi/1000 ft (6000' TVD) (8181' 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. . After well has completed flowback, obtain 24 hour well test. Contact Operations Engineering for a new gas lift design when necessary. ,----" ORIGIN ST^TE OF ALASKA ALASKA OIL AND GAS CONSERVATION ~MI~:~ION REPORT OF SUNDRY WELL OPERATIONS 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 _ 4. Location of well at surface 96' FNL, 1460' FEL, Sec. 33, T11N, R9E, At top of productive interval 1402' FNL, 1576' FEL, Sec. 34, Tll At effective depth 1450' FNL, 1425' FEL, Sec. 34, Tll At total depth 1481' FNL, 1296' FEL, Sec. 34, Tll N, R9E, N, R9E, N, R9E, 12. Present well condition summary Total Depth: measured true vertical 8 725' feet 6 2 61 ' feet Plugs (measured) 6. Datum elevation (DF or KB) RKB 127' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2F-10 Producer 9. Permit numl:jer/approval 84-40 / ~'--~ 10. APl number so-029-2107700 11. Field/Pool Kuparuk River Oil Pool number Effective depth: measured 862 3' feet true vertical 6186' feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 80' 3575' 8704' Size Cemented 1 6" 9-5/8" 1020 Sx A.S. III 7" 250 Sx Class "G" Measured depth True vertical depth 80' 80' 3575' 2851' 8704' 6245' measured 8278 '-8302', 8370'-8389', 8407'-8466' MD true vertical 5938'-5955', 6003'-6017', 6030'-6073' TVD Tubing (size, grade, and measured depth) 3 1/2", J-55 9.3 #/ft., EUE 8rd IPC, 818' Packers and SSSV (type and measured depth) SSSV: Baker FVL 1954', Packer: Baker FHL 8152' _..~. 13. Stimulation or cement squeeze summary Hydraulically fractured well with gelled water and 16/20 carbolite proppant Intervals treated (measured) 8278'-8302', 8370'-8389', 8407'-8466' MD Treatment description including volumes used and final pressure Pumped 50000# 16/20 carbolite, 1000 bbls gelled water, final pressure -- 6600 psi 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsecluent to operation 1 128 1283 0 1300 135 1992 2825 0 1600 145 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations i 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. Signed ~/~ ~ /~ r,4~~~TitleSr. Operations Engineer Form 10-404 lirev 06/15/88 SUBMIT IN DUPE'ICATE ,'~-" STATE OF ALASKA ~, ~ ', ' ALAS. . OIL AND GAS CONSERVATION COM, .~SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] '-,~,,~(,. Alter Casing [] Other [] 5. Datum elevation (DF or KB) Feet 2. Name of Operator ARCO Alaska. Inc, 3. Address ~ P.0. BOX 100360~ Anchorage~ Alaska 99510 4. Location of well at surface 96' FNL, 1460' FEL, Sec. 33, T11N, R9E, At top of productive interval 1402' FNL, 1576' FEL, Sec. 34, T11N, R9E, At effective depth 1450' FNL, 1425' FEL, Sec. 34, T11N, RgE, At total depth 1481' FNL, 1276' FEL~ Sec. 34~ T11N~ R9E~ 11. Present well condition summary 8725' Total depth: measured true vertical 6261' feet feet RKB 125' 6. Unit or Property name Kuparuk River Unit 7. Well number 2F-10 8. Approval number 9. APl number 50-- 029-2]077-00 10. Pool Kuparuk River 0il Pool Plugs ~'measured) Effective depth: measured 8623' feet true vertical 6186' feet Junk (measured) · Casing Length Size Structural Conductor 80 ' 16" Surface 3575' 9-5/8" Intermediate Production 8704' 7" Liner Perforation depth: measured . true vertical Tubing (size, grade and measured depth) Cemented Measured depth True Vertical depth 1020 Sx A.S. III 80' 80' 3575' 2851' 250 Sx Class "G" 8704' 6245' 8370' -8389' MD ,L "*-. '~ ~ '~ ' " 8407'-8466'MD 6003'-6017' TVD 6030' -6073'TVD " Packers and SSSV (type and measured depth) SSSV' Baker FVL 1954', Packer' Baker FHL 8152' 12. Stimulation or cement squeeze summary Intervals treated (measured) 8278'-8302' MD at 4 SPFo Treatment description including volumes used and final pressure See Attached 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure ~bing Pressure 511 286 0 1250 110 700 424 0 1250 118 14. Attachments Daily Report of Well Operations I~ Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ ~..~//¢~ ~77 Form 10-~404 Rev. 12~1-85 Title /%/~ ~ ~f¢._.¢.-~ ~, .~ ~ -'P-~/ Date / ~ '~ ~ ~ (/ j Submit in Duplicate .-~ ARCO Alaska, Inc. . Subsidiary of Atlantic Richfield Compan~'~ .... ,r~BDT I FIEL/~ISTRICT- STATE "¥'='"' ~,F"- / 0 I _. _ I ~'~,,~hl~. '~ WELL SERVICE REPORT I-'-I CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather ITemp. Chill Factor I Visibility Report "F "F miles Wind Vel. knots iSigned~~~' ~ ' ~ STATE OF ALASKA ALASh,,~ OIL AND GAS CONSERVATION COMr,,,SSION 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.O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 96' FNL, 1460' FEL, Sec. 33, T11N, R9E, 5. Datum elevation (DF or KB) RKB 125' 6, Unit or Property name Kuparuk River Unit 7. Well number 2F-10 feet At top of productive interval 1402' FNL, 1576' FEL, Sec. 34, Tll At effective depth 1450' FNL, 1425' FEL, Sec. 34, Tll At total depth 1481' FNL, 1276' FEL, Sec. 34, Tll N, R9E, N, R9E, N, R9E, 8. Permit number 9. APl number 4'1~' 50-- 029-21,0)~-00 10. Pool Kuparuk River 0il Pool 11. Present well condition summary 8725 Total depth: measured 6261 true vertical Effective depth: measured 8623 true vertical 6186 I , feet feet I feet I feet Plugs (measured) Junk (measured) Casing Length Size Structural Conductor 80 ' 16" Surface 3575' 9-5/8" Intermediate Production 8704 ' 7" Liner Perforation depth: measured Cemented Measured depth True Vertical depth 1020 Sx A.S. III 80' 80' 3575' 2851' 250 Sx Class "G" 8704' 6245' 8370' -8389' MD . 8407'-8466' MD '" true vertical :~,,_.~... .... ~..;~ Tubing (size, grade and measured depth)6030'-6073' TVD 3-1/2", J-55, 9.3 CC/ft., EUE 8rd IPC, 818' Packers and SSSV (type and measured depth) SSSV- Baker FVL 1954', Packer: Baker FHL 8152' 12.Attachments Description summary of proposal ~L Detailed operations program [] BOP sketch [] Perforate the C Sand interval from 8278' - 8302' 13. Estimat.~d date for, commencing operation may, 198/ 14. If proposal was verbally approved Name of approver Mr. L. Smith Date approved 5/18/87 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~7~'~/~/~ ~'~ ~,4~ Title Commission Use Only Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Approved by Form 10-403 Rev 124-8'5 Date by order of the commission Date,,~-'~ '"~7 Submit in triplicate Kuparuk Well 2F-10 C-Sand Perforating Procedure Charge Code #2381958WL · 2. 3. 4. 5. 1 · Set up cleanup/frac tanks. Shutin well (including lift gas). MIRU E-Line perforating unit. RIH with CCL/perf guns/magnetic decentralizer. Tie in depth using the following Schlumberger logs- DIL/SFL dated 3-30-84 CCL/CBL dated 4-14-84 Open well to tanks to shoot underbalanced. -~ Estimated C-Sand Reservoir Pressure = 3000 PSI. ~"". Estimated Final Bottomhole Pressure = 1900 to 220Q,~RS!... Projected System Underbalance = 1100 to 800 PSI. ' ....... -'~,.L -. Perforate the following interval as indicated. 2-1/8" strip guns are to be used. Two gun runs will be required. (DIL/SFL) (CCL/CBL) Interval .Depth (MD-RKB) Depth (MD-RKB) "C3" 8282'-8302' 8282'-8302' "C3" 8278'-8298' 8278'-8298' Shot Gun Rotation Dens i tS (degrees) 4 shots/ft -30 4 shots/ft +30 Gun Specifications Based upon API perforation specifications and the Exxon Perforating Study, any one of the following service company guns is acceptable, but it should be noted that the Schlumberger Enerjet Gun has shown the best results of the three in field use- Company Dresser Gearhart Schlumberger Gun '2-1/8" Silver Jet 2-1/8" E-Jet II 2-1/8" Enerjet · · RD E-line unit. Flow well until a minimum of two tubing volumes have been recovered. Confirm that BS&W has fallen below 2%, turn production back to CPF. ARCO Alaska, Inc. Post Office bw, 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 .Harch 11, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Well Completion Reports Dear Mr. Chatterton' Enclosed are Well Completion Reports for the following wells' 2F-10 2G-2 2G-8 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU5/LIO Enclosures RECEIVED 1 3 19B5 Aiast(a 0ii & Gas Cons. commission Anchorage ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA, LAND GAS CONSERVATION C MISSION 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. 84-40 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21094 4. Location of well at surface 9. Unit or Lease Name 96' FNL, 1460' FEL, Sec.3:3, T11N, RgE, UN Kuparuk River Unit At Top Producing Interval ~ - 10. Well Number 1402' FNL, 1576' FEL, See.:34, TllN, R9E, UM · 2F-10 At Total Depth 11. Field and Pool 1481' FNL, 1276' FEL, See.:34, TllN, RgE, UM : . . Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kupa ruk Ri vet 0i 1 Pool 125' RKB ADL 25657, ALK 258:3 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 0:3/23/84 03/30/84 04/15/84J N/A feet MSL I , 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD)19. Directional Survey [ 20. Depth where SSSV set I 21.Thickness of Permafrost 8725'MD,6260'TVD 862:3'MD,6185'TVD YES ~ NO [] 1943 feet MD 1400' (approx) 22. Type Electric or Other Logs Run D IL/SFL/FDC/CNL/GR/SP/Cal, CBL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 -Surf 80' 24" 225 sx Cold Set II 9-5/8" :36.0# J-55 Surf 3575' 12-1/4" 1020 sx AS Ill & 780 s:~ Class G 7" 26.0# J-55 Surf 8704' 8-1/2" 250 sx Class G & 250 s.~ 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) 8407' - 8466' :3-1/2" 817:3' 8145' 8370' - 8389' w/4 spf, 90° phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 6242' - 6255' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 6269' - 6:314' See attached Fracl~ure Stimulation Summary, 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE II~: 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Alaska 0i~ Anch0rag0 Form 10407 GRU4/WC68 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUEVERT. DEPTH . GOR, and time of each phase. . : _ . . . . Top Upper Sand 8277'~. 59~6' N/A ~se UpPer Sand 8298'- 5951' Top Lower Sand . . .8~52, 5989' ; Base Lower 'Sand 8550' - 61~2' : . . . . . . _ . 31. LIST OF ATTACHMENTS Addendums 32. I hereby certify that the foregoing is true and correct t0 the best of my knowledge INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (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". ADDENDUM WELL: 2F-10 9/18/84 9/21/84 9/26/84 9/28/84 FRACTURE STIMULATION SUMMARY Begin Frac Work At: 1059 Hrs, 9/18/84 Pmp 40 bbls hot diesel @ 13-1/2 BPM w/4750 psi; 20 bbls HgO/gel @ 15 BPM @ 1 ppg (1000# 100 mesh); 50 bbls H 0 g~l @ 15 BPM w/3980 psi @ 2 ppg 12-20 sand (2000#); ~7 bbls of 2 ppg 12-20 sand (14,600#) @ 15 BPM. Pressure went to 4800 psi; shut down, RD Dowell, RU Fracmaster. GIH w/coil tbg, broke circ@ 100' w/H~0/gel returns & no sand. (Gel was broke). Fin GIH to 8~75' while circ'g gel diesel w/coil tbg; no sand ret's until btms up f/6000'. (Calculate sand top = 6600'). Circ hole cln w/diesel, POH, RD Fracmaster. Csg press = 700 psi, tbg circ press = 170 psi thru cln out until @ pkr, then csg press dropped to 250 psi & tbg to 70 psi. SI well. Ck sand fill inside tubing Perf's: 6242'-6255' and 6269'-6314' TIH w/sinker bars, tag fill @ 2644', wrk dn to 2734', POOH, RD. Well SI. 8623' PBTD AFE 403920 RIH w/CTU to 2600', pmp gelled diesel @ .5 BPM, tag sand bridge @ 2640'. Wsh thru bridge, tag PBTD @ 8610'. Inc pmp'g rate to 1.5 BPM, pmp 10 bbl gelled wtr slug, followed by 10 bbl gelled diesel spacer. Pmp second 10 bbl gelled wtr slug. Spot each gelled wtr slug @ PBTD. Wrk CT in 7" csg bet tailpipe & PBTD while circ'g all gelled wtr slugs out of 7" into 3½" tbg (8203'-8610'). Circ out all wtr slugs. Pmp total 217 bbls gelled diesel & bO bbls of gelled wtr. (132 bbls diesel pmp'g after last gelled wtr slug.) Produced well during circ'g holding 300-450 psi back pressure. Rec'd 218 bbls total fluid in tst tank. Pull CT while circ'g final displm't vol. SI well. 8623' PBTD RU & tst to 3000 psi. RIH to 3244', wrk thru bridge, cont RIH to 3643', att to wrk thru bridge w/o success, POH. RECEIVED Alaska Oil & Gas Cons. Commission /~.nchorage (cont'd.) WELL: 9/29/84 10/05/84 10/12/84 10/14/84 ADDENDUM 2F-10 8623' PBTD RIH to 3622' w/bailer, wrk thru bridges to 7354'; unable to go deeper, POH. 8602' PBTD "A" Sand Perfs: 8370'-8389' and 8407'-8466' RU S/L, tst BOP & lub to 3000 psi; OK. RIH w/sinker bars, tag fill @ 3799' RKB; could not wrk dn, POOH. PU 2" bailer, bailed f/3799'-3829' (several small bridges). Rec'd a mixture of 100 mesh & 12/20. Cont in hole to 4504', tag up, bailed to 4527', POOH, RD. RU CTU, tst BOP & tbg to 4000 psi; OK. RU pmp to 7" x 3½" ann. Pmp dn ann @ .4 BPM/1950 psi f/25 bbls w/4 bbls rtns. RIH w/CT, pmp'g @ .2 BPM. Tag fill @ ~4500'. Inc rate to .5 BPM & wsh thru bridges to ±4650'. Circ out & decrease rate to .2 BPM. Tag btm @ 8611'. Inc rate to 1.5 BPM/4000 psi (holding ±350 psi back press). Pull up into tailpipe & pmp tbg vol of gel/diesel. PU to 8000'. RU pmp to 7" x 3½" ann. Circ 10 bbls diesel @ 1BPM/250 psi. POOH w/CT & displ ann w/10.1 ppg per gal NaCl~/NaBr2/H20 (350 bbls) @ 2 BPM/350 psi. RD, secure well~ 8623' PBTD RIH to confirm PB f/frac, tag PB @ 8608', POH. @ 8466') (Btm perf FRACTURE STIMULATION SUMMARY AFE 403920 Begin Frac Work At: 10:40 hrs, 10/14/84. Dowell frac'd Kupurak "A" zone performations 8370'-8389' & 8407'-8466' in 7 stages per revised procedure using hot diesel, wtr/gel, diesel, 100 mesh & 12-20 sand. Pressured annulus to 1500 psi with diesel. Test lines to 6400 psi; OK. Pumped 40 bbls 120° diesel pad containing P-20 @ 10 BPM w/5000 psi. Stage #1, 100 bbls wtr/gel @ 20 BPM w/4250 psi. ISIP = 1950 psi (friction = 800 psi). Stage #2, 20 bbls wtr/gel @ 15 BPM w/3750 psi. Stage #3, 25 bbls wtr/gel w/1 ppg 100 mesh (1000#) @ 15 BPM w/3700 psi. Stage #4, 30 bbls wtr/gel spacer @ 15 BPM w/3700 psi. Stage #5, 26 bbls wtr/gel w/2 ppg @ 12-20 (2000#) @ 15 BPM w/3600 psi. Stage #6, 54 bbls wtr w/7 ppg 12-20 sand (13,440#) @ 15 BPM w/3600 psi. Stage #7, flush w/19 bbls wtr/gel & 29 bbls slick diesel. Screen out @ 6000 psi, 32 bbls short of displaced. SI press @ 15 min = RECEIVED 1985 Alaska 0ii & Gas Cons. Commission Anchorage (cont'd.) ADDENDUM 10/16/84 10/19/84 10/22/84 10/26/84 i0/29/84 Pumped 1000#, 100 mesh & 9000# 12-20 sand in formation, leaving 6440# of 12-20 sand in casing. All wtr/gel w/10% KC1, .5% Methanol. Stage 1-6 w/50# per 1000 gal fluid loss. Load to recover 267 bbls of wtr & 69 bbls of diesel. Job complete @ 11:26 hrs, 10/14/84. 8623' PBTD GIH w/CTU to 6800', choke & flow in plugging w/ice & sand, POOH. Cln all ins & tbg w/diesel f/2500'-surf, POOH, RD CTU. Well shut in. 8623' PBTD "A" Sand Perfs: 8370'-8389' and 8407'-8466' RU CTU, tst BOP & coil to 4000 psi; OK. RIH w/CT while pmp'g .2 BPM. Tag fill @ 7638', wsh thru bridge, tag solid fill @ 8193'. Inc fluid rate to 2.3 BPM & start 350 scf/min N^. Held 500 - 700 psi back pressure w/CT. Pressure 3800z- 4000 psi. CO to 8620', taking 50' bites & wrk'g CT up into tbg tail. Circ cln on btm w/gel & diesel, POOH, displacing w/cln diesel.- RD & secure Pmp'd: 244 bbls gel/diesel 93 bbls cln diesel 50,000 scf N2 Fluid Pmp'd: 337 bbls Recovered: 361 bbls 8623' PBTD, SI f/sand settling RU WL unit & tst lub w/2500 psi. RIH w/gage tl to 8388'; unable to go deeper, POOH. MU bailer, go back in hole, tl stopped @ 8388', POOH. Rec'd small amt of sand & gel/diesel f/bailer. RD S/L unit, secure well. 8623' PBTD RU CTU & N2. GIH w/CTU pmp'g .2 BPM to 8400'. Displ hole vol wTgel/diesel. Start N? and gel/diesel & switch to diesel. Displ hole w/Il0 bbIs diesel. 8623' PBTD RU Camco. RIH w/S/L to 8354' & tag fill, POH. RU bailer, RIH, wrk fill to 8384', POH. RD Camco. Secure well. I( 'CEIVED i F~ . l ]985 Alaska Oil & Gas Corm. Commission Anchorage (cont ' d. ) ADDENDUM 10/30/84 11/o5/84 11/o6/84 8623' PBTD, Well SI MIRU slickln, GIH w/bailer & tg fill @ 8420', bail to 8423'. POH, rec frac sd. RU CTU, RIH to 8170', CO w/350 bbls gelled diesel & 65,000 scf N2. RU S/L. Tst BOP. RIH w/sinker bars, tag sand @ 8516' RKB, POOH, RD & secure. Rel'd to Production. RECEIVED iV~!-\R ! 5 !985 Alaska Oil & Gas Corm. Co,,~mmsion Anchorage Drillin~ Superintendent · "Date F-lO I RECEIVED ~02 8/2t/84, (over) coma ARCO Alaska, !~ Posl Otlice Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 2, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Subsequent Sundry Reports - Various Wells Dear Mr. Chatterton: Enclosed are Subsequent Sundry Reports for the following wells: 1E-22 1E-25 2F-10 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU3/L26 Enclosures RECEIVED JAN 0 9 19B5 Alaska 0il & Gas Corm. commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA - ALASKA UIL AND GAS CONSERVATION CO~v~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL i~ 2. Namec°fARO Ooerator 7. Permit No. Alaska, Inc. 84-40 8. APl Number 3'Adl~res(~--. v. Box 100360, Anchorage, AK 99510 50- 029-21094 4. Location of Well 9. Unit or Lease Name Surface: 96' FNL, 1460' FEL, Sec.33, T11N, R9E, UM Kuparuk River Unit OTHER [] 5. Elevationinfeet(indicate KB, DF, etc.) 125' RKB 61Lease Designationand SerialNo. ADL 25657 ALK 2583 10. Well Number 2F-10 11. Field and Pool Kuparuk River Field Kuparuk River 0i1 Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other [] Other [] Pulling Tubing ~ Pull 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 AAC 25.105-170). Accepted rig ~ 2230 hfs, 10/05/84. Killed well. Set BPV. ND tree. NU BOPE & tstd to 3000 psi - ok. Pulled tubing hanger and tubing. Retrieved pkr. Ran 3-1/2" completion assembly w/tail @ 8181', pkr ~ 8152' & SSSV ~ 1954'. ND BOPE. NU tree & tested - ok. Disp well w/crude. Dropped ball & set pkr. Set BPV. Secured well & released rig ~ 1130 hrs, 10/09/84. RECEIVED 0il & Gas G0ns. O0mrnissi0n Anchorage 14. i hereby certify that the foregoing is true and correct to the best of my knowledge. ~ /'~m,~, '- ~'/i,. ~.~'L.-~' Title Signed .~ UU?,j~/~., ~Z~_/~L} ~ Associate Engineer The space belov~/for Commission use Conditions of Approval, if any: Approved by [,l~l i i:-I j'l',, I, i ~,-1 By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate Form 10-403 Rev. 7-1-80 and "Subsequent Reports" in Duplicate ARCO Alaska, Post Offi~,,. Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 1, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT' 2F-10 Dear Mr. Chatterton- Enclosed is a Sundry Notice for the subject well. We propose to pull the existing tubing, change out the packer and PBR, and re-run the 3-1/2" completion assembly. Since we expect to start this work on October 2, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Si ely, /Area Drilling Engineer JBK/JG/tw GRU1/L67 Enclosures RECEIVED oc'r o /~laska Oil & Gas Cons. Commis$iort Anchorage ARCO Alaska, lnc, is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION ~,OMMISSION SUNDRY NOTICES AND REPORTS ON WELLS OTHER DRILLING WELL [] COMPLETED WE LLx~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 96' FNL, 1460' FEL, Sec.33, T11N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) RKB 125' 6. Lease Designation and Serial No. ADL ?c,~,r~7 Al K _9583 7. Permit No. 84-40 8. APl Number 50-- 029-21094 9. Unit or Lease Name 10. Well Number ~F-IO 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing j~ 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 AAC 25.105-170). ARCO Alaska, Inc., proposes to perform a workover on 2F-10. The procedure will be as follows: 1. Kill well with brine. 2. Pull tubing. 3. Change out packer and PBR. 4. Re-run 3-1/2" completion assembly. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly and operationally tested each tirp. 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 safe~y valve will be installed and tested upon conclusion of the job. Estimated Start: October 2, 1984 RECEIVED OCT 0 2191 Alaska 0ii & Gas Cons. Commission Anchnr~G.,-; Subseoxuent Work l~eported .. / ,..,,.~, so./ 03 14. I hereby ce, F~y~that the foregoing_is true and correct to the best of my knowledge. Signed (/'"' _r// /'/ ~ ~ _ Title Area Drilling Engineer Date ~he space,~low~r ~/~ission us. Approved by Blt LI#i'II£ & SlliIIi Approved COpy Returned By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 GRU1/SN65 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, In~ Post Office ~o^ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 7, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2F-10 Dear Mr. Chatterton' Enclosed are the Completion Report and gyroscopic survey for the subject well. If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG-tw GRU7/L33 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany · KUPARUK ENGINEERING Well Name: Transmittal DISTRIBUTION NSK Operations Dr il 1 lng Geolbgy/Ken Blueline Blueline Film Blueline & Sepia Date Run ~L f-z i z4 I Sign & return the attached' "" copy as rece~Of~~ -.: :~S. '~~Return to: ARCO ALASKA, INC. ATTN: F~u~ m.~T/P ATO-1115B P.0. Box 100360 Anchorage, AK 99510 : >~*'--~',, STATE OF ALASKA ~ ~ ALASK. _AND GAS CONSERVATION , /llSSION O~~' WELL COMPLETION OR RECOMPLETION REPORT AND I. 1. Status of Well Classification of Service Well OIL d(X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 1~. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-40 ~. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21094 :4'. Location of well at surface 9. Unit or Lease Name 96' FNL, 1460' FEL, Sec.33, TllN, RgE, UN~ Kuparuk River Unit At Top Producing Interval I '~/~ ILP~xib~ 10. Well Number FNL, 1576' FEL, Sec.34, TllN, RgE, UM i VERIFIED I 2F-10 1402' Surf. ~_~_~ At Total Depth 1 1 Field and Pool 1481' FNL, 1276' FEL, Sec.34, T11N, RgE, UM j B.H. ~ ' ~ 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 1'2. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 16. No. of Completions 03/23/84 03/30/84 04/15/84I N/A feet MSL 1 17. TotalDepth(MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set ] 21. Thickness of Permafrost 8725'MD,6260'TVD 8623'MD,6185'TVD YES ~ NO [] 1943 feet MD 1400' (approx) 22. Type Electric or Other Logs Run DIL/SFL/FDC/CNL/GR/SP/Cal, CBL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 80' 24" 225 sx Cold Set II 9-5/8" 36.0# J-55 Surf 3575' 12-1/4" 1020 sx AS III & 780 s; Class G 7" 26.0# J-55 Surf 8704' 8-1/2" 250 sx Class G & 250 s; AS I 24. Perforations open to Production (M D+TVD' of Top and Bottom and 25. TUB I NGR ECOR D interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 8407' - 8466' 3-1/2" 8173' 8145' 8370' - 8389' w/4 spf, 90° phasing '26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A -- 27. N/A PRODUCTION TEST Date First PrOduction Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL 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 ~-~ !': ,:~ r~'! ,. :--,..: , ,' ~',.'i?', '( '-..: . .~' - ~-~ ~L '0-407 GRU7/WC11 Submit in duplicate -80 CONTINUED ON REVERSE SIDE ~¥,~o~oGi~l~l~i~E~f~ -{ ,-.: ..i- ~.: i ..,/ ,_ ;': -s? :., ?.:;. -~: .¢, ~, ;. .:: -;?--.,. ;,..4!~:-~ ~:. ~f::~i~dR'M~Ti'ON tE~TS' :'.... ..... ;,.?: ,.::.i~.t-, "-,i;,: ._ . .. · , . _ . 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 8277' 5936' Base Upper Sand 8298' 5951' Top Lower Sand "' .... '~ 8352' 5989' N/A :' Base Lower Sand 8550; 6132' , :.. · : . .. . , . :'~ 31. LIST OF ATTACHMENTS , . Drilling History= ComoletioniSummary= Cvroscoi~ie'SUrvev (2 co~ies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~~~ Title A?e~ D.~I.i.~Rg E e,.~. 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". I.:..*U PA F:,: i..i I< i...' ;i. ii:': L. D ALASKA VERTIF:AL. SE]]:'FION CALE:ULATED ALE;NG _. ]' [:;.: 1_1L:.i[ '.:::; I..I B-5:; E A (7: (Z)i ..1 i:':.:' '.;ii, Mt.::.":A F;LiF;:E; D v'E. ::,.''~- i CAi .... VF.;F? 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J..'1:1 ,q. ,, :ii: ::ii: :ii; -':1. 4 :'::; :1..t;.": ':5 E .'2 ..... ~"~ 1. :iii: ,, ::ii: 0 .t. 144, '7:':~:'", ,454. (), 61 E 2 :"~ 6 :'3. '74 1. 1 '74 "" ~'::' , .,_ , .,~ ...... 'E; 4 649 5 .l E "::'1 14.51 1 2 ()2.0 4 :i:; 4 7 5 q.. :.::': 0 1.2 "::/1 6 2. :'_::6 .'1. 2 2',.3 ,, E: '!? E; 4 0.5 7.9 5 E :2 2 0 ~3. ~ 2 77 ,:'] ._t ..1 ,'5, ......... ¢H:,~C':'O AI....ASP.::A~ I NC,, ' 2F-- 1 () ( :.:.'i~EC:2,:3 T :l 1N ROii)E" ) I<LIF'AF;:LII-':: F:' I ELD ~¢4L'ASKA SPERRY-SUIq WELL. '.::i:I...IF;:Vliii:Y:[NG (::OMF'ANY A Iq F:: H 0 R A (."..i E A L.. A'..-]; I< A tN'-'~-T-ED VALLIES F()R EVEN 'T' R U liii: S I_1B--'..'-";lie A "1" ~ :' '/'Al .... IqE. A.'.~;LIR E:'£1 VER'T Il ........ .... m,_ VER'T t CAL. RECTANGULAR DEPI'H I}EF:"I'H [IF"]:-" T H N'FIRI"H / :::;(:~UTH C 00 R D i N A '1" E :3 E A ::; T .../W E :!.::; "i' 81 1 9 ':::'""'"'"':: .,c,..' , ............. ("~(] 5'7 ()(") () 0 1 '.':2'7 9 ,, 13 :!;.'; ":.,0.::: ......... ..... ;':', :'.":'i:~ Ii".": :::', 2 6 .............. 1 ""; 9 ::::' ;":; () ()':"?,,..-.,'"" 0 .... t..~. (") ..... (') .1. 3 f'-~ ;;2:40 :L ,':,C~2F"; ()0 ']" .......................... '"'" '" "*' ' ............. _. ., . ,,. ::YO0 , O0 J...:-::Z:=~ ..... 3:3 :'.:', .,::4 ::~. 1,.:, E :=:_ 54 ['). ,':, 1 ..'.'-' ._, '=' . ('.::, () 60 ()0.0 (') 1:2:52: ,, 71 '..::; !::";.~ ..."::~ 41. ::~:() Ii-':: 8 6 7 7 '-' '"' 6,.~...' .... ........ 00 6100. () () 1:2:7/:,. 7 '.:." ':::' '::, ...... 4 ..:,'..-" ,, .... :2::3 Iii"' .,-c.l- '-, =; ...... · ........... . · " .............. _ 7:,: .... . . A'.2F,;,'..P.,, 8(:) 6'.t ;3.4, .8C) t :...¢:..45 ,, t ~'~ '.:'.:.'; 546:3 :~:::: E .,) iqE~.-'T'VEI . VER'i".t. CAL ............................... ,,~. ........ D I I:::F:'E IRE N CI::':' C OF;,'RE C T 101'4 2 2~;:2: ,, 4 2 ......... - · 4:3-...?..t ................. i ...... ' ........... i:~ .:: :~=: ............. 2 41.z,"'". 2 9. :3 :-2: ,, 4 7 :2:4 5:2. :2: :2: :--: 7 ,, ():3 :2:465.2() · 12 ,, 88 'T'HE i ..... ... .... [-t L. C I...I L. A "i' I 0 N I::' R Fl CIE D LI R Ii.:- :3 U :.'.-'.'; [iil A t.... 1' t\1E A R :t: i,,I "f E:' R 1z' 0 I_ A 'T' I t"'l N B E; 'T' W E IE N THE NE~RES"r 20 F'OO'T MO (F'RFir;t RADII..I:S OF' CLIRVA'I"LiRE) F'CIIN'I"S 2 F- '1. 0 ( :.E'; E C :iii: :3 'T' :1. 11',1 Fi: ()9 E" ) I<UF'AFiX..II< F:' I EI._.D ..... ALASKA SF'EF:d:;tY-SUN WELL. ',ii~;I...II::~VE:Y I big CCIMF'AN¥ A Iq C H 0 R A f:ii E" A L. Pt'F;I< A C: 0 l'q F:' I..I 'T' i::'.'~ 'T' :[ 0 i"q J[)A 'T' e.'iil A F:'I::;: .'[ I .... :t. 6, 1 '.:.';':iii', 4. HEASURE'£ DEF'TFI "1" Fi: I...1 li~: V E R "f' :[ C: A L~ DEPTH :F:ilJ B-'.:_:;t:i:A "r'(.)"l" A L VER i i' _.~: REC"f'At",I('jt...tLAR (:X3f'-IR'.() :[ NA"t"EE; DEPTH NORTH / !.::;01 I'T'H li'E (.~ E; T / WES"r' IqAIRKIER .... I0 ]('~i: N I...I I'~'1B E R A I<- B C ..... 4 0 (:) 2 8 KE L. L_ Y '"' ' E'L E~~ - - ~,'~;~)""'~:f~ ........... TOP UPF'ER SAND ......................................................................... :[{'J'~ A :!~.; Iii!: I...IF::' F::'l!iJ:J:~: :.;.'!; A I',1 El "F CIP L... 0 W E R '..:.'.'; A N 0 SURVEY OEP'T'H BASE L..OWE:R '.'3AND F'L U(3 BAr.'.': K T D TOTAL. DEPTH 'DRtLL..ER ............................................................... liii;"l' R A"I' itl (3 R A F::' t'.-J I C fi: L.I H M A I:::,' Y Ell::il R 1 V t::i' D U :i~; ;[ N (3 i311 .... i( .1E F'"I"I'"t :iii; A N D :!ii; F' E R i::;: Y :!ii; LIN '.i!i; U 1::~ ViE ¥ E, A'T'A :!HE:A8 LI R E :[~ f)E F' T H ..................... 'l"V D ................. "l"l'-'i I C i< 1'4 E :::; S : ...... ~ ...... B KB B K B "5; t...! B--' :F'; E A V ER T' I CA t.- ................ MAI::d<EF:;; .................. ]"OF:' LIF'F'ER SAND .'3277 BASE UF'F'ER '.ii!;AND :E:2'i78 T(:)F' LOWER SAI',ID 8:::52 --.,.-.BASE, I_C;WFR, SAND ....... 8F;;5() ......... F' L. I...I G B A C I.':: T ][) F:/:, 2 :':.': 'I'E~-I'AL.. DiEF:"T'H DR :[ Lt__EF;: 1) FI-ROM LINEAR EXI-RAF'i3LATIOI',I BELOW DEEF'EST S'I'ATION, --2--)--- 4]: FI t'f F; I..I T ER F'ROGRAFt - SPERRY SUN TFtREE D t P'tENf_-3' I ONAL. RAD I l._lt~ L-)F C:URVATLIRE. , ......................... DATA CALCLIL_A]' :1: ON AN_F.I :1: N"I'ERF'F~L..AT I ('iN BY I::;.:AD '1: I..It...-..; ('.)1::' i:'_':i...IF;.:Vi:::'~"I-LII::;L(.Z r":F'IMF'LI-I"A T :i: ON APR I t.._ ]./} :, .t. '.::','84 L-IF ::;LIRVEY' APRIl_ :1.4... I-::]EL_['Y BI_IF;HINFi Ei...I:{V,, ::: :I. J;:".:!!;, C,'.:) t:::"i". ARCO Alaska, Inc. Our Boss Gyroscopic Survey Job No. AK-BO-40028 Well: ~2F-10 (SEC33 TllN R09E) Kuparuk Field North Slope, Alaska Survey Date: April 14, 1984 Operator: McGuire Scale: 1" = 1000' I -~000,00 TRUE NORTH Surface Location 96 FNL 1460 FEL ~ I I I I I i ~~_ 3.000. O0 '~000. O0 5000. O0 '--2000 O0 - -"' "'--~ "'"'"'~.......~ ~ '/ 2 5 HORIZONTflL PROJECTION 0.00 1000. O0 2000.00 3000.00 4000.00 5000.00 6000.00 7O00.00 ARCO Alaska, Inc. Our Boss Gyroscopic Survey Job No. AK-BO-40028 Well: ~2F-10(SEC33 TllN R09E) Kuparuk Field North Slope, Alaska Survey Date: April 14, 1984 Operator: McGuire Scale: 1" = 1000' x. 5636.68 @ S 75° 46'E ~8725 1000.00 2000. O0 3000.00 4000.00 5000.00 VERTICAL PROJECTION I 8000. O0 r,~> I' ......... . . ~ . ~. ~,~ ~ ~ ~ ~ '"~ .~ ~ ~ . . ~ ~ ~ ~ ~F..~......~.....'.....~.,,..'.'.~.......~..~..,'.,, .......... . ................... ,., ....................................................................................................... . ................ 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'ii',,.':;~4?:i~r'! , i:!i~,,..~'..,,~!,~,}s~.,:.,:!~i::!ii!ili'.i~!:~ ~:~.:*~.~:~]:!!~]~:~.~:i~?-4~?4!~:!:!:!::`~k~i~;!~:!~:~!:]:~:~:i~i:~)~;~ ,~, ======================================================================================================================================================== '!~: :: :' ::.'.:. ,,.i: ,,:.:, ::'?_,,..::::! !. : · =,] RAJ I t: RAF H I C SUMMARY DERIVED LISINO I) IL DEPTHS gND SF'ERRY SUN SURVEY DATA : I ' ........................................................................... ~.: ~'~:"~.'." ~" ~ ' ~~ili:'~'~ ....................... ~ "~" ~' ~' ~.~ '".'" ?,~'.¢."~'"":,~' ~ ........ "."~"~' .......... ~"'"~,' ........................................................ · '. ' * ;'..:'-::,:.:,..'.:,:..:: ................ .',.'.,.'::: ~ ~ ' '~ ~ ~ ~, A ..'. .',.,'.~.~.:.~ '. .:.,:~ :. ~'::: ::: :.,"':~¢:~' '.:'.'~ :''~,:.~.': .~ ~'.¢~..':..':. ~;~ .::::.~ ~ ,¢ :c ::" ..... :: : '.' ~ :~,:: DATA C:ALC:LIL_ATION AND INTERPOLATION BY' RADIUS OF C:LIRVATLIRE .................. ~ .... ~ ...... ~' ........ ~ ' .......... .~ ....... ~ ~".~:~ ~>-~ ~,-~°' · ~ '~.,.-~.: .... i.~ '~:'~:'~:~!~i'~'"'~:::~ '~:'"""'~'":J~i~ :'~..~...'"'~i: ........ ~.'_~?'""":'~"'~. :~ ......... .. ".":~'"':' ................ :i~?~.~.!:!~.......:.~.::::..:~`~...:::~.::`:.:...::...:..?:~:~:~:~`:.:.~::~:::~P.;`~::~::.~:::~::~:.~::.::~.::: '-'.:~::::': .::::-:;:'-:~:'~'.'~'" ........ "~ ~"" '"':': ' .,, ,:':,,:":' .KELLY J~USHING EkEV. = 125 O0 FT. '1','. ~, ,' ' , , ' · "' ~.' : :'...,~ ~ I.: . ~ ' '. .. 0 0 0 ARCO Alaska, Inc. Our Boss 'Gyroscopic Survey Job No. AK-BO-40028 Well: ~2F-10(SEC33 TllN R09E) Kuparuk Field North Slope, Alaska Survey Date: April 14, 1984 Operator: McGuire Scale: 1" = 1000' T~UE NO~TH I -1000. O0 Surface Location 96 FNL 1460 FEL ~ooI~.oo ~oob. oo --~ooo. oo's~~ I 5000. O0 --2000.00 HOR I ZONTHL PRO JECTION 0.00 tO00. O0 2o0o. oo 3000.00 4000.00 5000. O0 ARCO Alaska, Inc. Our Boss Gyroscopic Survey Job No. AK-BO-40028 Well: ~2F-10 (SEC33 TllN R09E) Kuparuk Field North Slope, Alaska Survey Date: April 14, 1984 Operator: McGuire Scale: 1" = 1000' 6000.00 7000.00 5636.68 @ S 75° 46'E 8725 VERT I C~L PRCJECT I ON I lO00. O0 2000. O0 3000. O0 4000. O0 5000. O0 6000. O0 Suggested form to be inserted in each "Active" well folder to d~.eck for tin~ly cor~liance with our' rc<julations. Operatb~, ~Vel I Na~e and Numker Reports and Materials to be received by: ., ~ '/,_~C_~.~--- ~,/ Date Required Date Received Remarks _ Ccmpletion Reuort Yes '. '.. ~ ,, ~re ~ips -' ,, ,_ Core ~scrip~n Registered S~ey Plat . Inclina~on S~ey ~ ~__~~ ~/~ Dire~ional ~ey Drill Stm Test Returns Digitiz~ ~ta KUPARUK ENGINEERING We 11 Name: ~~',/0, ,, Log ~_ Date Run ~ DISTRIBUTION NSK Operation Blueline Drilling Blueline Geology/L. J. Bi/Se R&D Blueline D&M Blueline B1/SE F.G. Baker Blueline D.B. Schafer Blueline Geology/Ken Film ~~~~ & return the copy as rec~ipt of d~,, Anchorage Retu~ to: ARCO A~S~, INC. ATTN: D. Fay ALLISON ATO-1115B P.0, Box 100360 AnchoraEe, ~ 99510 OHFinal 2F-10 DRILLING HISTORY NU 20" hydril and diverter. Spudded well @ 0330 hrs on 3/23/84. Drld 12¼" . hole to 3610% Ran 90 jts 9-5/8" 36# J-55 HFERW BTC csg w/shoe @3575'. Cmtd 9-5/8" csg w/1020 sxs Artic Set III and 780 sxs class "G". Bumped plug .w/2000 psi - floats held - ok. ND 20" hydril & diverter. Performed top job w/81 sxs Arctic Set I. Instld 9-5/8 packoff & tstd to 3000 psi - ok. NU BOPE & tstd to 3000 psi - ok witnessed by Ben Lanorman w/AOGCC. Tst csg to 1500 psi - ok. Drld FC & cmt, tstd csg to 1500 psi - ok. Drld FS and 10' new form. -Tstd form to 12.5 ppg - EMW - ok. Drld 8½" hole to 8687'. Ran logs DIL/SFL/GR/SP/CAL/FDC/CNL f/8701' to 3575'. Cont drlg 8½" hole to 8725' TD as of 3/30/84. Ran 225 jts 7", 26#, J-55 HFERW BTC csg w/shoe @8704'. Cmtd 7" csg w/250 sxs class "G". Bumped plug to 3000 psi, floats held ok. ND BOPE. Instld 7" packoff & tstd to 3000 psi - ok. Performed arctic pack. Displ brine from top of well for freeze protection. Secuzed well and released rJ.g @1900 hrs on 3/31/84. DH127 4/16/84 ih 2F-10 COMPLETION SUMMARY 04 13/84 ND tree. NU BOPE & tstd - ok. Circ. & Accepted rig @ 1030 hrs,_ ./ ..... 14 ~-~-~tion rate into 9-5/8" x 7" ann heat brine to 100°F- ~s~ab/~neo ,-J~ ' bbls H^O, w/diesel (1000 psi @ 5 BPM). rctic packed 9-5/8" x 7" ann w/200 Ran ~BL 250 sx AS I & 64 bbls Arctic Pack. Ran gauge ring/JB to PBTD. f/8616' - 1890'. Ran Gyro. RIH & perforated the following intervals w/4 spf, 90° phasing' 8437' - 8466' 8407' - 8437' 8370' - 8389' Ran 3-1/2" completion assy w/tail @ 8173', pkr @ 8145' & SSSV @ 1943'. ND BOPE. NU tree & tstd - ok. Disp well w/diesel & crude oil. Dropped ball & set pkr. Opened SSSV. Set BPV. Secured well & released rig @ 2300 hrs, 04/15/84. GRUT/CS11'tw ARCO Alaska, Inc' Post Office Dux 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 18, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Subsequent Sundry Reports - Various Wells Dear Mr. Chatterton' Enclosed are Subsequent Sundry Reports for the following wells' 2F-6 2V-4 2F-10 2V-6 If you have any questions, please call me at 263-4944. Sincerely, _. J. Gruber Associate Engineer JG- rb GRU7/L02 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichlieldCompany STATE OF ALASKA ALASK;"~':IL AND GAS CONSERVATION C~'MMISSION SUNDRY OTICES AND REPORT OH WELLS 1. DRILLING WELL [] COMPLETED WELL'C;[ 2. Name of Operator 7. Permit No. ARCO Alaska, inc. 84-40 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21094 4. Location of Well Surface: OTHER [] 96' FNL, 1460' FEL, Sec.33, T11N, RgE, UM 5. Elevation in feet (indicate KB, DF, etc.) 125' RKB, 6. Lease Designation and Serial No. ADL 25657 ALK 2583 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 2F-10 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations '~ Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other [] Other [] Pulling Tubing [] Pull Tubing (Note: Report muhiple completions on Form 10.407 with a submitted Form 10-407 for each completion.) 13. Describe ProPosed or Completed Operatiorm (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any I proposed work, for Abandonmentsee 20 AAC 25.105-170). · AccePted rig ~ 1030 hrs, 4/13/84. ND tree. NO BOPE & tstd - ok. Circ. & heat brine to 100° F. Establishe injection rate into 9-5/8" x 7" ann-w/diesel (1000 psi ~ 5 BPM). Arctic packed 9-5/8" x 7" ann w/200 bb]s H O, 250 sx AS I & 64 bbls Arctic Pack. Ran gauge ring/JB to PBTD. Ran CBL f/8616'- 1890'. Ran Gyro. RIH~& 2 perforated the following intervals w/4 spf, 90° phasing: 8437' - 8466' 8407' - 8437' 8370' - 8389' ND BOPE. 'NU tree & tstd - ok. Disp well] Dropped ball & set pkr. Opened SSSV. Set BPV. Secured we]] & released rig ~ 2300 Ran 3½" completion assy w/tail ~ 8173', pk~ ~ 8145' & SSSV ~ 1943'. w/diesel & crude oil. hfs, 4/15/84. RECEIVED APR 2 4 1984 Alaska Oil & Gas Cons. Commissio Ancherage 14. I hereby certi:[y that the foreqoing is true and correct to the best of my knowledge. Signed - Title Area Dri 11 i ng Engi neet Dale By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-i-80 GRUT/SN01 Submit "Intentions" ,n Triplicale and "Subsequenl Reporls'' in Dup~ice:e ARCO Ala'ska, Inc. Post Office E~ox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 April 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: 2B-9 2F-7 WSP #3 2B-10 2F-8 WSP #9 2B-11 2F-9 WSP #12 2B-12 2F-10 Hemi Springs State #1 2A-1 WSP #1S Thank you. Sincerely, in strict Drilling Engineer JBK/SHI:ih ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany " . ,--"- STATE OF ALASKA ..--,. · ' ALASKA ,..,IL AND GAS CONSERVATION C,,_ .AMISSION MONTHLY REPORT OF ORILLINO ANO WORKOVER OPERATIONS · Drilling well [~ Workover operation [] Nam, e..o.f,f.qpe[a,tor __ 7. Perrr~i~N~.0 2. AKUU A±asma, Inc. - 3. AdZe. ss 0 Box 100360 Anchorage AK 99510 8. AP~ Nu~_21094 · ' ' ' 50- 9. Unit or Lease Name 96' FNL,1460' FEL, Sec.33, TllN, R9E, UM Kuparuk River Unit 4. Location of Well at surface 5. Elevation in fe~t (indicat_e KB, DF etc.) I 6. Lease Desiclnation and Serial No. PAD 96 , 125' RKB' ADL 25657 ALK 2583 March For the Month of 10. Well No. 2F-10 11. Field and Pool KPK River Field KPK River Oil Pool 84 12. Depth at end of month, footage drilled, fishing jpbs, directional drilling problems, spud date, remarks Spudded well @ 0330 hrs, 03/23/84· Drld 12¼" hole to 3610'. Ran, cmtd & tstd 9-5'/8" csg. Performed top job. Drld 82"a hole to 8687. Ran logs. Cont drlg 8½" hole to 8725'TD. Ran, cmtd & tstd 7" csg. Performed arctic pack. Displ brine from top of well. Secured well and released rig @1900 hrs on 3/31/84. 13. Casing or liner run and quantities of cement, results of pressure tests 9-5/8" 36# J-55 HFERW BTC csg w/shoe @ 3575'. Cmtd,w/1020 sxs Arctic Set III and 780 sxs class "G". 7" 26# J-55 HFERW BTC csg w/shoe @ 8704 . Cmtd w/250 sxs class "G". 14. Coring resume and brief description N/A 15. Logs run and depth where run DIL/FDC/CNL/GR/SFL/SP/CAL f/8701' to 3575'. 1 6. DST data, perforating data, shows of H2S, miscellaneous data N/A APR ~!aska 0il & Gas Cons, C0mmissl0~ ftnch0rage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge· SIGNED ( ~t,,~- TITLE Area Drillin~z Emzineer DATE o,, t,,,...o.r, o' st t.s o' o..rat,o. . with the Alaska Oil and Gas Conservat~ Commission by the 15th of the succeeding month, unless otherwise directed. Form 10~04 ~/~32 Submit in duplicate 2F-10 DRILLING HISTORY NU 20" hydril and diverter. Spudded well @ 0330 hrs on 3/23/84. Drld 12¼" hole to 3610% Ran 90 jts 9-5/8" 36# J-55 HFERW BTC csg w/shoe @3575'. Cmtd 9-5/8" csg w/1020 sxs Artic Set III and 780 sxs class "G". Bumped plug w/2000 psi - floats held - ok. ND 20" hydril & diverter. Performed top job w/81 sxs Arctic Set I. Instld 9-5/8 packoff & tstd to 3000 psi - ok. NU BOPE & tstd to 3000 psi - ok witnessed by Ben Lanorman w/AOGCC. Tst csg to 1500 psi - ok. Drld FC & cmt, tstd csg to 1500 psi - ok. Drld FS and 10' new form. Tstd form to 12.5 ppg - EMW - ok. Drld 8½" hole to 8687'. Ran logs DIL/SFL/GR/SP/CAL/FDC/CNL f/8701' to 3575'. Cont drlg 8½" hole to 8725' TD as of 3/30/84. Ran 225 jts 7", 26#, J-55 HFERW BTC csg w/shoe @8704'. Cmtd 7" csg w/250 sxs class "G"o Bumped plug to 3000 psi, floats held ok. ND BOPE. Instld 7" packoff & tstd to 3000 psi - ok. Performed arctic pack. Displ brine from top of well for freeze protection. Secured well and released rig @1900 hrs on 3/31/84. DH127 4/16/84 ih APR 1 9 19,8g Alaska Oil & Gas Gons. (;ommiss~o~l Anchorage KUPARUK ENGINEERING DATE' . see below Transmitted herewith are the following' PLEASE NOTE' BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE, PC - PHOTOCOPY Well Des~rip%ion Date [EI PT ACKNOWLEDGED: ASE RETURN RECEIPT TO: · DATE. ARCO ALASKA, INC. ATTN- D. FAY ALLISON - ATO/]ll5-B P. O. BOX 100360 ANCHORAGE, AK. '99510 MEMORANDUM TO: THRU: Lonnie C. Smith Commi s s lonerb %~~/ %~'E P H O N__ E NO: FROM: Ben LeNorman ~ SUBJECT: Petroleum Inspector State of Alaska ALASKA OIL AND GAS CONSERVATION C0I~-XISSION C.v.~t~erton D^TE: March 30, 1984 Chai~~ : / ~' / FILE NO: Witness BOPE Tests on ARCO' s Kuparuk 2F-10, Sec. 33, TllN,R9E,LR.~, Kuparuk River Unit. maturday, March 24, 1984: I departed my home at 1:10 pm for a 1:40 ShOwup an-d"2:40 pm departure via Alaska Airlines, Flt. ~61 for Deadhorse arriving at 4: 20 pm. Weather-. -28°F, clear, calm. Sunday, March 25, 1984: BOPE tests on ARCO's Kuparuk 2B-12 were ~0mpietedL,' ~'he'-Subject of a separate report. BOPE tests on ARCO's Kuparuk 2F-10 began at 8:55 pm and were completed at 9:55 pm. BOPE inspection report is attached. Monday, March 26, 1984: Function test on Exxon' s J-1 diverter ~ystem witnesse'd'~' the-subject of a separate report. Tuesday, March 27, 1984: Plugging for abandonment of ARCO's Kavik Ti beg-an... Wednesday, }iarch 28, 1984: ...and' was continuing when i was ~e%ieved 'b?"Ed'Sipple 'd{~e to a pulled muscle in my back. Thursday, March 29, 1984: I departed Deadhorse via Alaska ~irline~-,' Fit."'#66-~.t: 9:50 am arriving in Anchorage at 11:30 am and at my home at 12:00 noon. In summary, I witnessed successful BOPE tests on ARCO's 2F-10. Attachment STATE OF ALASKA ALASKA OIL & GAS OONSERVATION CCMM%qSION B .O.P.E. Inspection Report Date Operator ~F~ ~ Location: Sec ~ T]Z~/R ~-bi ~ ' ~illing ~n~a~or ~~~~ Rig Representative, Permit # ~- ~ ~Caslng Set Repre~ntat ive Location, C~neral ~9/~ Well Sign_ 6;/~ C~neral Housekeeping Reserve pit Rig, BOPE Stack Annular Preventer Blind Rams Choke Line Valves.__ H.C.R. Valve Kill Line Valves- ~ Check Valve Test Pressure ACCUML~ATOR SYSTEM Full Charge Pressure ~)~D~ psig Pressure After Closure /~F~9 psig Pump incr. clos. pres. 200 psig. Full Charge Pressure Attained: ~ ' N2 R~-O~ ~--~,..~~ ~ ~4~Op_ sig Controls: Master ~/~ Remote sec. min ~ sec. Blinds switch cover Kelly and Floor Safety Valves · Upper Kelly .Test Pressure Lo%~r Kelly. Bali Type Inside BOP Choke Manifold ~. valves__ ~ Test Pres sure ~ ~ Test Pressure ~ Test Pres sure ~ Test Pressure No. flanges Adj ustab le Chokes ~9. Hydrauically operated choke Test Results: Failures / Test Tin~' / hrs Repair or Replac~nent of failed equipment to be made within days and Inspector/Ccmmission office notified. Distribution orig. - AO&GEC cc - Operator cc - Supervisor ARCO Alaska, In'~''~ . Post Offic= ,~ox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 March 23, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2F-10 Dear Mr. Chatterton' Enclosed is a Sundry Notice for the subject well. We propose to complete this well with our workover rig. Since we expect to start this work on May 18, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, JBK/GRU6L50' tw Enclosures [',LAR 2 ::? ]984 Alaska Oil & Gas Cons, Oommls,~ior~' ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA '~-'- ALASK~ OIL AND GAS CONSERVATION boMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 84-40 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21094 4. Location of Well Surface: 96' FNL, 1460' FEL, Sec.33, T11N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) 125' RKB 6. Lease Designation and Serial No. ADL 25657 ALK 2583 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 2F-10 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 12. 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 Stim u late [] Abandon [] Stim u lation 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 DOPE will be nippled up and tested. 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 18, 1984 Subsequent Work Beportect [';IAR 2 .? 1984 ~asD. Oil & Gas Cons. Oomrnla$lor~ Anchorage 14. I hereby cer~f4/that the foregoing is true and correct to the best of my knowledge. Area Drilling Engineer Signed Title ission use Conditions/Of Appr~/l, if any: Date ORIGINAL $1GN£[} BY LONI IE I. SMill Approved by COMMISSIONER Form 10403 GRU6/SN23 Rev. 7-1-80 Approved Copy Returned By Order of the Commission Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate March 20, 1984 Mr. jeffrey B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 A~nchorage, Alaska 9951 Re: Kuparttk River Unit 2F- ! 0 A~.~CO Alaska, Inc. Permit Ho. 84-40 Sur. Loc. 96'~-~3'~, !460'FEL, Sec. 33. ....... TllI'-T R9~ ~. Btmhole Loc. 1376'F~, !078'FEL, Sec 34, , .... , Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of we!]~ cuttings and a mJ.~d log are not required. A continuous directional survey 'is reqUired as per 20 AAC 25.050(b)(5). If available, a tape contain .... g tn.~ digitized log information shs~], be submittod on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have be~n classified as important for the spawninE or migration of a~Mdro~ou8 =~ ~ .... ~=o .... Opera~ion~ in these areas ar~ sub~ect to AS 16.05 870 and ' .............. , . toe regulations promulgated thereunder (m~t!~ ~ Alaska Administrative Code). Prior to comenci.n~ operat~.ons 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 (.~zttm 18 Alaska Administrative Code Chapter 70) and by the Federal Water Pollution Control. Act, as amended. Prior to commencing ..... operations vou.~ ..... m~?~ be contacted .... by., a re~rem~ntmtive~ o~.... the Department of Environmental Conservstion. To aid us in scheduling field work, please notify this offence o4 hours prior to commencing ~ps~al~.a~on o~ ~..he b!owo;.tt ~ ~-~n~ ................... ~ p ............ 0,~.. Mr. Jeffrey B. k_~in Kuparuk River Unit 2F-10 -2- March 20, 1984 equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. ~ere a dtverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the~shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, Chairman of Alaska Oil and Gas Conservation Commission be Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ARCO Alaska, Inc. /'". Post Office B,._. 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 March 9, 1984 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2F-10 Dear Mr. Chatterton: Enclosed are: ° An application for Permit to Drill Kuparuk 2F-10, along with a $100 application fee ° A diagram showing the proposed horizontal and vertical projections of the wellbore o 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 March 24, 1984, your earliest approval would be appreciated. If you have any questions, please call me at 263-4970. //Area ~xjq 1 lng Engineer JBK/JG6/L24:tw Enclosures RE[EIVED MAR Oil & Gas Cons. Commission A?.chorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany la. Type of work. STATE OF ALASKA ALASKA ~JIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL DRILL REDRILL DEEPEN 20 AAC 25.0O5 EXPLORATORY [] SERVICE [] STRA'f~c, RAPHIC DEVELOPMENT GAS [] MULTIPLE ZONE J~]( 9. Unit or lease name Kuparuk River Unit 10. Well number 1 b. Type of well 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 96' FNL, 1460' FEL, Sec.33, TllN, R9E, UM At top of proposed producing interval 1300'~FNL, 1413' FEL, Sec. 34, TllN, R9E, UM At total depth 1376' FNL, 1078' FEL, Sec. 34, T11N, R9E, UM 30 mi. NW of Deadhorse 16. Proposed depth (MD & TVD) 8849' MD, 6253' TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 500 feet. 21 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 SIZE i Hole Casing Weight ;24" [ 16" 65.5# !2-1/4" I 9-5/8" 36.0# .~-1/2" 7" 26.0# 22. Describe proposed program: miles 1078' @ TD feet 17. Number of acres in lease feet 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 50 o (see 20 AAC 25.035 (c) (2) : Proposed Casing, Liner and Cementing Program CASING AND LINER SETTING DEPTH Grade Coupling Length MD TOP TVD H-40 I Weld 80' 29' I 29' J-55 Ii BTC 3546' 29' I 29' I HF-ERW ~ J-55 I BTC 8821 28' I I 28' HF-ERW I I I 2F-10 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool Amount $500,000 15. Distance to nearest drilling or completed 2F-9 well 60' @ surface feet 18. Approximate spud date 03/24/84 2761 3099 psig@ 80°F Surface .psig@ 6125 ft. TD (TVD) M D BOTTOM TV D 109'11 109' 3575' 2867' I I 8849'16253' I I QUANTITY OF CEMENT (include stage data) + 200 cf 1020 sx AS Ill & 780 sx Class G 440 sx Class G neat ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 8849' MD (6253' 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 3575' MD(2867' 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 2761 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 c~ that the foregoing is true and correct to the best of my knowledge ,,, / _ SIGNED s~sei~u ~' - TITLE Area Drilling Engineer The spa ~~o~r~s CONDITIONS OF APPROVAL Samples required []YES ~O Permit number Mud log required APPROVED BY Form 10-401 I-lYES ~ Approval date ] Directional Survey required APl number /J~ES I~NO 50-- ~ q- ~]' SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE March 20, 1984 by order of the Commission Submit in triplicate PERMIT TO DRILL 2F-10 installed and tested upon completion of the job. 2F-10 will be 60' away from 2F-9 at the surface. There are no other close wellbores anywhere downhole. Top of cement for the production string will be placed at 7600'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. RECEIVED MAR i ]984 Alaska Oil & Gas Cons, Commission Anchorage . t-lq ~illiHl !ti / t~/ i/,,,: ~/'i~,l=;~',/,~ 7 2. 3. 4. 5. . Surface Diverter System 16"-2000 psi Tankco starting head. Tankco quick connect assy. 16" X 20" 2000 psi double studded adapter. 20" 2000 psi drilling spool w/10" side outlets. 10" ball valves, hydraulically actuated, w/10" lines to reserve pit. Valves to open automatically upon closure of annular preventer. 20" 2000 psi annular preventer. 20" bell nipple. Maintenance & Ooeration 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 flow to surface is detected. If necessary, manually override and close ball valve to upwind diverter line. Do not s. hut in well under andy circumstances. ~6" Conductor ANNULAR 9 8 DIAGRAM ~1 13-5/8" 5000 PSI RSRRA BOP STACK 1. 16" - 2000 psi Tankco starting head 2. 11" - 3000 psi casing head 3. 11" - 3000 psi x 13-5/8" - ~000 psi spacer spool 4. 13-5/8" - 5000 psi x 13-5/8" - 5000 psi drilling spool 5. 13-5/8" - 5000 6. I3-5/8" - 5000 lines 7. 13-5/8" - 5000 8. 13-5/8" - 5000 g. 13-5/8" -.5000 psi pipe rams psi drilling spool w/choke and kill psi pipe rams psi blind rams psi annular BLIND $OR ILLIN~ ttD 2 ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREJ%M OF THE REGULATOR. 3. OBSERVE TIME, I'HEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING 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 STACI( AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACT- ED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND l/'3)ul~¥]~S UPS~ 01~ CHOI<]~S. DON-~T TEST ACAINST CLOSF_D CFIOIfES 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD 'FOR 10 MINUTES. 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. ~'PtLI~SSL)R~ I)O~~ O1~ CHOI<~ ISOIATION VJkLV]~S. TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD.VALVES, IF ANY, WITH 3000 PSI UPSTREm%M OF VALVE AND ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN TOP SET OF PIPE RAMS AND CLOSE BOTTOM SET OF PIPE RAMS. 10. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES BLEED TO ZERO PSi. 11. OPEN BOTTOM SET OF PIPE RAMS. 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 P, AMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLING POSITION. 13. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 15. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. 16. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. REV. I RENUMBER ALL WELLS PER NSK DRILLING. (180° ROTATION OF NUMBERING ) REV.?. CHANGE ALL ELEV.; CHANGE BASIS OF ELEV. NOTE O5 40 O6 i0 28 27 34 $:R' 8 F- 12-30-30~ ' - :' "/ PHASE II AS- BUILT -~ CONDUCTORS 9-16 "/ LOCATED IN PROTRACTED SECTION TOWNSHIP II N., RANGE 9 E.,UMIAT MER. .BASIS OF LOCATION IS MONUMENTS C.R.F.-Z N.E.& 2:C MIDDLE PER LHD ASSOCIATES. 3O DRILL. SITE AS BUILT 2'F CONDUCTORS LOCATIONS.", WELL 9 Y: 5,948~846.91 X= 517~761.38 37' FN L Lat. 70° 16'17. I0 15" Long, 1.49° 51'22.870" 1470' FE L WELL I0 Y = 5,948~757.73 X= 517,771.51 . 96' FNL Lot. 70° 16'16.5192" Long. 149051'22.580'' 1460' FEL WELL [I Y= 5,948,7?- 8.56 X-' 517,781.64 155' FNL Lat. 70° 16'15.9370" Long. 149051' 22.289" 1450' FEL WELL Y= 5,948,669.35 X= 517,791.81 214' FN L Lat. 70°16'15.3544'' Long. i ~49°51 '21.997" 1440 FEr WELL 13 WELL 14 Y = 5 ~948~ 622.31 X= 517~516.04 :~61' FN L Y= 5,948,681.31 X'- 517,505.83 202'FNL Lat.70° 16'14.89 80" Long. 149° 51 '$0.07-9" 1716' FEL Lat. 70° 16'15.4786" Lo ng. 149°51' 3 0.37-2" 1726' FEL li~'E~.L i 5 Y=5,948t740. 50 x= 517,495.75 143'FNL WELl. 16 Y =5,s~8,799.60 X = 517,485.54 8$'FNL Lat. 70016' 16. 0610" Lang. 149051' 30.61 17~6' FEL Lat.70° 16'16. 64?.6 Long. 149°51'$0.905'" 174'6' FEL DAVID FILUCC! 5276 . I HEREBY CERTIFY THAT I AM PROPERLY . REGISTERED AND LICENSED TO PRACTICE I_AND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE. UNDER MY DIRECT SUPERVISION AND THAT ALi_ DETAILS ARE CORRECT AS OF NOV. 5,198.3. ARCO Alaska, Inc. Kuparuk Project North Slope Drilling DRILL SITE 2.F CONDUCTOR AS.BUILT LOCATIONS scale' 1"=400' CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. /'~- f~ [~ ITEM APPROVE DATE (1) Fee (2 thru 8) '(8) ' (~ thru 11) s,'- ,-,. (10 and 11) ( 4 ) C,a sg ~)f ~ V ~- (12 thru 20) (21 thru 24) (6) Add: e 10. 11. 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 ............... 7. Is operator the only affected party ................................ 8. Can permit be approved before ten-day wait ......................... ' ~ __ Does operator have a bond in force ....................................... Is a conservation order needed ...................................... Is administrative approval needed ................................... 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. REMARKS Is conductor string provided .................................... Is enough cement used to circulate on conductor a~d ~u~fac; .. 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 of diverter a~d BOP equipment attached Does BOPE have sufficient pressure rating - Test to ~:~ psig .. ,~:~ __ Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. Additional requirements ............................................. Additional Remarks: CLZ)$£sT .M?PEbA~-FI t~t.L ~- /~ o ~0 Geology: Engiqeering rev: 12/08/83 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE :--/'~7 ,o/0 .-, .,,O~ ,... ! -'~ "~f'.~ '-' /7/~' ,~ 0 ~ i Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file, To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIXi .. No special'effort has been made to chronologically organize this category of information. .o VP nlO..09 VE~I~I~ITI~N I,TSm)NG PA~E I EPV?C? NAME I~DTT ACE Z~,4/04/ 9 RTG~N t ONTTNIIAmI~N # =01 R~VTOIIS EPEE, 1 OMM~NT8 tt,~RAR¥ TAPE ,R)G)N :0000 ~APE NAM~ . tqOq5 LONTTNHA?ION ~ ':R~V'TO!t$ T,AP~ !O~MFNm$ =f,I~RARY TAPE ********** E~F 'It, E NAM~ t~DTT .001 )E~VTC~ NAME : ~,ERSTO~ e "~T,E TYP~ I. 'R~VTO~S F~6~ )N ~ ARCO ALASKA TNC PN I KUPA~UK .[)[ N= ~T,~TA ALASRA ?T~Y~ ~VSA 000 000 0~0 §00 OOB' 0'0'0 O0 :002 000 000 004 OOiO 000 00:2 000 OOO OOB 000 00:0 0:06 000 000 004 065 L--r,) ,'l. 1 ,. wp~ ,[,_: [=~ ',mi (' SCH~,UMBFR~F..P ALASKA COMOUTING C~N?E)D O~!P~kNy = A'I'LAN'rlC D!CHIrlEI.,D rO~PANY gt, b = 2r-,~O I~J..,h = KUP/~RUK . 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O0 -999.9~500 9 '3:00 0859 ?50Oo IbM. r)R"O CAI,I CAb! r)RHO Tb~ DRHO DRHO DRHO CALX DR~O RHO C A t, I ORHO CAbZ C~LI DRHO CA%I -q9~.2500 -~99.2500 -099.~500 3'.13~7 -999. -999.~500500 . 3'$ -999.~500 4.~6~5 9~,2500 .,soo -P99.2500 !500 -999.~500 99.9. 41.00.0000 -4,?. 1.2~0 aT -o9~.9500 ',PT 4nOn'. nO00 gFI,,U ~T -990. ~'500 ' l~O.nO00 ~FLU ~B -o99..~500 ~CNL ~T -090.~500 ~N~A 3.mOO., noO0 -5~ ~437 -~9~. ~500 PNPA 3700'0000 -43. ~ 875 -g'9~, ~500 ~CNL 3~00". 0000 -3g. ~ 875 -~90.. ~500 NCNb 3~2~'. 5000 -B3.~3~5 -qgo. 9500 ~C~'L -099,~500 3'1 -q99,9500 rC"L 9 7, ~ 5 0 0 ~ P H I 6~. 4:37'5 -999, ~500 rC~b 85 75 3' 56~4 81 .~6~5 9 e '" " .~500 81..3750 -090-,9500 WCN[, ,o90.~500 17. 3504 Tt, b -09q.~sno rCNL -og~.95o0 ~ TaPF WRalf. 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