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Home My WebLink About178-030Originated: Schlumberger PTS - PRINT CENTER 2525 GAMBELL STREET, STE. 400 ANCHORAGE, AK 99503 (907) 273-1700 main ce Delivered to: MakanaK Bender Natural Resources Technician lI Alaska Oil & Gas Conservation Commission 333 W 7'� Ave. Suite 100 Archoraue. AK 90601 zZf"87' r TRANSMITTAL DATE L, TRANSMITTAL # ��l DATA LOGGED g t3o/201y, IA. K. BENDER WELL NAME 01-02 SERVICE ORDER# C2JC-00173 FIELD NAME SERVICE PRUDHOE BAY DESCRIPTION WL DELIVERABLE DESCRIPTION SCMT/JETCUT DATA TYPE FINAL FIELD DATELOGGED 3 -Sep -14 • •• PRINTS 1 CDs 1 04-17 CBOO-00084 PRUDHOE BAY WL RST FINAL FIELD 12 -Sep -14 1 1 MPB-05A CFGK-00085 MILNE POINT MEMORY (PROF FINAL FIELD 5 -Sep -14 1 1 MPC -42 CFGK-00083 MILNE POINT MEMORY IPROF FINAL FIELD 2 -Sep -14 1 1 MPE-23 CFGK-00084 MILNE POINT MEMORY (PROF FINAL FIELD 3 -Sep -14 1 1 MPF -81 CY89-00027 MILNE POINT MEMORY LDL FINAL FIELD 15 -Sep -14 1 1 L1-21 CYCD-00026 LISBURNE WL PPROF FINAL FIELD 16 -Sep -14 1 1 1-2-33 C1SD-00130 LISBURNE MEMORY LDL FINAL FIELD 17 -Sep -14 1 1 MPH -191-1 C1SD-00131 MILNE POINT MEMORY PPROF FINAL FIELD 18 -Sep -14 1 1 MPJ -15 CY89-00028 MILNE POINT MEMORY IPROF FINAL FIELD 18 -Sep -14 1 1 17-06 CFMH-00084 PRUDHOE BAY WL IPROF FINAL FIELD 10 -Aug -14 1 1 09-04A CFMH-00083 PRUDHOE BAY WL LDL FINAL FIELD 8 -Aug -14 1 1 1-5-28A CYCD-00021 LISBURNE WL PPROF FINAL FIELD 17 -Aug -14 1 1 G -29B ClSD-00125 PRUDHOE BAY MEMORY PPROF FINAL FIELD 11 -Aug -14 1 1 G -08A CV61-1-00035 PRUDHOE BAY MEMORY PPROF FINAL FIELD 2 -Aug -14 1 1 18-11B CY89-00023 PRUDHOE BAY MEMORY LDL FINAL FIELD 2 -Sep -14 1 1 P2-53 C2JC-00149 PRUDHOE BAY WL PPROF FINAL FIELD 11 -Jun -14 1 1 F-36 CYCD-00014 PRUDHOE BAY WL USIT FINAL FIELD 23 -Jul -14 1 1 S-13 CYCD-00023 PRUDHOE BAY WL USIT-MSIP FINAL FIELD 8 -Sep -14 1 1 18-07A CFMH-00081 PRUDHOE BAY WL LDL FINAL FIELD 16 -Jul -14 1 1 MPL-08 CY89-00020 MILNE POINT MEMORY IPROF FINAL FIELD 10 -Aug -14 1 1 15-01B Cl SD -00128 PRUDHOE BAY MEMORY PPROF FINAL FIELD 19 -Aug -14 1 1 02-21B ClSD-00127 PRUDHOE BAY MEMORY LDL FINAL FIELD 17 -Aug -14 1 1 1-5-16A C2JC-00166 LISBURNE WL PPROF FINAL FIELD 6 -Aug -14 1 1 Transmittal Receipt Print Name 0Transmittal Receipt signature confirms that package (box, envelope, etc.) has been received and the contents ents of the package X have been verified to match the media noted above. The specific Signature Date 9 IZ911t content of the CDs and/or hardcopy prints may or may not have been I verified for correctness or quality level at this point. Please return via courier or sign/scan and email a copy to Schlumberger. 561-8317 fax Stephanie Pacillo Data Delivery Services Technician Schlumberger Oilfield Services WIRELINE 2525 Gambell St, Ste. 400 Anchorage, AK 99503 9: Office: (907) 273-1770 DATE: 23 -Aug -12 TRANSM 6044 MakanaK Bender 'Ib Natural Resources Technician II Alaska Oil & Gas Conservation Commission 333 W. 7` Ave, Suite 100 F>rchorage, AK 99601 WELL SERVICE ,OH RESERV CNL MECH LOG DESCRIPTION DATE B/W COLOR CD's NAME ORDER # DIST DIST DIST DIST LOGGEDPRINTS G-258 BAUJ-00145 X MEMORY (PROF 25 -Jul -12 1 1 CD E -09C 6COO.00024 X PPROFIIPROF MCNL 12 -Jul -12 1 1 CD G-048 C600.00026 X MEMORY PPROFIIPROF MCNL 10 -Jul -12 1 1 CD K-1 OC SAUJ-00138 X MEMORY PPROF WI GHOST 29 -Jun -12 1 1 CD V-202 C600-00031 X MEMORY LUL 22 -Jul -12 1 1 1 CD Z -06A CSXI-00016 X MEMORY PPROF 13 -Jul -12 1 1 CD W -02A CSXI-00018 X MEMORY LEAK DETECTION 15 -Jul -12 1 1 CD 14-33A CSXI-00006 X MEMORY PPROF 13 -Jun -12 1 1 CD 05-23B BAUJ-00140 X MEMORY PPROF WI GHOST 3 -Jul -12 1 1 CD H-09 C=40027 X IPROF 23 -Jun -12 1 1 1 CD MPS -018 SZ81-00021 X PDC CORRELATION 9 -Jul -12 1 1 CD MPS -01H BZ81-00021 X USI? 11 -Jul -12 1 1 CD 05-228 8CRC-00196 X MEMORY PPROF 9 -Jul -12 1 1 CD P1-05 _ 15YU-00048 X IXFLOW W/ IBP SET RECORD 20 -Jun -12 1 1 1 CD L1-09 BVYC-00041 X PPROF 16 -Jul -12 1 1 CD L1-21 APBSURVE X PPROF 26 -Jun -12 1 1 CD N-12 APBSURVEEL, X PPROF 19 -Jul -12 1 1 CD 05-22B v� BCRC-00196 X MEMORY PPROF WI GHOST 9 -Jul -12 1 1 CD 18-25A 11996389 X ISCMT 13 -Mar -08 1 ICD G -258f BAUJ-00145 X IMEMORY PPROF W/ GHOST 24 -Jul -12 1 1 CD Z-1 3A BAUJ-00142 X IMEMORY LEAK DETECTION 7 -Jul -12 1 ICD x Please return a signed copy to: BP PDC LR2-1 900 E Benson Blvd Anchorage AK 99508 Please return a signed copy'to: DCS 2525 Gambell St, Suite 400 Anchorage AK 99503 STATE OF ALASKA ALASKA &ND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Other ❑ Performed: Alter Casing ❑ Pull Tubing Perforate New Pool ❑ Waived] Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate 0 Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development II Exploratory ❑ . 178 -0300 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 . 50- 029 - 20304 -00 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028302 . L1 -21 10. Field /Pool(s): PRUDHOE BAY FIELD / LISBURNE OIL POOL 11. Present Well Condition Summary: Total Depth measured 10383 feet Plugs (measured) None feet true vertical 10366.34 feet Junk (measured) None feet Effective Depth measured 9000 feet Packer (measured) 8094 8675 feet true vertical 8988.84 feet (true vertical) 8086 8665 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 94# H -40 30 - 110 30 - 110 1530 520 Surface 2709' 13 -3/8" 72# L -80 29 - 2738 29 - 2738 4930 2670 Production 8495' 9 -5/8" 47# L -80 28 - 8523 28 - 8514 6870 4760 Liner 2180' 7" 29# L -80 8203 - 10383 8195 - 10366 8160 7020 Liner Liner Perforation depth: Measured depth: SEE ATTACHED - - . " ra -t U ' — True Vertical depth: _ _ Tubing: (size, grade, measured and true vertical depth) 5 -1/2" 17# L -80 27 - 41 27 - 41 4-1/2" 12.6# L -80 41 - 8092 41 - 8084 3 -1/2" 9.3# L -80 8092 - 8687 8084 - 8677 2 -7/8" 6.5# L -80 8687 - 8697 8677 - 8687 Packers and SSSV (type, measured and true vertical depth) 4 -1/2" Baker DB Packer 8094 8086 3 -1/2" FB -1 Packer 8675 8665 12. Stimulation or cement squeeze summary: RECEIVED Intervals treated (measured): SEP 3 0 Nil Treatment descriptions including volumes used and final pressure: t 3 Oil & Gas Cons. Commission 13. Representative Daily Av *Qion or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 392 16,044 13 700 Subsequent to operation: 846 27,318 108 1,021 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development El . Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil . 0 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed N. e oe Last ' Title Petrotechnical Data Technologist Signs re ,kntI_ Phone 564 -4091 Date 9/29/2011 RBDMS OCT 0 3 4;I' '�'' / 0. 3 .11 Form 10-404 Revised 10/2010 Submit Original Only li' rD/,A L1 -21 178 -030 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base L1 -21 8/30/78 PER 8,810. 8,822. 8,799.79 8,811.74 L1 -21 8/30/78 PER 8,834. 8,856. 8,823.68 8,845.57 L1 -21 8/30/78 PER 8,890. 8,902. 8,879.39 8,891.33 L1 -21 9/8/78 APF 8,697. 8,745. 8,687.35 8,735.1 L1 -21 9/12/78 APF 8,560. 8,639. 8,551.02 8,629.65 L1 -21 3/2/08 BPS 8,316. 8,902. 8,307.88 8,891.33 L1 -21 3/15/08 BPP 8,316. 8,902. 8,307.88 8,891.33 L1 -21 9/4/11 APF 8,834. 8,844. 8,823.68 8,833.63 L1 -21 9/4/11 APF 8,844. 8,856. 8,833.63 8,845.57 L1 -21 9/4/11 APF 8,890. 8,902. 8,879.39 8,891.33 AB ABANDONED PER PERF APF ADD PERF RPF REPERF • BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • w L1 -21 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 9/4/2011 ** *Continued from 09 -03 -11 WSR * ** T /I /0= 2200/0/0 Assist E -line Load and Kill (Perforating) Pumped 5 bbls neat methanol and 295 bbls 2% KCI down Tbg. Pumped 38 bbls crude down Tbg for Freeze Protect. FWHP =0/0/0 E -line in control of well upon departure. 9/4/2011 ,***JOB CONTINUED FROM 3- SEP- 2011 * ** (E -LINE: PERF) ;LRS FINISHES PT. CONTINUE WITH HOT CHECK AND ARMING 10' GUN. RIH AND TIE IN TO SLB CBL LOG DATED 10 -AUG -1978. PULLED TO SAFE POSITION WHILE LRS KILLED WELL WITH 295 BBLS OF 2% KCL. PERFORATED INTERVAL 8834' -8844' AFTER CONFIRMING WITH CLIENT, CCL TO TOP SHOT = 3.3 FT AND CCL STOP DEPTH = 8830.7 FT. POOH WHILE LRS I ; PUMPED 38 BBLS OF FREEZE PROTECT TUBING. GOOD CONFIRMATION OF ;SHOOTING AT SURFACE. RIH WITH GUN# 2 (12FT LOADED). PERFORMED TIE IN PASS AND PERFORATED INTERVAL 8844FT- 8856FT AFTER CONFIRMING WITH PE CCL TO TOP SHOT = 7.3FT AND CCL STOP DEPTH = 8836.7FT. POOH.; GOOD CONFIRMATION OF SHOOTING AT SURFACE. RIH WITH GUN# 3 (12 FT ; LOADED), PERFORMED TIE IN PASS AND PERFORATED INTERVAL 8890' - 8902' AFTER CONFIRMING WITH CLIENT, CCL TO TOP SHOT = 7.3 FT AND CCL STOP DEPTH = 8882.7 FT. CHARGE DATA: 2" PJ HMX 6 SPF, PENETRATION 19.0 ", ENTRANCE HOLE 0.23 ", 6.5 GMS. ** *JOB COMPLETE * ** (WELL SHUT IN UPON DEPARTURE) - FLUIDS PUMPED BBLS 5 NEAT METH 295 2% KCL 38 CRUDE 338 TOTAL TREE = ' ` FMC I WELLHEAD = FMC + •EtY NOTES ACTUATOR = AXELSON L 1 -2 1 KB. ELEV = 54' BF. ELEV = KOP = 5600' ) I 41' I — L 5-1/2" X 4-1/2" XO I Max Angle = 6 @ 5600' Datum MD = 8965' Datum TVD = 8900' SS { 2232' H 4 -1/2" OTIS HRQ WR SSSV, ID = 3.813" I I5 -1/2" TBG- IPC,17 #, L -80, .0232 bpf, ID = 4.892" 41' ■ GAS LIFT MANDRELS 113 -3/8" CSG, 72 #, L -80, ID= 12.347 H 2738' ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2344 2344 2 CA -MMG RD 2 7027 7019 1 CA -MMG RD 3 7952 7944 2 CA -MMG RKED Minimum ID = 2.205" @ 8692' PRODUCTION MANDRELS OTIS XN NIPPLE ST MD TVD DEV TYPE VLV LATCH PORT DATE L 4 8405 8397 5 KBUG DMY BEK -2 0 07/27/90 L 5 8493 8484 6 KBUG DMY BEK -2 0 07/27/90 ( 4 -1/2" TBG -IPC, 12.6 #, L -80, .0152 bpf, ID = 3.958" H 8092' I-- 1 8092' I — I 4 -1/2" X 3 -1/2" XO I 1 8094' I — I 9 -5/8" BAKER DB PKR, ID = 4.75" I I TOP OF 7" LNR H 8203' 1 1 1 8333' H 3 -1/2" OTIS XN NIP, ID = 2.75" I 19 -5/8" CSG, 47 #, L -80, ID = 8.681" H 8523' I — A Ul 8570' H BAKER 3 -1/2" BLAST JOINTS, 94' I 8675' H7" BAKER FB -1 PKR, ID = 4.00" I 13-1/ TBG -IPC, 9.3 #, L -80, .00870 bpf, ID = 2.992" 8 687' K 3-1/2" X 2-7/8" XO I H 1 � 8687' H ( 8692' H 2-7/8" OTIS XN NIP, ID = 2.205" 2 -718" TBG IPC, 6.5 #, L -80, .00579 bpf, ID = 2.441" H 8697' I I 8697' (--I 2-7/8" TUBING TAIL W /BAKER WLEG I PERFORATION SUMMARY 1 H ELMD TT NOT LOGGED I REF LOG: FDC/CNL 07/23/78 ANGLE AT TOP PERF: 6 @ 8560' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 2 -1/8" 1 8560 - 8639 0 09/12/78 2 -1/8" 1 8697 - 8745 0 09/08/78 2 -1/8" 1 8810 - 8822 0 08/30/78 2" 6 8834 - 8856 0 09/04/11 2 -1/8" 1 8834 - 8856 0 08/30/78 2" 6 8890 - 8902 0 09/04/11 2 -1/8" 1 8890 - 8902 0 08/30/78 I PBTD —I 9000' 4. f fffff I7" LNR, 29 #, L -80, .0371 bpf, ID = 6.184" ( — I 10383' I 0. +..•• DATE REV BY COMMENTS DATE REV BY COMMENTS LISBURNE UNIT 08/05/78 ORIGINAL COMPLETION WELL: L1 -21 07/27/90 RWO I PERMIT No: 78 -030 09/29/01 RN/TP CORRECTIONS API No: 50- 029 - 20304 -00 03/04/07 RL DATUM MD SEC 1 T11N R14E2367.58 FEL 4479.83 FNL 03/10/08 DAV/TLH 3 -1/2" NIP CORRECTION 09/20/11 SRD/ PJC PERFORATIONS (09/04/11) I BP Exploration (Alaska) 06/08/09 ~1 U ..~•~ ~l~~litflR~~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description NO.5271 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Date BL Color CD H-35 AYTO-00018 CROSS FLOW CHECK j 05/09/09 1 1 14-35 ANHY-00087 INJECTION PROFILE ~ 05/15/09 1 1 06-08A AV1H-00012 IBP/FBS/CFS/GRADIO/PRESS/T P 05/11/09 1 1 A-44 AWLS-00017 SCMT 05/25/09 1 1 12-07A BOCV-00016 SBHP SURVEY 05/19/09 1 1 09-24 ANHY-00088 CROSS FLOW CHECK/IBP ~ 05/17/09 1 1 H-29A AYQO-00027 PPROF/RST - 05/19/09 1 1 09-09 AYTU-00032 CROSS FLOW CHECK - ~- 05/06/09 1 1 15-45B ANHY-00010 PRODUCTION PROFILE ~- 05/09/09 1 1 13-13A AYTU-00033 USIT - ~ ~ 05/08/09 1 1 M-196 AY3J-00024 PRODUCTION PROFILE 05!14/09 1 1 Z-12 ANHY-00084 INJECTION PROFILE 05/07/09 1 1 E-36A B1JJ-00018 MEM CNUSTP / 05/18/09 1 1 X-30A 62WY-00005 MEM PROD PROFILE C 05/10/09 1 1 12-23 AYKP-00021 USIT L - 05/08/09 1 1 W-34A AWJI-00031 MEM PROD PROFILE 05/19/09 1 1 - Z-14B AZCM-00022 PROD PROFILE/JEWELRY LOG • (~- 05/20/09 1 1 L7-21 B2NJ-00006 PRODUCTION PROFILE 05/24/09 1 1 A-31A AZCM-00023 USIT ~ - Q (a G 05/22/09 1 1 H-19B' 62WY-00004 MEM PROD PROFILE Z 05/07/09 1 1 G-16 AYKP-00022 SCMT f / 05/09/09 1 1 M-196 AY3J-00024 SCMT 05/15/09 1 1 12-37 AWL9-00032 PRODUCTION PROFILE _ L/G~ / 04!21/09 1 1 11-04A AYOO-00028 USIT f L/ - 05/21/09 1 1 18-30 61JJ-00015 MEM PROD PROFILE >G/ 05/i3/09 1 1 4-14A/S-37 AYKP-00024 PRODUCTION PROFILE ~ v~ d 05/11/09 1 1 3-37/L•35 AWL9-00035 PROD/INJECTION PROFILE 05/22/09 1 1 3-37/L-35 AWL9-00035 TEMPERATURE SURVEY 05/20/09 1 1 V-217 AYOO-00024 INJ PROFILE/RST WFL `} ~ /~/J 04/26/09 1 1 YLtAJt AI:RIVUWLtUtGt titl:tlY I tST 511aIV11V(a AIVU Flt l UtiIV11V19 VIVt t:UYT tAl:r1 I V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. •>-tin • s' ~= ~ fit,` ., ~~y~, Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ((;~i ~í"r: ft~\ 'Ti if' ',", "I ¡iiI, !:.:! ') ¡ ~.J,' i L (1) .~ L {rÜ l J l_l "'1¡ ";-.:1 (r,! I L lU) U-" /".-\ ! '! j~'\ (r~'ì ¡"lri r;' I. \ I I .I Î' i l \ U ,! 1,..\ !i\ill II\,',""I(¡I\\ ¿~~ l1 ¡¡~ @ U'~ Lf\i ; ! FRANK H. MURKOWSKI, GOVERNOR ! / ALAS KA 0 IL AND GAS CONSERVATION COMMISSION í 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 May 12,2004 Mr. Bruce J. Williams GPB Operations Integrity Manager BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, AK 99519-6612 Dear Mr. Williams: The Alaska Oil and Gas Conservation Commission ("Commission") received well safety valve system (SVS) test reports from BP Exploration (Alaska) Inc. at Prudhoe Bay Unit Lisburne sites as follows: Location Date of SVS Test Failure Rate PBU L1 ' April 23, 2004 30.0% PBU L2 April 26, 2004 16.7% PBU L3 April 27, 2004 50.0% Copies of the SVS Test Reports are attached. Regulation at 20 MC 25.265 requires all wells to be equipped with a Commission approved fail-safe automatic surface SVS capable of preventing uncontrolled flow by shutting off flow at the wellhead and shutting down any artificial lift system where an overpressure of equipment may occur. If installed, a subsurface safety valve must be maintained in working order and is subject to performance testing as part of the SVS. Commission policy, as outlined in a letter dated November 14, 1995, states that the testing frequency will be increased when a failure rate exceeds 10 percent. The AOGCC-AOGA Safety Valve System Task Force report issued June 13,2003, supported retention of the 10% failure threshold. Effective the date of SVS test, and until an acceptable level of performance is achieved, the safety valve systems associated with wells located on PBU Ll, L2, and L3 must be tested every 90 days. When testing is schedul, must notify the Commission Field Inspector at 907-659-2714 to provide an opportunity to w't th SVS test. Sincerely, 2J~ J . Norman, Chair Commissioner Daniel T. Seamount, Jr. Commissioner 3 Attachments cc: AOGCC Inspectors (via email) Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Ron White AOGCC Rep: Waived Submitted By: Ron Marquez Date: 04/23/2004 UnitiFieldlPad: Greater Pt McIntyre/Lisbume/Ll Separator psi: LPS 450 HPS 450 Well Permit Separ Set LIP Test Test Test Date Tested and or Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed Retest or SI GAS, CYCLE, SI 11-01 1850550 7/19/2003 SI 11-02 1851720 450 350 320 P 5 P 4/27/2004 011 11-09 1850010 450 700 690 P P P OIL LI-lO 1850830 4/30/1990 SI LI-14 1851400 3/10/1996 SI Ll-15A 2031200 450 350 350 P P P OIL 11-21 1780300 450 600 550 P 5 P 4/27/2004 OIL 11-27 1891220 5/10/1994 SI 11-28 1880250 12/17/1992 SI 11-30 1900180 3/28/1995 SI LI-31 1980150 450 350 350 P 5 P 4/27/2004 OIL Wells: 5 Components: 10 Failures: 3 Failure Rate: Remarks: 11-024/23/2004: Called grease crew and heater 11-21 4/23/2004: Called grease crew L1-31 4/23/2004: Called grease crew Page 1 of 1 SVS PBU LIS L 1 04-23-04.xls ARCO Alaska, Inc. Post Office Box 100360 Anchorage Alaska 99510-0360 Telephone 907 276 1215 September 27, 1993 Mr. Dave Johnston AOGCC 3001 Porcupine Drive Anchorage, AK 99501 R£C.£1VEb 0CT - 1 1993 Alaska Oil & (]as Cons. L;onlmissio,,~ Anchorage Subject: L1-21 Downhole Separation TestmSundry Approval Dear Dave: Sundry approval is requested for a short-term test on Lisburne Well L1-21. The test will involve oil and gas separation downhole Kith. gas being produced up the 4-1/2" x 9-5/8" annulus and low GOR oil productibn in the 4-1/2" tubing string. A similar test was performed last year at L5J~:~. While separation was achieved, liquid carryover became a problem at high gas takeoff. We therefore have pursued a more active method of separation, the auger separator, shown schematically in Attachment 1. As shown, fluid will go through an auger where the centrifugal force causes movement of the oil to the outside while gas goes up the center. A crossover tool diverts gas into the tubing/casing annulus through an open gas lift mandrel. Temporary piping will connect the annular production to the L1~23 well slot. We request approval to conduct this test without subsurface safety valve (SSSV) control of the annular fluids. Subsurface control of tubing production will be operational. A surface safety valve (SSV) will be placed on the 4-1/2" x 9-5/8" annulus. Dedicated manning during production of the annulus is planned. Annular production is planned to last no more than three weeks, and the downhole equipment will be removed within six weeks of installation. Successful downhole separation could provide a gas source at high flowing surface pressures (1,100-1,500 psi in this well). The gas could potentially be used to provide for raw gas lift, thereby reducing overall gas handling requirements. Also, this could potentially make additional gas compression and injection economically attractive since compression ratios and required horsepower will be lower. While lab tests of the auger separator have been conducted with excellent results, a field test of this concept is needed for verification. Key objectives of the test are to determine the effectiveness of separation, to determine pressure drops in both the annulus and tubing for projection in longer-term applications, and also to attempt to lift nearby well LI-1. ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company Mister Johnsto~ September 27, 1993 Page 2 We are continuing to investigate options for long term downhole 'SSSV' control of the annular production. For this short term test, in order to optimize design of the downhole separator, we wish to test without SSSV control of the annulus. With the SSSV and continual manning of the test site during annular flow, safe, short-term operation can be assured. Your timely approval of this short-term downhole separation test on L1-21 would be appreciated. Please call me at 265-6538 if you have any questions concerning the test. r i.~L ~arris Lisburne/Point Mclntyre Engineering JLH/MJW:jb Attachments RECE VF-D 0 CT - 1 t99;5 ,Alaska Oil & Gas Cons. Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany A (A OIL AND GAS CONSERVATION COMk ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Alter casing _ Repair well _ Change approved program _ Operation Shutdown_ Re-enter suspended well_ Plugging _ Time extension Stimulate Pull tubing _ Variance _ Perforate _ Other x_ 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 2500 FNL, 2500 FWL, Sec. 1, Tll N, R14E, UM At top of productive interval 2500 FNL, 2500 FWL, Sec. 1, Tll N, R14E, UM At effective depth 2500 FNL, 2500 FWL, Sec. 1, T11N, R14E, UM At total depth 2500 FNL, 2500 FWL, Sec. 1, T11N, R14E, UM 6. Datum elevation (DF or KB) RKB ' 54.5' feet 7. Unit or Property name Prudhoe Bay Unit/Lisburne 8. Well number L1 -21 9. Permit number 78-30 10. APl number 5o-0 2 9-~~L~,b-o~ ~.~ 11. Field/Pool (2' Lisburne Oil Pool 12. Present well condition summary Total Depth: measured 10,383' MD true vertical 10,383' TVD Effective depth: measured 9,000' MD true vertical 9,000' TVD Casing Le n gt h Size Structural Conductor 80' 20" Surface 2738' 13-3/8" feet Plugs (measured) feet Norle feet Junk (measured) feet None Cemented Measured depth True vertical depth 175 sx AS11 76' MD 76' MD 4300 sx PF 11 2738' MD 2738' MD Intermediate 8523' 9 5/8 1000 sx Class G 8523' MD 8523' MD Production 2180' 7" 450 sx Class G 8203' MD 8203' TVD Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth 4 1/2" 12,6# L-80 to 8092' MD, 3 1/2 " 9.3# L-80 to 8686' MD, 2 7/8" 6.5# L-80 to 8697' MD Packers and SSSV (type and measured depth) 8094' Baker 9 5/8" DB, 8650 Baker 7" FB-1, SSSV is Otis 4 1/2" 'HRQ' Wireline Retrievable 13. Attachments Description summary of proposal x (Wellbore schematic attached). 14. Estimated date for commencing operation October 15, 1993 16. If proposal was verbally approved Detailed operation program__ BOP sketch 15. Status of well classification as: Oil ~ Gas __ Suspended _ Name of approver Date approved 17. I hereby, cert~,l'~t th~ for?gibing is true and correct to the best of my knowledge. ;~' fZ2' / // -- FOR COMMISSION USE ONLY Service Conditions of approval' Notify Commission so representative may witness Plug integrity __ BOP Test Location clearance Mechanical Integrity Test _ Approved by the order of the Commission Form 10-403 Rev 06/15/88 IApproval No. Subsequent form require 10-5~O~ Original S~gned By /'¢ '-~?-~'~_ ....... David W. Johncton SUBMIT IN TRIPLICATE RECEIVED 0 CT - 1 199;5 Alaska 0ii & Gas Cons. C0mmis Aneh0raae DS L1-21 Proposed Procedure for Downhole Separation , , . 4. 5. . . Perform MIT test on 4-1/2" x 9-5/8" annulus. Monitor 13-3/8" annulus pressure. Insure no communication between 9-5/8" x 13-3/8" annulus before proceeding with test. Rig up temporary piping from L1-21 4-1/2" x 9-5/8" annulus to L1-23 well slot. Install SSV. Pressure test piping. Change out dummy GLVs in L1-2! at 7,952' MD and 7,027' MD. Drift tubing. Unload annulus. Set retrievable packer below mandrel at 7,027'. Set auger separator with upper retrievable packer and sting into polish bore of lower packer. Set packer. Begin production up both tubing and 9-5/8" annulus. Well will be manned throughout test and pressures will be monitored. Well tests of both annular and tubing flow will be obtained. Annulus will be flowed for maximum of three weeks. During this interval, the annular gas may be used to lift LI-1. Within six weeks of installation, pull retrievable packers and separator. Return L1-21 to original condition. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany RECEIVED OCT - 1 199~ ,~laska o~1 & Gas Cons. Comm~Ss~', Anchorage Attachment 1 AUGER SEPARATOR OIL GAS OIL GAS T GAS UBING CASING AUGER SEPARATOR W/CROSSOVER &TUBING PACKOFF PERFORATIONS .~,ttachment 2 IVVELL L1 1 SCHEMATIC IAPI # 50-029-20:304-01 ] er Separator Placed at 2nd Station 10 3 14 16 20 Status: Producer Surface Location: 2500 FNL, 2500 FVvL, Secl, T11 N, R14E, UM Top Lisbume Loc: 2610 FSL, 2488 FWL, Sec1, T11 N, R14E, UM RKB To Tubing Hanger: 27 Feet Top of Wahoo: 8566 MD/8503 SS Datum: 8965 MD/8900 SS Reference Log: FDC/CNL(Porosity),7-23-78,Schl. Annulus Fluids: Inhibited seawater w/2200' diesel cap. Spud Date: 6-18-78 Completion: 10-7-78 Recompletion: 7-28-90 Minimum ID; 2.205" @ 8692' MD 1. 27 MD-5-1/2" TBG HANGER, 5-1/2" X 17.0# L-80 2. 41 MD-5-1/2" X 4-1/2" X/O 3.43 MD--4-1/2" X 12.6# L-80 TBG 4. 2232 MD -- OTIS 'HRQ' SSSV WlRELINE RETR, 3.813"ID 4. 2226 MD AND 2234 MD - CAMCO FLOW COUPLINGS 5. 2738 MD -- 13-3/8"X72# CSG. SET 6. GAS LIFT MANDRELS DEPTH MANDREL TYPE VALVE LATCH TRO 2344 MD CAMCO 1-1/2" MMG DUMMY RK 7027 MD CAMCO 1-1/2" MMG DDDUMMY RK 7952 MD CAMCO 1-1/2" MMG EQDMY RKED 8092 MD - 4-1/2" X 3-1/2" X/O 8094 MD- BAKER 9-5/8" DB PACKER, 4.75"1D 8120 MD- 3-1/2" X 9.3# L-80 TBG 8203 MD - TOP OF 7"X29# L-80 LINER 8333 MD - 3-1/2" OTIS XN NIPPLE, 2.75 I.D. w/2.635"No-Go. . 8. 9. 10. 11. 12. 13. 14. 3-1/2" EQUALIZING MANDRELS 8405 MD - CAMCO 1" KBUG EQ DMY BK-2 8493 MD - CAMCO 1" KBUG EQ DMY BK-2 8523 MD - 9-5/8" X 47# L-80 CSG WAHOO 7/6 PERFORATIONS JSPF GUN 8560 - 8589 1 TT 8589 - 8639 1 TT 15. 8570 MD- 1 6.8650 ELMD 17. 8686 MD- 1 8. 8692 MD- 19. 8697 MD- 20. WAHOO 5 PERFORATIONS 8697 - 8745 21. WAHOO 4 PERFORATIONS 8810 - 8822 8834 - 8856 8890 - 8902 22. 9011 MD - PBTD 23. 10383 MD-TD 3-1/2" J-55 BAKER BLAST JTS, 94' - BAKER "FB-1" PACKER W/4" BORE 2-7/8" X 6.5# L-80 TBG 2-7/8" OTIS XN NIPPLE, 2.205 I.D. 2-7/8" BAKER WL GUIDE. JSPF GUN 1 TT JSPF GUN 1 TT 1 TT 1 TT MAXIMUM WELL DEVIATION: 0 DEGREES / STRAIGHT HOLE SS DEPTH (2290 SS) (6965 SS) (7890 SS) (8497-8576' SS) (8633-8681' SS) (8746-8837' SS) RECEIVED OCT - 1 199~ MAXIMUM H2S LEVEL MEASURED - 40 PPM Alaska Oil & Gas Cons. Anchorage Revision Date: 6-13-91 (4) 1. Operations Performed: STATE OF ALASKA ALA~r,,A OIL AND GAS CONSERVATION COMMISolON REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown__ Stimulate m Plugging __ Perforate Alter casing __ Repair well m Pull tubing X Other...~. Workover 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 2500' FNL, 2500' FWL, Sec. 1, T11N, R14E, UM At top of productive interval 2500' FNL, 2500' FWL, Sec. 1, T11N, R14E, UM At effective depth 2500' FNL, 2500' FWL, Sec. 1, T11N, R14E, UM At total depth 2500' FNL, 2500' FWL, Sec. 1, T11N, R14E, UM 6. Datum elevation (DF or KB) 54.5' RKB 7. Unit or Property name Prudhoe Bay Unit/Lisburne 8. Well number L1-21 9. Permit number/approval number 78-30/9-960 10. APl number 50-029-20304 11. Field/Pool Prudhoe Bay Field Lisburne Oil Pool feet 12. Present well condition summary Total Depth: measured true vertical 10383' 10383' feet Plugs (measured) None feet Effective depth: measured 9000' true vertical 9000' feet Junk (measured) None feet Casing Length Size Conductor 8 0' 2 0" Surface 2738' 1 3-3/8" Intermediate 85 23' 9 - 5 / 8" Liner 21 80' 7" Cemented Measured depth True vertical depth 175 sx AS II 76' 76' 4300 sx PF II 2738' 2738' 1000 sx Class G & 8523' 8523' 300 sx PF cmt 450 sx Class G 8203'-1 0383' 8203'-1 0383' Perforation depth' measured 8560'-8639', 8697'-8745', 8810'-8822', 8834'-8856', 8890'-8902' true vertical 8560'-8639', 8697'-8745', 8810'-8822', 8834'-8856', 8890'-8902' Tubing (size, grade, and measured depth) 5-1/2" / 4-1/2", L-80, tbg w/ tail @ 8697' Packers and SSSV (type and measured depth) OTIS 'HRQ' @ 2232', Baker 'DB' & 'FB-I' pkr @ 8097' & 8675' 13. stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure RECEIVED AUG 2 3 1990 &!as Ojt & Gas Cons. 14. N/A Prior to well operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Subsequent to operation 15. Attachments *WORKOVER WELL HISTORY Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector ~ Oil ~ Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Re 05/17/89 Title Drillincj Analyst Date ~' 2~' ~0 SUBMIT IN DUPLICATE ARCO Oil ~...a Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a welt is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. County. parish or borouoh District ARCO ALASKA INC. NORTH SLOPE AK Field LISBURNE . Lease or Unit ADL: 28302 Auth. or W.O. r~.L1253 Tit e WORKOVER API: 50-029-20304 IARCO wi. Operator ARCO 50.0000 Spudded or W.~,~T ]Date 07/17/90 IH°ur 0530 HRS Prior status if a w.o. Date and depth as of 8:00 a.m. 07/17/90 ( TD: 0 PB: 9000 SUPV:HMP 07/18/90 ( TD: 0 PB: 9000 $UPV:HMP 07/19/90 ( TD: 0 AUG 2 990 07/20/90 ( TD: 0 PB: 9000 S~V: DCS/~D 07/21/90 ( TD: 0 PB: 9000 SUPV:DCS/MDD The~J correct Sj~na~J~ .. / ~S d i~re~ t i ~nb uf i0,o-n, - _ '--Drilling,~and 87. Complet ...... d l~ ~:~:~ y RU TO KILL WELL MW: 9.5 NaCl MOVE RIG FROM DS 4-2 TO L1-21. ACCEPT RIG @ 0530 HRS, 7/17/90. RU TO WELLHEAD TO KILL WELL. DAILY:S5,482 CUM:$5,482 ETD:S5,482 EFC:$958,000 N/U BOP MW: 9.0 NaCl TAKE ON 9.5 PPG BRINE, MIX 50 BBL HEC PILL. PULLED BPV. PUMPED HEC PILL & 9.5 BRINE, ATTEMPTED TO CIRC W/O SUCCESS. TBG & CSG PRESSURE - 2600 PSI. ATTEMPT TO BLEED DOWN' CSG PRESS WHILE R/U TO BULLHEAD. BULLHEAD DOWN ANNULUS W/ 50 BLLS HEC & 500 BBLS 9.5 BRINE. BULL HEAD DOWN TBG W/ 50 BBLS HEC & 50 BBLS 9.5 BRINE. WELL ON VACUUM. PUMP 150 BBL HEC PILL DOWN TBG. SET BPV. N/D TREE. TEST 9-5/8" PACKOFF TO 5000 PSI, TEST 13-3/8" PACKOFF TO 1500 PSI. N/U BOP, FILLING HOLE WHILE DURING N/U W/ 9.0 PPG BRINE. DAILY:S23,151 CUM:$28,633 ETD:SO EFC:$986,633 L/D TUBING MW: 8.7 NaCl FIN N/U BOP, PUMPED 200 BBL HEC PILL & 280 BBLS 9.0 PPG BRINE, BEGIN FILLING HOLE W/ 8.7 PPG BRINE. TEST BOPS. PUMP 480 BBLS 8.7 BRINE, 150 BBL HEC PILL, 30 BBLS 8.7 BRINE. LOSS RATE DECREASED F/ 2 BPM TO I BPM. P/U ON LDG JT, ATTEMPT TO RELEASE PKR, NO SUCCESS. BACK OUT LDG JT. R/U ATLAS E-LINE. JET CUT TBG @ 8050'. R/D E-LINE. M/U 3-1/2" TBG STRING. DAILY:S163,049 CUM:$191,682 ETD:SO EFC:$1,149,682 WORKING PACKER FREE MW: 8.7 NaC1 FIN L/D COMPLETION STRING. R/D TBG TOOLS, M/U FTA #1. RIH, SLIP & CUT DRILL LINE. WELL STARTED TO FLOW, BULLHEAD 60 BBL HEC PILL & 580 BBLS 8.7 BRINE, OBSERVE WELL, WELL TAKING FLUID @ I BPM. FIN RIH. TAG TBG STUB @ 8053'. LOSING FLUID @ I BPM, SPOT 50 BBL HEC PILL @ PKR, 50% RTNS WHILE CIRC. ENGAGE TBG STUB, PRESSURE DOWN ANNULUS TO 1000 PSI TO RELEASE HOLD DOWN BUTTONS. RELEASE PKR, WORK PKR UP & DOWN TO WEAR RUBBER FREE. DAILY:S42,075 CUM:$233,757 ETD:SO EFC:$1,191,757 POOH MW: 8.7 NaC1 WORK PKR TO LOOSEN RUBBER. PUMP 50 BBL HEC PILL. POOH 5 STDS, LOSING FLUID @ 2 BPM. PTTMP 50 BBL uEC DILL. POOH. RECOVERED 2/3 OF RETRIEVABLE DUAL PKR, TBG STUB & BHP SENSOR, LEFT 5' OF LOWER PKR BODY IN HOLE. RIH W/ OVERSHOT TO CATCH TBG PATCH IN PKR. POOH, NO RECOVERY. RIH W/ OVERSHOT, COULD NOT LATCH FISH. POOH FOR SPEAR. DAILY:S24.752 CLTM=S258:509 RTD~ R~C~$1;9~6.509 I Title I"'l,,,l I I I,~FI (~1 I,,/I IIIII I~ INumber all daily well history forms consecutively aa they are prepared for each well. iPage no. ARCO Oil a,. ,~as Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforaling, show formation name in describing work performed. Number ail drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil siring unlil completion. District Field ARCO ALASKA INC. ICounty or Parish NORTH SLOPE I LISBURNE ILease or Unit L1-21 I Complet ...... d f .... ~Adj~o~e ~'~,~g ..... k .... in prog .... Date and depth as of 8:00 a.m. 07/22/90 ( TD: 0 PB: 9000 SUPV:DCS/MI 07/23/90 ( TD: 0 PB: 9000 SUPV:DCS/~ 07/24/90 ( TD: 0 PB: 9000 SUPV:DCS/M.[ 07/25/90 ( TD: 0 PB: 9000 SUPV:DCS/M~ 07/26/90 ( TD: 0 PB: 9000 SUPV:TDJ 8) State AK Wetl no. 10) The ab~/e is correct ~l~'f~tion" a~d distribution ~e~'"Procedul~s Manual Section 10, 86 and 87 L/D ISOLATION SEAL ASSBLY MW: 8.7 NaC1 FIN POOH, NO RECOVERY. M/U FTA #4 (3.50" OD SPEAR). RIH, TAG TOF @ 8120'. WORK SPEAR INTO PKR, GAINED 15K# DRAG. POOH. L/D BALANCE OF DUAL PKR, XO & 2-7/8" JT ON SHORT STRING, DID NOT RECOVER TBG PATCH IN LONG STRING. M/U FTA #5 (4.25" O/S). RIH. SLIP & CUT DRILL LINE. FIN RIH. TAG TOF @ 8124'. ENGAGE O/S AND JAR FREE ISOLATION SEAL ASSEMBLY F/ MIDDLE ISOLATION PKR. POOH. R/U 3-1/2" TBG TOOLS. L/D 3-1/2" ISOLATION SEAL ASSEMBLY. DAILY:S69,197 CUM:$327,706 ETD:SO EFC:$1,285,706 POOH MW: 8.7 NaC1 FIN L/D FISH, DID NOT RECOVER TOP 30' OF TBG PATCH. L/D 6" BHA. CLEAR RIG FLOOR. HELD FIRE DRILL & SAFETY MTG. M/U FTA #6 & RIH. TAG TOP OF PKR @ 8680' WOK TO ENGAGE TBG PATCH. POOH. L/D TBG PATCH. M/U FTA #7 (MILL & PRT). RIH, TAG PKR @ 8680. ENGAGE PRT, MILL OVER PKR TO 8682.5'. POOH, NO DRAG. DAILY:S67,992 CUM:$395,698 ETD:SO EFC:$1,353,698 MW: 8.7 NaCl FIN POOH W/ MILL & PRT. M/U FTA #8. RIH. HELD H2S DRILL. FIN RIH. ENGAGE SPEAR INTO MIDDLE PKR. JAR ON PKR, PULLED 320K#. POOH W/ MIDDLE PKR ASSBLY. LEFT 48' OF 2-7/8" TBG, "D" NIPPLE & LOWER SEAL ASSBLY IN HOLE. L/D FISH. RIH W/ ROTARY SHOE, (2) JTS OF WASH PIPE & BOOT BASKETS. TAG FILL @ 8765'. ROTATE & WASH FILL DOWN TO LOWER PKR @ 8796' SPOT 50 BBL HEC PILL. POOH. RIH W/ FTA #10 ( 2-7/8" OVERSHOT). DAILY:S30,425 CUM:$426,123 ETD:SO EFC:$1,384,123 RIH W/ 6" BIT MW: 8.7 NaCl SLIP & CUT DRILL LINE. RIH W/ 2-7/8" OVERSHOT. ENGAGE 2-7/8" STUB. POOH & L/D 2-7/8" TBG STUB, "D" NIPPLE & LOWER SEAL ASSBLY. RIH W/ MILL. TAG LOWER PKR @ 8797'. MILL PKR & PUSH TO PBTD @ 9000'. PUMP 58 BBL HEC PILL. POOH. M/U 6" BIT, 7" SCRAPER & 9-5/8" SCRAPER. RIH. DAILY:S34,988 CUM:$461,111 ETD:SO EFC:$1,419,111 RIH W/ GR/JB MW: 8.7 NaC1 RIH W/ BIT & SCAPERS TO 9002' DPM. SPOT 50 BBL HEC PILL. REVERSE CIRC HOLE CLEAN. WELL STARTED FLOWING, SHUT IN WELL, SIDP & SICP - 30' PSI. BULLHEJ%D 30 BBLS DOWN BACK SIDE. ATTEMPT TO BLEED OFF PRESSURE. PUI~ 50 BBL DOWN DP W/ RTN THRU CHOKE. LOST 23 BBLS OF FLUID. MONITOR WELL, NO FLOW. TAG PBTD. POOH, LOST 17 BBLS. L/D BHA. M/U 9-5/8" RTTS & FO FINGERS. RIH & SET RTTS @ 2545' TEST 9-5/8" CASING & FO COLLARS TO 3500 PSI, OK. POOH. RIH W/ 7" RTTS TO 8459'. SET RTTS & TEST 7" LINER & 9-5/8'' CSG Tn 3500 PSI¢ OK. RELEASE PKR. E-LINE. I~fi~rH W/ 6" ~/J~'~CL / HELD SPILL DRILL. POOH. R/U ATLAS FAILED, CHANGE OUT CCL, RIH W/ I~IIIIIII~ AR3B-459-2-B . Number all daily well history forms conseculively as they are prepared for each well. Page no. ARCO Oil ar,,., Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating~ show formation name in describ~nq work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less trequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin9 until completion. District A~C:C; ALA~'KA I-NC. [County or Parish NORTH ST.OPE [state Field l,J.,,.,% 14U["'LN~.. ILease or Unit ]',].--~.]. / Complete record for eae~[a~c~e ~i~i,~g or workover in progress Date and depth as of 8:00 a.m. 07/27/90 ( TD: 0 PB: 9000 SUPV:TDJ 07/28/90 ( TD: 0 PB: 9000 SUPV:TDJ 11) 12) GR/JB. DAILY:S38,985 CUM:$500,096 ETD:S500,096 EFC:$958,000 AK Well no. L/D DRILL PIPE MW: 8.7 NaCl RUN GAMMA RAY / CCL F/ 8995' TO SURF. RUN 6" GAUGE RING / JUNK BASKET TO 8680' M/U 7" FB-1 PKR ASSBLY. RIH W/ PKR ON E-LINE & SET PKR @ 8650'WLM. R/D ATLAS E-LINE. R/U TBG TOOLS. M/U 9-5/8" BAKER PKR AND ISOLATION ASSBLY. RIH W/ PKR ASSBLY ON DRILL PIPE. STING INTO LOWER PKR. SET 9-5/8" PKR @ 8070'. TEST 9-5/8" CSG & PKR TO 3500 PSI. POOH LAYING DOWN DRILL PIPE. DAILY:S54,687 CUM:$554,783 ETD:S454,783 EFC:$1,058,000 LANDING TUBING HANGER MW: 8.7 NaC1 PULL WEAR RING. RUN 4-1/2" SEAL ASEMBLY & COMPLETION ASSEMBLY. ENGAGE SEALS. VERIFIED W/ 500 PSI. SPACED OUT. M/U TBG HGR. DISPLACE WELL W/ 8.5 PPG SEAWATER. REPAIRED TRASH RING ON HGR. FREEZED PROTECTED W/ 150 BBLS DIESEL. LAND TBG HGR. ATTEMPT TO ENERGIZE HGR PACKOFF, COMPRESSION RING DID NOT MOVE. PULL HGR TO FLOOR, REPLACING COMPRESSION RING. DAILY:S240,705 CUM:$795,488 ETD:S695,488 EFC:$1,058,000 Date ITitle I ~,-2.-~(.3 Drilling Supt. Fol~orl~ ~tion and d~[~l~n see Prdcedures_.~tion 10, DrillingS7 AR3B-459-2-B Number all daily well history forms consecutively IPage no. as they are prepared for each well. ARCO O,, and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" oq the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Firlal Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ARCO ALASKA INC. Field LI SBURNE County or Parish NORTH SLOPE Lease or Un ADL: 28302 ITitle WORKOVER IAccounting cost center code State AK Auth. or W.O. no. AL1253 well~n]~'- 21 API: 50-029-20304 Operator A.R.Co. W.I. ARCO 50.0000 Spudded or'W.O, begun Date ACCEPT 07/17/90 Iotal number of wells (active or inactive) on this, ost center prior to plugging and 1 bandonment of this well our 0530 HRS IPrior status if a w.o. I Date and depth as of 8:00 a.m. 07/29/90 ( TD: 0 PB: 9000 SUPV:TDJ Complete record for each day reported NABORS 2ES RIG RELEASED @ 18:00 HRS MW: 8.7 NaC1 RELAND TBG, RILDS. TEST TBG TO 3500 PSI FOR 30 MIN. TEST 9-5/8" ANNULUS TO 3500 PSI FOR 30 MIN. L/D LDG JT. SET BPV. ND BOP, NU TREE. TEST PACKOFF TO 5000 PSI. PULL BPV, SET TEST PLUG. TEST TREE TO 5000 PSI. PULL TEST PLUG. PRESSURE TBG TO 3000 PSI & ANNULUS TO 1500 PSI. PRESSURE TBG TO 5000 PSI & SHEARED THE SHEAR OUT SUB. BLED ANNULUS TO 0 PSI & TBG TO 350 PSI. SET BPV W/ LUBRICATOR. R/D LUBRICATOR. SECURED WELL. RELEASE RIG @ 18:00 HRS 7/28/90. OTIS 'HRQ' SSSV @ 2232', BAKER "DB" PKR @ 8097', BAKER "FB-I" PKR @ 8675', TUBING TAIL @ 8697' DAILY:S16,962 CUM:$812,450 ETD:S712,450 EFC:$1,058,000 Old TD New TD PB Depth Released rig Date IK nd of rig I Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data !Welt no. Date Reservoir Producing Inten/at Oil or gasTest time Production Oil on test Gas per day I p Pump size, SPM X length Choke size T.P. lC.. Water % GOR Gravity Allowable Effective date corrected The ~;~e is correct Date ITitle ~.~ -~"F./~r, m.~.,_ I~--z~,) Drilling Supt. n and distribution, ual, Section 10, nd 87. AR3B-459~3-C INumber all daily well history forms consecutively as they are prepared for each well. iPage no. Dlvllton of AllantlcRIchfleldCompeny ~--;' LGI-04 DUAL BURSTTDT RUN1 7/26/90 ~u ..L1-21 PRODUCTION PACKER RUN 1 7/26/90 ~- L5-19 PIPE RECOVERY RECORD RUN I 7/5/90 ,~--,~. L3-12 PRODUCTION PROFILE RUN I 7/9/90 ...L4-10 LEAK DETECTION RUN 1 5/10/90 .,'E'i-27 PRODUCTION PROFILE RUN 1 5/5/90 SCHLUMBERGER ATLAS SCHLUMBERGER CAMCO CAMCO CAMCO SIGN AND RETURN TO: JOHN BARBO ARCO ALASKA, INC. /! /700 G STREET; ATO 409 ' /{~/ ?'!ANI~i-i,ORAGE, ALASKA · 99510 BP '~~~)N ~~ TRANSMITTAL # 634 ~ ~ TO: THRU: Lonnie C. Smi~~ Commissioner .. MEMORAhDUM Slate of Alaska ALASKA OIL A~ND GAS CONSERVATION CO~-~4ISSION DATE: July 30, 1990 JT.BF. 730.10 FILE NO: TELEPHONE NO: SUBJECT: RiG/BOPE Inspection Lisburne Oil Pool FROM: Petroleum InspeCtOr ~' Thursday July 26, 1990: I made a walk thru BOPE inspection on Nabors rzg ~~the BO~E installed properly and appeared to be good working order. checked the IADC report and found that the last test had been ~ ~ o er~ormes on 7/22/90 and was logged 02-00lA (Rev. 6/89) 20/ll/MEMO1.PM3 TO: THRU: FROM: MEMORAhOUM State of Alaska ALASKA OIL AND GAS CONSERVATION CO,XR~ISSION Lonnie C. Smi~j~'~ DATE: July 30, 1990 Commissioner ~ '~ ~ FILE NO: JT. BF. 7 3 0.9 TELEPHONE NO: SUBJECT: RIG/BOPE Inspection AAI PBU Lt-=~I Lisburne Oil Pool Bobby D. Foster l~<i~ 'l- Petroleum inspedf0r hurs_d~y July~26_~: I made a walk thru BOPE inspection on ~,7abors {~6rti-dve~~~--2~g -ahd found all. the equipment installed properly and appeared to be in good working order. ! checked the IADC report and the last BOPE test had been logged in properly on 7/17/90. 02-00lA (Rev. 6/89) 20/ll/MEMO1.PM3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY 1. Type of Request: Abandon __ Suspend __ Alter Casing __ Repair well __ Plug~g __ Change approved program __ Puli tubing __ Variance __ 2. Name of Operator I 5. Type of Well: Development ARCO Al aska, I nc. ! Exploratory __ 3. Address Stratigraphic_ P,O. Box 100360 Anchorage, AK 99510-0360 Service__ 4. Location of well at sudace 2500' FNL, 2500' FWL, Sec. 1, T11N, R14E, UM At top of productive interval 2500' FNL, 2500' FWL, Sec. 1, T11N, R14E, UN At effective depth 2500' FNL, 2500' FWL, Sec. 1, T11N, R14E, UN At total depth 2500' FNL, 2500' FWL, Sec. 1, T11N, R14E, UM Operation shutdown __ Re-enter suspended well __ Time extension __ Stimulate __ Perforate __ Other __ ,, 6. Datum elevation (DF or KB) RKB 54.5 ' feet 7. Unit or Property name Prudhoe Bay Unit/Lisburne 8. Well number I 1-21 9. Permit number 78-30 10. APl number 51~29- 20304 11. Field/Pool Lisburne 0il Pool 12. Present well condition summary Total depth: measured feet true vertical 10383 'MD feet 10383 ' TVB Effective depth: measured 9000 'MO feet true vertical 9000'TVD feet Plugs (measured) None Junk (measured) None Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 80' 20" 175 sx AS II 76'MD 76'TVD Surface 2738' 13-3/8" 4300 sx PF II 2738'MD 2738'TVD Intermediate 8523' 9-5/8" 1000 sx C] ass G 8523'MD 8523 'TVD Production 2180 ' 7" 450 sx C] ass G 8203'MD 8203 ' TVD Liner 10383 'MD 10383 'TVD Perforation depth: measured 8890'-8902', 8834'-8856', 8810'-8822', 8697'-8745', 8560'-8639' true vertical 8890'-8902' 8834'-8856', 8810'-8822', 8697'-8745' 8560'-8639' Tubing (size, grade, and measured depth) ' 3-1/2" set, Packers and SSSV (type and measured depth) 13. Attachments Pkrs ¢ 8790' 8674', ~109' /.'~i~8~{~ Description summary of proposal ~ Detailed operations program ,.~ BOP sketch 14. Estimated date for commencing operation March 1990 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ~ Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~/,.~ Z~ ,~,,.._~ Title Regional Dri l'li ng Engi neet ¢"// ~/' FOR COMMISSION USE ONLY Condition.~f approval: NotiCCCommission so representative may witness Plug integrity __ BOP Test __ Location clearance Mechanical Integrity Test __ Subsequent form required 1-67- Approved by order of the Commission Form 10-403 Rev 06/15/88 Original Signed By David W. Johnston 133/5A4 Approved O.oP¥ Returned - ~'' Commissioner Date SUBMIT IN TRIPLICATE WORKOVER PROCEDURE MSBURNE L1-21 Objective: Pull leaking 3-1/2" tubing and upper retrievable packer, mill and recover two, 7" permanent packers, and dean the well out to PBTD. A 4-1/2" single selective completion will then be installed including a 7" and a 9-5/8" permanent packer. Packer fluid will be inhibited brine with a 2000' gelled diesel cap. . RU slickline. RIH and pull dummy valve from Camco gas lift mandrel at 7848' MD. POOH, RD slickline. 2. MIRU workover rig. Circulate 9.5- 10.0 ppg NaCI brine down 3-1/2" tubing taking returns out annulus to kill well. Set BPV. 4. ND 3-1/2" FMC Gen l tree. NU13-5/8" 5M BOP stack and test. PulIBPV. . e . . . 10. 11. 12. Engage tubing hanger. PU on 3-1/2" tubing to release Baker AL-5 dual, retrievable packer. PU +_20' to pull seal assembly out of middle packer. Circulate bottoms up. POOH, LD 3-1/2" Hydril CS-CB tubing, packer, and seal assembly. MU 6" packer mill and RIH to Baker 7" FB-1 permanent packer at 8674' MD. Mill over and retdeve packer and tailpipe, including 13' lower seal assembly. MU 6" packer mill and RIH to Baker 7" F-1 permanent packer at 8790' MD. Mill over packer and retrieve packer, if possible. Otherwise, push packer to bottom. POOH. MU 9-5/8" RTTS and RIH to top of 7" liner at 8200' MD. Set RTTS and pressure test 9-5/8" casing to ~0 psi for 30 min. POOH, LD RTTS. RU electric line. RIH w/6" gauge ring/junk basket to 8690' MD. POOH. MU 7" permanent packer with 3-1/2" tailpipe and RIH. Set packer at 8650' MD with end of tailpipe at 8680' MD. POOH, RD electric line. MU 9-5/8" permanent packer with 3-1/2" straddle assembly and RIH on 3-1/2" DP. Sting seal assembly into lower 7" packer and set upper packer at +8100' MD. Test packer to 35(X) psi. Displace well with inhibited seawater. POOH, LD DP. MU seal assembly on 4-1/2" ABMod BTC IPC tubing and RIH. MU gas lift mandrels and wireline retrievable SSSV as directed. Sting seal assembly into packer and space out. Pressure test tubing and annulus to 3500 psi briefly. MU FMC 5-1/2" Gen I Retrofit tubing hanger with XO to 4-1/2" MOD BTC and land same in tubinghead. Pressure test tubing and casing to 3500 psi. Set BPV. 13. 14. 15. ND BOP's. NU FMC Gen I tubinghead adapter and 5-1/2" 5M tree. Pull BPV, install tree test plug. Test tree to 5000 psi. Retrieve test plug. Displace 9-5/8" x 4-1/2" annulus and 4-1/2" tubing with diesel through circulating valve in top GLM station. Follow diesel with gelled diesel to fill top 2000' of 9-5/8" x 4-1/2" annulus. Close annulus valve. Set BPV. Release rig. o BHP = 4200 psi @ 8900' TVD (9.07 ppg) Workover Fluid = 9.2 ppg NaCI STATE OF ALASKA ' ~-~ OIL AND GAS CONSERVATION Ct_ tlSSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Alter Casing [] Other Operation shutdown [] Stimulate [] Plugging [] 2. Name of Operator ARCO Alaska~ Inc. 3. Address P.0. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2500' FNL, 2500' FWL, Sec. 1, T11N, R14E, UN At top of productive interval 2500' FNL, 2500' FWL, Sec. 1, T11N, R14E, UM At effective depth 2500' FNL, 2500' FWL, Sec. 1, TllN, R14E, UH At total depth 2500' FNL~ 2500' FWL~ Sec. 1~ TllN~ R14E~ UN 11. Present well condition summary Total depth: measured true vertical WELL NAME CHANGE Perforate [] Pull tubing 5. Datum elevation (DF or KB) RKD $4.s' 6. Unit or Property name Prudhoe Bay Unit/Lisburne feet Plugs (measured) feet 7. Well number L1-21 8. Approval number ?R 9. APl number 50-- 029-207,04 10. Pool Lisburne 0il Pool Effective depth: measured true vertical feet Junk (measured) feet Casing Length Size Cemented Measured depth ARCO Alaska, Inc. has changed the well number designation from "West Bay State #1" to "L1-21". Feet Perforation depth: measured true vertical Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) !-., ,...~,-,.~ A[as[:a Oil & Gas Cons. Anchorage 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure True Vertical depth 14. Attachments None Daily Report of Well Operations [] Copies of Logs and Surveys Run ~ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Tubing Pressure Signed ~,,o(~ .t/t~,~,~L~.L/t..~ Title Associate Engineer Date i0--~-~-~'7 Form 10-404 Rev. 12-1-85 ~ (JG) 5W02/98 Submit in Duplicate 10-7-87 DATE: FROM: PAM LAMBERT ENCLOSED IS THE FOLLOWING DATA FOR LISBURNE: CH Finals for Lisburne L1-21 Collar Log 8-23-87 Run 1 5" DA~M~ L3-12 Collar Log 8-28-87 Run 1 5" DA~y~ CENTRAL FILES PLANO D&M EXXON STANDARD STATE OF ALASKA TRANSMITTIAL # 316 STATE OF ALASKA ALASKA .,IL AND GAS CONSERVATION COMMI; ~,ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Requests: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing ~,, Amend order [] Perforate ~ Other 2. Name of Operator ARCO Alaska, Inc 3. Address P. 0. Box 100360 Anchoraqe~ AK 99510 4. Location of well at surface 2500'FNL, 2500'FWL, Sec.1, T11N, R14E, UM At top of productive interval 2500'FNL, 2500'FWL, Sec.1, T11N,.R14E, UM At effective depth 2500'FNL, 2500'FWL, Sec.1, T11N, R14E, UM At total depth 2500'FNL, 2500'FWL, 5ec.1, T11N, R14E, UN 5. Datum elevation (DF or KB) 54.5' RKB feet 6. Unit or Property name Prudhoe. Bay llnif 7. Well number 8. Permit number 78-30 9. APl number 50-- 029-20304 10. Pool W{ldcat 11. Present well condition summary Total depth: measured true vertical I 0)383 ' M D feet 10,383'TVD feet Effective depth: measured 9000'ND true vertical 9000'TVD Casing Length Size Conductor 80 ' 20" Surface 2738 ' 1 3-3/8" Producti on 8523 ' 9-5/8" Liner 21 80 ' 7" feet feet Plugs (measured) None Junk (measured) None Cemented Measured depth 175 sx AS I I 76 'MD 4300 sx PF II 2738'HD 1000 sx Class G 8523 'MD 450 sx 8203'MD- 10383 'MD True Vertical depth 76 ' TVD 2738 ' TVD 8523 'TVD 8203 'TVD- 1 0383 'TVD Perforation depth: measured See attached sheet true vertical See attached sheet Tubing (size, grade and measured depth) 3-1/2" set (~ 8790' Packers and SSSV(type and measured depth) Pkrs ~ 8790', 8674' RECEIVED APR 2 :-: i98fi Alaska 0il & Gas Cons. Commission 81 09 ' Anchorage 12.Attachments Description summary of proposal X~ Detailed operations program ~ BOP sketch [] 13. Estimated date for commencing operation As soon as possible 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~}'~ ~}J.L~Y./~ Title Associate Engineer Commission Use Only (JG) SA/01 6 Conditions of approval Approved by Date Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI . ~ .,~:~' ~ .,~ · ,~:~ ;-' :'~:,'- ' ...... ' : ................... by order of : ~':~ :"~ Commissioner the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate perforation Interval s MD 8890' - 8902' 8834' - 8856' 8810' - 8822' 8697' - 8745' 8560' - 8639' TVD 8890' - 8902' 8834' - 8856' 8810' - 8822' 8697' - 8745' 8560' - 8639' RECEIVED SA/01 6a: tw 04/22/86 ARCO Alaska, Inc., proposes to change the well number designation from "West Bay State #1" to "L1-21". SA/0OSa:tw LISBURNE ENGINEERING Date: 11-17-86 From: Para Lambert Enclosed are the following: Pressure Reports L1-21 9-17-86 Static Gradient Camco LGI 10 10-25-86 Flowing Gradient Otis L2-33 Production Profile 11-5-86 Run 1 Camco Field Print Received by: Please sign and return to~PamLambert ARCO AK INC. 700 G Street ATO 477 Anchorage, AK. 99510 D&M EXXON STANDARD CENTRAL FILES TRANSMITTAL # 102 ALASKA.¢~-'-.; AND GAS CONSERVATION CO~4MISSION ',SUNDRY IL JTICES AND'REPORT'.. JN WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box'10'0360 Anchoraqe, Ak. 99510 4. Location~ Well Surface Loc. 2500' FNL,2500' FWL,Sec:i,T-11N,R-14E Bottomhole Loc. Same as surface 5. Elevation in feet (indicate KB, DF, etc.) I 8 . Lease Designation and Serial No. ADL 2~302 7. Permit No. 78-30 8. APl Number 50- (3 2 c)_ 2(3 ~C)zt 9. Unit or Lease Name PP_~ Unit/Lisburne 10. Well Number . -~---- ' ~'/1 11. Field an-d-I~ool- PRB Field/Lisburne Lisburne 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 [] 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). Change name of subject well from West Bay State No. 1 to L1-21. This change is needed to allow the Lisburne delineation wells to be incorporated into the well nomenclature that is planned as part of the Lisburne full field development. 14. I hereby certif, y that the foregoing is true and correct to the best of my knowledge. Conditions °'fJApprovat, if any: · ~pprov~-j~ to.~¥ ~eturnCd By Order of Approved by COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" ~n Triplicate and "Subsequent Reports" in Duplicate ARCO AI.a.~ska F',O, Box Anchorage, A i. a.s'k a 995t(') DATE: March RLEFERENCE: 4~ t 985 ARCO Pre.s'.'~ure Da'fa CDBR C D B R Pres'sure Bui Ld--up Homer F'l.o±.'.~ w/L i :s't ing F:lowir, g Pressure & Gradient F're.s:sure FaLL Off 2 .... i 3-85 5,tat i c 5,ul"vey G 0 ,~(: h S' ur v e y_~ GO [; 0 DA F"l:ease :irign and return the attached copy as receip'f of da'fa, Receivecl ]By ........................... ' HAVE A NICE DAY! . Ke L I.y Mcl::'ar Land ATO- t 4"29F ' ~r, ch0r~g~ D I S' T R I B lJ T I 0 N Chevron Mobil. E & P D & M PhiLLips ExpI. ora'tion ,::Tervice.s Prudhoe Bay WeLL E'xt'en~ion E'xpLoration R & ~ E x x on $oh i o Marathon State of ALaska Mob i L Texaco FiLes ARca Alaska, Inc. Post Office Bo~60 Anchorage. Alaska 99510 Telephone 907 277 5637 ~ <~~ ~~ March 16, 1983 Mr.C. V. Chatterton ii:;~aO~i~l:~~aGas ØJtIiÐ},\A'l101.9Ð7 . . Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: ...of~. Well Test Report West Bay State No. 1 II-I -<9( Dear Mr. Chatterton: Attached is a description of the 9-month production test of West Bay State No. 1 in the Prudhoe Bay Unit - Lisburne Reservoir. The data gathered in 1982 has added to our understanding of this complex carbonate reservoir; however, further evaluation and testing of the Lisburne will be required before-a-decision can bema-ð@ as to--thecomme.rcialit;YQf field development. Since this test was conducted and financed solely by ARca Alaska, Inc. and Exxon Company, USA, we ask that the contents be held confidential. If you have any questions about the West Bay test or the contents of this report, please contact me at 265-6193 or D. K. Chancey at 265-6330. Thank you for your continued assistance and interest in the Lisburne evaluation program. Very truly yours, I1JI? I:~~.t. ,,~) ".',{,~ \..' \ ~~ . R. Knepler Regional Engineer New Projects JRK:DKC:ml RECEIVED 1V1AR 17'-, 1983 Alaska Oil & Gas C 011$. Com . Anchorage !rllssian Attachment ARCO Alaska. Inc. is a lubsidll'Y of AllanticRlchfieldCompany J1-1r-030 February 16, I983 ARCO Alaska, Inc. P.O. Box 360 Anchor age, Alaska ..,9 9510 Subsequent Reports, Sundry Notices and Reports on Wells (Form 10-403) Attn: Pete Van Dusen .. District Dril ling Engineer For the following lists of "Notice of Intention To:" Sundry Notices and Reports on Wells (form 10-403) this office does not have on record the "Subsequent Report of~" defining the action taken on the approved intention. Please advise this office by Subsequent Report of the disposition of the intention. DS 14-18 2/11/ W. Sak River State B5 619/ .DS 12-~A :10123/81 DS 12-7 - 11/23/ DS 13-3 11/2/81 DS 12-4 12/15/~1 BP 24-10-14 DS 13-2 West Bay State 1 BP 31-10-16 DS 15-3 Oliktok Pt. 1 DS 15-3 DS 5-11 DS I6-13 N. Prudhoe Bay St. 2 Euparuk 1E-12 12/15/81 2/2/82 2/2a/~2 3/17/82 3/23./s2 3/23/82 4/2/82 4/5/s2 6/2/82 6/2/82 _Brie_f_._Desc_riPt_ign..of. Int_ent io_n Change course of this well, Workover Abandon lower borehole prior to sidetrack Abandon lower borehole prior .to sidetrack Pull and replace tubing Abandon lower borehole prior to sidetrack Plug and abandon Pull and replace tubing Test Lisburne formation Plug and abandon Change setting depth 9 5/~" casing Deepen ~% hole to basement Change setting depth 9 5/~" casing Pull tubing and repair casing Sidetrack Abandonment proc edure C~ange grade L-~0 portion of 7" casing ALASKA OIL AND GAS CONSERVATION COMMISSION Date: ~//~/~,"--,,,%, To: ! Transmitted via 3001 PORCU,elNE DR/VE.ANCHORAGE, ALASKA 99501 are the following: Quantity Description of Item RECEIVED SEP 2 ? 1982 Alaska 0tl & Gas Cons. Commission Anchorage Please acknowledge receipt by si/~ning and returning one copy of this letter. Signed:. ~.?;::~:~~i...'. Yours very truly, Dated: ALASKA OIL & GAS CONSERVATION COHHTSSION ALASKA OIL AND GAS CONS£RVATiOtt COMMISSION Date:, ~//(~ / To: Transmitted via .lAY S. N~I4¥ONO, GOVERNOR 3001 PORCUPINE DRI VE.ANCHORA GE, ALASKA .q9501 are the following: Quantity Description of Item Please acknoWledge receipt by signing and returning one copy of this letter. .Sicjned: oated~ Yours very truly, ALASKA OIL & GAS CONSERVATION COMMISSION ARCO Alaska, Inc. Post Office F 360 Anchorage, ,~,. _;ka 99510 Telephone 907 277 5637 September 7, 1982 Re f er enc e: Arco Cased Hole Final On August 26, 1982-a Diff Temp Log was sent out to you on West Bay St. #1. It was dated 7-31-82 and was a Dresser Atlas log, run 1 5". This log was not supposed to be sent out as it is a tight hole well. If you would please return t.his log to me I would appreciate it. If you have any questions, please call me at 907-263-4232. Kelly McFarland AFA-403 Trans. # 447 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M GEOLOGY STATE OF ALASKA DALLAS ALASKA OIL AND GAS CONSERVATION COMMISSION Date:, ~//~/ Transmitted via Re: / I ! 14~' & H4MWO#O, F, OVERNOR 300I PORCUPINE DRIVE.ANCHORAGE, ALASKA 99501 are the following: Quantity Description of Item Please acknowledge receipt by signing and returning one copy of this letter. Signed: ~3ted. Yours very truly, ALASKA OIL & CAS COA'$S,KUA/ION CC.:.:MISSIO~ ARCO Alaska, Inc. Post Office B :60 Anchorage. A~..=,~(a 99510 Telephone 907 277 5637 August 26, 1982 Reference: Arco Cased Hole Finals D.S. 12-9 7-30-82 D.S. 13-33 8-3-82 D.S. West Bay St. #1 Fluid Density ACBL/VDL/Signature/GR 7-31-82 Diff Temp Log Run 1 5" DA Run 1 5" DA Run 1 5" DA / Please sign and regurn the agtached copy as receipt of data. Kelly McFariand Trans, 420 D I STRI BUT ION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY GEOLOGY STATE OF ALASKA DALLAS August 12, 1982 Mr. Minos Hebert ARCO Alaska, Inc. A~O Room 321 P. O. Box 360 Anchorage, Alaska 99510 Dear Mr. Hebert In reference to our conversation this date regarding clean-up and. inspection of ARCO well sites on the Arctic Slope, I am enclosing a copy of our letter of May 21, 1982 to Mark Major regarding clean- up. In addition to the wells on this list add: West Sak #13 Oliktok Pt #1 West Sak 923 West Sak #24 West Sak %25 Etleen #1 . North Prudhoe Bay St #2 Gull Is. St. #1 Gu!l_Is~St. W. Mikkelsen Unit #2 Some of the wells on the lists are for repeat clean-up inspec- tions while others are being inspected for the first time. Wells in a suspended status require a yearly clean-up inspection. When the clean-up inspectign is approved as satisfactory for abandoned wells no furthers, inspection is required. ARCO Alaska, Inc. North Stope [>, .:itt Post Office 8o× 360 A~'~chorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rocho~ D~trJct OperetJon~ E~g~eer April 30, 1982 Mr. Harry W. Kugler 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: RE: West Bay State No. 1 Lisburne Test ! STAT t~ STAT IFC" ....... ~ Fit F: This letter is to update you on the status of the Lisburne Test at West Bay State No. 1. The test was started on March 1, 1982. Production for the month of March was intermittent with frequent shutdowns caused by unanticipated pro- blems in the ~uninsulated portion of the flow line. Lab analysis concluded that low temperature effects on the combination of Lisburne oil and NGLs were causing the problems. Based on this information, tanks and associated piping were installed at the well site to allow trucking of the crude oil and flaring the gas. The test was re-started under this mode of operation on April 19, 1982. The well is producing approximately 1100 STBPD and 1.0 MMSCFPD. Use of the flow line for gas production to minimize flaring is being evaluated. The possibility of using the flow line for oil and gas production during warmer weather is also being evaluated. If you have any questions or need any further information please contact Jeff Robinson at 263-4237. Very truly yours .,:..-/c. .~:"J. A. Rochon JAR: JBR' adri ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany MAY 0 AL~sk~ Oil & Gas Cons. Commission Anchorage ALASKA OIL ANi'? CAS CONSEPVA?JIONC...O?,.~n~,:,!O'r,;' ~" ~'''-' r, / Commi s s ioner ~uss Douglas /y i<arch 2, 1.~82 t,~est Bay State ~').o~;' Test (Cc, nfzoc~,~.iai Petroleum Engineer On Pebruar3- 26, 1982 I received a call :fxo,:~ Lo,~nie and i.,.e requ. cstcd T take a look at AR:CO's setup on the ~? ~ ~.~al, c oil. This well is being prepared for a long fo r~at io n. I contacted Dotty t~avard., ..... S . ARCO the Nest ~ay ~..tate #1 location for L!~e test. ~tle flare pit was bein9 constructed around it before testing l:egins. separator is being hooked up for the test. The well was perforated and tested in late APCO now wishes to evaluate the limestcP seconda~, porosity with a long term test. of interest two oil and one gas. The about 3,000 bb! ~r day of oil each in thc acidized with 28% tlCl. in the 1978 tcst 2~N~CP after acidizin~. The lower oil interval test will he foz~ t~,}o r,?ont!u.? if i'~ wii2 flow that long. The upper interval will then be tested ior ak,u. ut four months again pending on whether or not the well will production that. long. The gas zone v~i].l 't~:!en be. tested for perio~ l'~ased on results of thc lonq tern oil flow tests. ~he well is ec~]ir~r:ed wth :~z.,, tubJ. ncr n~'ou 5/~ cas~.ng ~q2':'~ A 7" liner is set to I0,383'~-:r~ - ' IL,.u_,c,c~ ha.d~ to 9000'~'1~. E'he well is a straight bo].e therefore I'L and TVL arc t)?e zame. The we] .... ~"" ~::lc-:w linc Luring wizeline valves one oD t~}e tree add one on ,_.r,,c} ,_ . work the tree valve wil ~ c,~.f to a.void ac:cic/cntal closing. The 'wing valve wi.!3 13e fui.!y c:,pcrational. The subsurface safety valve zor the ,.,o,~t ?a ....... wi ! reiT!ai2 out c:.f thc: hole duz'ing the test.. The well will be flowed to the test seNarator w]':~ere the oil, gas and water wi].l.:,'~,c separated at aNtTrcxinatelv ..... i000 psi anq 140°F. The respective streams wilt ~'-,~- ,~;teterc-d t'}~en recombined downstream Prom the drill site the flow will gc through a 4" line which, will tie in on the downstream side of the field fuel gas unit. From I~onnie C. Smith 2 rch 3, 1982 there it ties into the drill site two manifold which then goes to flow station ~! for final separation. Flaring of the gal will not occur except for start up of the tests or for a syst~ upset. Testing is expected to begin by Sunday F~rua~y 28, 1982. February 10, 1982 [Jr. J. A, F:oehon District Engineer AROO("Alaska, Inc. P. 0.' Box 360 Anchorage, Alaska 99510 Deaf'Mr. Rochon: We~have'received your letter of February 1, l~$2 request inff that the Commission review the limi~ations placed on the flaring of gas for tho ~est of ihs Ltsb~rne Oil Pool in the West Sta~e No. I ~ell that ~ere set ou~ ~n our letter, dated ~.~a~ch 1~, 1981, The ~mmtsston has reviewed tho conditions of approval of March 18, 1951 ~nd baa considered your request of February 1, 1982;.with re~ard to the same well, The Con~ission finds tt tn the best interest of the Stot~ and a beneficial use of ffas to for~o its physical conservation during the testin~ of subject well in orde~ to evaluate the production charactertstie~ of this questionable resource. Tho fla~in~ of ~as produced with th~ oil from the West Bay State Es. 1 well durin~ a six n~onth te~t of the I, isburne Oil Pool is l~ereby approved with the followln~ conditions: 1, Tl~e approval for the flart~ of ~as as stated in the C~ission's letter of ~,Mrch 1~, 19~1 is hereby rescinded. 2. The flarin~ of Isa ts pe~ittcd w}ten the ff~s produced cannot be ~aved due to' the eon~n line pressure restrictions. 3. A total volume not to exceed l~0 ~,fCF may be flared, necessary, durin~ the six ~nth test int~ period. 4. If the oil test t~ not conclusive n. fter six months duration or tf further teatin~ will ndd additional beneficial tnfo~tion, the Con',miasion will consider furthe~ requests. '~'$. ~onthly production forroa (Fern 10-405 and For~.n 10-422) must be tinmly submitted and these production data ~'ill be released to the public. 6. ~ A m~n~hly recap of the daily ~rod~ctton rates and the volumes of gas flared will ~~mely submitted. ~. ltithin 9~ days after thc completion of the tenting operations, a report on the project will be ~ubmttted. The report should include all pressure data, choke :..~?. produced volumes and all other pertinent data. ts~to.n again wishes to congratulate ARCO Alaska, Inc. for-making the time, equipment and ~ney available for the teating-~of this reservoir. We wish you success in your ~nd~hope that, aa a result of this work, we all ~ill better understand the 5isburne reservoir. Yours ve~' truly }larry ¥t. Kuffler'~ C~mi ~s toner ARCO Alaska, Inc. North Slope Post Office 8o× :360 Anchorage, A~aska 99510 Telephone 907 27-7 5637 Jerry A. Rochor~ District Operations Engir~eer February 1, 1982 Mr. Harry Kugler State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 West Bay State No. 1 Lisburne Test Dear Sir: ARCO Alaska, Inc. requests that you review your previous limitations for flaring during the Lisburne Test at West Bay State No. 1. Our new well-site facility design eliminates flaring on a continuous basis as long as the well can produce into common line pressure. Our studies indicate that unless the reservoir is quite limited, it should produce into the system for the entire test. Initial flaring would consist of start-up and shutdown volumes. If the well cannot produce into the common line, a pump will be used to boost oil pressure. At that time, we would like to flare the gas. For a six month test, your previous limitations would have allowed approxi- mately 180 MMCF total flare gas. As total limit, the test is not expected to exceed that figure and is very likely to be well below it. However, the test may exceed the 1MMCFD average for portions of the test. We request that the approval be amended to allow a total flaring figure for the test of 180 MMCF for the expected six months of oil production. We also request the option to extend the test on a monthly basis at 30 MMCF, if additional data is required. Please acknowledge receipt of this letter by returning one signed copy of this letter for our files. Thank you for your attention in this matter. Very truly your~s, ~.~ .; /.c z? ...... /.J~': A. ~ochon JAR: EJH: adr i Attachments Title RECEIVED FEB 0 5 ]982 Aj~l~Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. North $iope` L, .... rict Post Office [~o× ;380 Anchorage., A~aska ~95'i0 'Tetephooe 907 277 5637 Je~?y A~ ~ochor~ District Operations ~ngineer ~ebruary l, 1982 ~r. Harry Kugler State of Alaska Department of ~atural Resources D~v~s~on of Oil and Gas 3001 Porcupine Dr~ve Anchorage, Alaska 99501 RE: West Bay State No. 1 Lisburne Test Dear Sir: ARCO Alaska, Inc. submits this Sundry Notice and takes this op- portunity to reiterate plans to test the Lisburne reservoir in the West Bay State No. 1 Well. The test is currently forecast to start-up in April, 1982. Although delayed, the intent of the test is unchanged. Of particular importance is the wireline data to be collected. The subsurface safety valve (SSSV) will be removed as is customary for wireline work. The valve is usually replaced on completion of the wireline work. Since there will rarely be more than five days between surveys, the SSSV will not be rerun. This will reduce the disruptions in the pressure transients. To pull and rerun the SSSV, the well must be shut-in. If the well is shut-in every few days, the disruption may render the data unuseable. Analysis of the pressure transients from bottom-hole pressure data is the key to determining the future of oil production from this reservoir. If the SSSV was pulled and rerun each time a wireline tool was run, important data would be lost by shutting in the well. We realize that removal of the valve for months at a time is not customary, but, in this case, it is very important. The Constant supervision of the facility reduces the danger of damage to the wellhead. This test is manned full-time by operators. Most of the time, the operator will be accompanied by a wireline supervisor and an engineer. Please acknowledge receipt of the attached report by returning one signed copy of this letter for our files. Thank you for your attention in this matter. Attachments Title ARCO Alaska, t.c, is a subsidiary of AtlanticRichfietdCor~pa.qy RECEIVED Da te FEB 0 5 1982 Alaska Oil & Gas Cons. Commisslo. Anchorage '" STATE OF ALASKA ALASKA L,.L AND GAS CONSERVATION CO.,..MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE L L:~× OTHER 2. Name of Operator Atlantic Richfield Company 3. Address P. O. Box 360, Anchorage, Alaska 99510 4. Location of Well Alaska 0il & Gas Cons 2500' FNL, 2500' FWL, Sec. 1, TllN, R14E, UM AnChora~COrnmiss 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. AUT, 28302 7. Permit No. 78--30 8. APl Number 50- 029-20304 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number ~ West Bay State No. 11. Field and Pool ?rudhoe Bay Field Lisburne Oil Pool 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other :~ Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (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 plans to test the Lisburne formation to determine the ability of the well to sustain an economic oil rate. Surface and bottom-hole pressure data will be collected for analysis of the reservoir. The test will help determine the areal extent of the porosity development and the fracture system. The test is designed to last about 7 months. To measure the bottom-hole pressure regularly, the SSSV will be removed for the entire test. This will permit bottom-hole pressure measurement as necessary during the flowing period. By collecting the drawdown data over several months, a more accurate assessment of the reservoir's capabilities can be made. The drawdown data at this time should be much more informative than the build-up data. The West Bay State No. 1 Well will be under constant supervision. The location will be manned with an operator; most of the time' two operators will be present. The location will be subject to limited vehicle access during test operation thereby reducing the chance of wellhead damage. The wellhead is equipped with a hydraulically actuated master valve which serves as the main surface safety valve. There will also be automatic safety devices throughout the test facility. We request that all information on this test be considered confidential. 14. I hereby ce/~fy that the fo,9~regoing~s~rue and correct to the best of my knowledge. Signed ~ Title ~'/~5' ~- ~/~-/'~" -~ 2-- - :x ' The space ¢/w for Commission use / Conditions 'of Approval, if any: Approved by Approved Copy Subsequent Work p~eported Returned No. Patext ---/---/-- ORIGINAl.' $ I~ E~¢~ ------- ByOrder of 8y t~NHIE c, SMIT~ COMMISSIONER the Commission Date ................. Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate / ALASKA OIL AND GAS CONSERVATION COMMISSION / 300I PORCUPINE DR/VE.ANCHOR?4GE, ALASKA 99501 March 18, 1981 Mr. J. J. Pawelek ARCO Oil and Gas Company P. O. Box 360 Anchorage, Alaska 99510 Re: Production Test - West Bay State ~1. Dear Mr. Pawelek: We received your letter, dated February 16, 1981, on March 16, 1981 concerning the request for the flaring of gas during the extended production test of the Lisburne Reservoir in the West Bay State #1 well. The flaring of gas produced with the oil from the testing of the West Bay State #1 well is hereby approved as follows: 1. Flaring of gas is permitted during the start-ups and shut-downs which have been estimated to be 35 MCF per event. 2. Flaring of gas is permitted, when necessary, during the production tests but is limited to 31 MMCF for 31 day calender months and 30 MMCF for 30 day calender months. It is understood that equipment will be maintained to save and rein- ject all of the gas that is possible, estimated to be about 85% of all produced gas. 3. Monthly production forms (Form 10-405 and Form 10-422) must be timely submitted and this production data will be released to the public. 4. A monthly recap of the daily production rates and flared volumes will be timely submitted. 5. Within 90 days after the completion of the testing operations, a report on the project will be submitted. This should include all pressure data, choke sizes, produced volumes and all other pertinent data. FEB 0 5 WAR Oil, & Gas Cons. Commissior~ ~rEC, PR O~ECl'S Mr. J. J. Pawele~ .... -2- Production Test - ~est Bay State #1 March 18, 1981 The Commission wishes to congratulate you and your company for making the time, man-hours and monetary expenditures that will be necessary to test this reservoir. We wish you success in your efforts and hope that, as a result of this work, the Lis- burne Reservoir will be a drilling target in the near future. Yours very truly, Harry W. Commi ssione r RECEIVED FEB 0 5 Alaska Oil & Gas Cons. Commission Anchorage December 10, 1981 Mr. Richard C. Hager Mobil Oil CorPoration · P.O. Box 5444 Denver, Colorado 80217 Re.' Preparation of Petrographic Thin Sections from Core Chips in State Library Collection De.a r Rick, Pursuant to our recent discussions, permission is hereby granted to Mobil Oil Corporation to oxtract a maximum 1 cc. of core material per foot of core from the State's set of core chips for the purpose of .preparing petrographic thin-sections within the designated intervals in the following wells, subject to the below listed conditions .. Sample Set No. ~;el 1 Interval 326 386 414 415 ARCO E. Bay St. #1 ARCO Gull Island St. #2 ARCO ~';. Day St. #1 ARCO ~.~. z e-Son Bay #1 9,986 '-12,090 ' 10, 4~0 '-12, 770 ' *8,595'- 9,923' 11,305 '-12,340' *Thin sections to be prepared at depths in addition to those set forth in your }~ovember 17, 1981 letter; both sets of slides to be composited consecutively in one bov.. CONDITIONS i 1. Cuts of the core chips from the State collection are to be extracted only from those individual envelopes or bag's in which total content of core material is greater than 10 cc. (Mo cuts are to be extracted if the volume of material in the individual envelope is .!e~s.s. than 10 cc.) 2~ Mobil will provide the State with a list of the depths in each well from which material was extracted. Mr. Bichard C. Bag '~' 2 ~ .-Lember 10, 1981 3~ All petrographic thin-sections prepared are to be received by the Commission by approximately February 15, 1982 and are to be transmitted direct'to the Commission and not examined by outside parties. All residue and excess material is to be returned to the Commission. No additional slides are to be prepared nor special analyses conducted without specific consent from the Commission. 6. Mobil shall bear all costs entailed. We are pleased to work with you in this beneficial project and look forward to your company's continued exercise of care and good~ judgement in the handling of this limited quantity of valuable well material. I know we both understand that the State's well sample library is public property and that granting ~obil permission to extract portions of material from this library for the purpose of preparing the indicated thin-sections enhances the value of the library and. is in the public interest. Very truly yo .u~s, William Van Alen Petroleum Geologist October 6, 198I Mr. Rick Hager ~obil Oil Corporation P.O. Box 5444 Denver, Colorado 80217 Dear. ~re Hager: Pursuant to our October 1, 1981 phone conversation, permission is hereby granted to Mobil Oil Corporation to extract a maximum icc. of sample material per sample envelope or i cc. of core material per foot of core from the State's set of samples and cores for the exclusive purpose of preparing ~trographic thin sections of core chips within the designated interval in the following well, subject to the below listed conditions: Sample Slides to be Pre, red Interval 414 ARCO West Bay St. ~1 - Petrographic thin sections 8595' - 9923' CONDITIONS: Cuts of the core material from the State collection are to be extracted only from those individual envelopes or bags in which total content core material is greater than 10 cc. (No cuts are to ~ extracted if the volume of material in the individual envelope is les_ s than 10 cc. ) 2~ Mobil will provide the State with a list of the specific core footages from which material was extracted. 0 All petrographic thin sections prepared are to be received by the Commi~szon prior to December 15, 1981 All residue and excess material is to ~ returned to the Commission. Mr. Pick Mager -2- f oL~r 6, 1981 . Ail slides prepared are to be transmitted direct to the Commission and not examined by outside parties. . NO other thin sections are to be prepared nor other analyses conducted without specific consent from the Commission. 7. Mobil shall bear all costs incurred. We are pleased to work with you in this beneficial project and look forward to your company's exercise of care and good judge- sent in the handling of this limited quantity of well material. I know we both understand that the State's well sample library is public property and that granting Union permission to extract ~rtions of material from this library for the purpose of pre- paring the indicated slides enhances the value of the library and is in the public interest. Very truly yours, William Van Alen Petroleum ~eologi st cc: Steve Gunderson Mobi 1-Derive r WJYA: g lh March 18, 1981 Mr. J. J. Pawelek ARCO Oil and Gas Company P. O. Box 360 Anchorage, Alaska 99510 Re: Production Test - West Bay State 91. Dear Mr. Pawelek: We received your letter, dated February 16, 1981, on March 16, 1981 concerning the request for the flaring of gas during the extended production test of the Lisburne Reservoir in the }~est Bay State ~1 wello The flaring of gas produced with the oil from the testing of the West Bay State ~1 well is hereby approved as follows: 1. Flaring of gas is permitted during the start-ups and shut-do%~ns which have i'~en estimated to be 35 MCF per event. 2. Flaring of gas is permitted, when necessary, during the production tests but is limited to 31 ~MCF for 31 day calender months and 30 MMCF for 30 day calender months. It is understood that equipment will be maintained to save and rein- ject all of the gas that is possible, estimated to be about 85% of all produced gas. 3. Monthly production forms (Form 10-405 and Form 10-422) must be timely submitted and this production data will be released to the public. 4. A monthly recap of the _da__i_l~ production rates and flared volumes will b~ timely submitted. 5. Within 90 days after the completion of the testing ot:~rations, a report on the project will be submitted. This should include all pressure data, choice sizes, produced volumes and all other t~rtinent data. Mr. J. J. Pawelek -2- Production Test - West Bay State March 18, 1981 The Commission wishes to congratulate you and your company for raking the tiM, man-hours and monetary expend, itures that will be necessary to test this reservoir. We wish you success in your efforts and hope that, as a result of this work, the Lis- burne Resez~;oir will be a drilling target in the near future. Yours very truly, Harry W. Kugler Commissioner ARCO Alaska, Inc. Post Office b,.x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 February 16, 1981 State of Alaska Department of Natural Resources Division of Geological & Geophysical Surveys 3001 Porcupine Drive Anchorage, AK 99501 ATTENTION: MR. HOYLE H. HAMILTON ALASKA OIL AND GAS CONSERVATION COMMISSION SUBJECT: FLARE REQUEST - WEST BAY STATE NO. 1 Dear Mr. Hamilton: ARCO Alaska, Inc. requests a permit to flare hydrocarbon gas during an extended production test of the Lisburne Reservoir in the West Bay State No. 1 well located near Prudhoe Bay. This test is crucial to determining the viability of developing the Lisburne oil in this area. The test is expected to take about six months. The intent of the test is to determine if the oil zone can sustain an economic rate. The test will also examine the gas- oil-ratio behavior. The main zone to be tested flowed a maximum of 3300 BOPD. The rate is expected to decline rapidly. The average rate over a six-month period is expected to be about 2000 BOPD. The initial GOR was approximately 750 SCF/BBL. Their .~est facility is designed to conserve 85% of the gas in the expected operating range. The compressor is designed to handle 2 MMCFD with a 500 psi inlet pressure. By re- cycling the compressor can handle rates as Iow as 1 MMCFD. Incremental volumes in excess of 2 MMCFD would be flared. Also, at rates below 1 MMCF. D the compressor can not operate and all of the gas will be flared. The majority of the test is expected to occur in the design range of the system. However, the ability to flare gas for rates beyond the expected operating range is important to allow full evalu- ation of the reservoir. A smokeless burner will be used to flare the gas. There will also be flaring associated with equipment start-ups and shutdowns on the order of 35,000 SCF per event. The majority of the oil and gas will be transported to Flow Station No. 1 for final separation. The gas will be transported to the CCP and allocated as field fuel. The oil will be transported to TAPS for sales. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany Our intention is to proceed with the test when all approvals and permits have been received. At present, we anticipate a summer start-up. This information is proprietary and should be held confidential. If you would like to discuss the matter in more detail, please call me at 263-4205. Very truly yours, -~. J. Pawelek EJH/lw AtlenticRichfieldCompany North American Producing Division North Aiasl ~istrict Post Office ,.Jx 360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 24, 1979 Mr. Hoyle Hamilton State of A1 aska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 ? - CONFEiL FILE: Subject' Core Summary ARCo-Exxon West Bay State No. 1 Dear Mr. Hamilton- Enclosed please find our Core Summary for the West Bay State No. 1 well submitted as Item No. 36 on Form P-7. Very truly yours, d. D. F~rtier Operations Geologist JDF-jea Enclosures - as stated cc' K. Lenz ARCO-EXXON ~'~est Bay State No. 1 Core Summary Conventional Cores: Core ~l' 8595'-8652' Cut 57' Rec. 57' Limestone w/minor shale, poor porosity. No shows. Core #2' 8652'-8712' Cut 60' Rec. 58.5' Limestone, Dolomite & shale. Poor to good shows. Core ~ ' -8773 Cut 61 Rec. 58 73. 8712' ' ' ~ -8833 Cut 60 Rec. 60 Core ~4: 8773' ' ' ' Core #5: 9453'-9513' Cut 60' Rec. 59' Core#6: 9707'-9766' Cut 59' Rec. 59' #7: ' ' ' ' Core 9766 -9809 Cut 43 Rec. 43 Core #8: 9806'-9865' Cut 59' Rec. 59' Core #9: 9865'-9923' Cut 58' Rec. 60' Limestone & chert. Poor to good shows. Limestone & Dolomite. Poor shows. Limestone & Dolomitic Limestone. Poor show. Limestone & Dolomite. Poor to fair shows. Dolomite & Limestone. Poor shows. Dolomite & Limestone. Poor shows. Dolomite & Limestone. Poor shows. Sidewall Cores: 7946 7955 7972 8044 8048 8056 8060 8067 8082 8094 8102 8105 8122 8162 Shale Shale Sandstone, fair Sandstone, poor ~orosity, no show ~orosity, poor show Sandstone, fair porosity, no show Sandstone, fair Sandstone, poor Sandstone, fair )orosity, poor show )orosity, ~oor show ~orosity, poor show Sandstone, good porosity, poor show Sandstone, poor porosity, ~oor show Sandstone, poor porosity, ~oor show Sandstone, poor porosity, ~oor show Sandy conglomerate, good porosity, poor-fair show Pebbly sandstone, poor porosity, poor show Sidewall Cores West Bay State No. 1 Page two 8170 8175 818O 8189 8196 8199 8201 8208 8211 8214 8221 8223 8225 8228 8230 8238 8248 8251 8253 8261 8265 8267 Scattered chert pebbles Sandstone, fair porosity, fair show Sandstone, poor porosity, no show Sandstone, poor porosity, no show Sandstone, fair porosity, fair show Pebbly sandstone, poor porosity, poor show Sandstone, fair porosity, poor show Sandstone, fair-good porosity, poor-fair show Conglomerate, fair porosity, poor show Pebbly sandstone, poor porosity, poor-fair show Sandstone, fair porosity, poor show Mudstone Sandstone, fair porosity, poor show Sandstone, poor porosity, poor-fair show Sandstone, fair porosity, poor show Pebbly sandstone, poor porosity, poor-fair show Mudstone Sandstone, fair porosity, fair-good show Sandstone, fair to good porosity, poor-fair show Scattered chert pebble Sandstone, poor porosity, fair-good show Sandstone, poor porosity, poor-fair show 8269 Sandstone, poor porosity, fair show 8274 8289 8303 Sandstone, good porosity, fair-good show Sandstone, poor porosity, fair show Sandstone, poor porosity, poor-fair show Sidewall Cores ~'~est Bay State Ito. 1 Page three 832O 8336 8342 8356 8363 8372 8375 8386 8391 8394 8406 8409 8413 8419 8431 8438 8447 Sandstone, fair porosity, poor-fair show Sandstone, fair porosity, poor show Sandstone, poor-fair porosity, fair show Sandstone, poor porosity, poor show Sandstone, good porosity, fair show Sandstone, poor porosity, poor show Sandstone, fair porosity, fair show Sandstone, poor-fair porosity, fair-good show Sandstone, poor porosity, poor show Sandstone, poor-fair porosity, fair show Siltstone, fair porosity, poor show Sandstone, good porosity, good show Pyrite fragments Sandstone, poor to fair porosity, fair-good show Sandstone, poor to fair porosity, fair-good show Sandstone, fair porosity, poor show Sandstone, poor to fair porosity, fair-good show 84q. 9 ~.!udstone ::AUar, ticRJchfieldCompany North American Producing Division Norlh Alas':' ')istrict Post Office ~ox 380 Anchorage, Alaska 99510 Telephone 907 277 5637 January 10, 1979 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, .Alaska 99501 SUBJECT' West Bay State #1 ~ Permit No. 78-30 Dear Sir- Enclosed find the As-built Survey for the above-mentioned well. We consider this hole extremely tight and would appreciate your cooperation in placing this report in secured storage where it will receive minimum exposure. Please acknowledge receipt of the attached report by returning one signed copy of this letter for our files. Thank you for your attention in this matter. Very truly yours, P. ^. VanDusen District Drilling Engineer PAV-css Enclosures CONFIDENTIAL DISTBIBUTED TO:. STATE OF ALASKA DIVISION OF OIL & OAS Signature / Date Title · $5!56 PROTRACt TI2N 56 ED SECTION 1 CONDUCTOR No. 1 T. 11N.,R.]4 E., U.M. 2 I 31 6 WELL No ! LAT 70°20' 12.519'' LONG. 148°28'1 Y: 5 975 132.78 X: 688 61 5.67 ASP(_; ZONE 4 LEGEND ,~ EXISTIHG COt',iDUCTOR CERTIFICATE OF S~RVEYOR t HEREBY CERTIFY THAT I AM PROPERLY RE/;ISTERED AND LICENSED TO PP. ACTICE LAND SURVEYING IN THE 5rA'FE OF ALASKA ANO THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION, AND ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT DEC. I 3,1978 , [}ATE SURVEYOR IHVL No. 46-WBS-78 ATLANTIC RICHFIELD CO. AS- B LII LT WEST BAY STATE No. 1 LOCATED IN PROTRACTED SECTIOH I,T. IIN.,R.14E.,U.M, ALASKA PREPARED BY HEWlTT V. LOUNSBURY A ASSOCIATES 723 W. 6th AVE., ANCHORAGE, ALASKA DATE DEC. 1978 CHKD. BY HPC' SCALE I" = I000' FIELD BK. AflanticRichfieldCornpany North Ameri~--q Producing Division North Aiask,~ ,istrict Post office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 10, 1979 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 SUBJECT' West Bay State #1 Permit No. 78-30 t' Dear Sir' Enclosed find the As-built Survey for the above-mentioned well. We consider this hole extremely tight and would appreciate your cooperation in placing this report in secured storage where it will receive minimum exposure. Please acknowledge receipt of the attached report by returning one signed copy of this letter for our files. Thank you for your attention in this matter. Very truly yours, P. A. VanDusen District Drilling Engineer PAV:css Enclosures COI I)mTIAL DiSTRIBTJTED ~ STATE OF ALASKA DIVISION OF OIL & GA~ si'gnature / / Ti tl e Date 35i36 TI2N 36 TIIN I 250~ PROTRAC' i I ED SECTION CONDUCTOR No. 1 T. 11N.,R.14 E., U.M. :2¸1 WELL No 1 LAT '70°20' 12.519'' LONG. 148°28'10.355" ¥: 5 975 132 ,78 X: 688 61 5.67 ASPC ZONE 4 LEGEND EXISTIHG CONBUCTOR 31 CERTIFICATE OF SURVEYOR I HEREBY CERTIFY THAT I AM PROPERLY RF_GISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE 5FATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION, AND ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT DEC; I 3,1978 DATE SURVEYOR HVL No. 46-WBS-78 ATLANTIC RICHFIELD CO. AS- BUILT WEST BAY STATE No. I LOCATED IN PROTRACTED SECTION I,T. IIN.,R.14E.,U.M., ALASKA PREPARED BY H£WITT V. LOUNSBURY a ASSOCIATES 723 W. 6th AVE., ANCHORAGE, ALASKA DATE DEC. 1978 CHKD. BY HPC- SCALE I"= I000' FIELD BK. AflanticRichfieldCompany North American Producing Division" North Alas?-3istrict Post Office ~o× 360 Anchorage, Alaska 99510 Telephone 907 277 5637 December 18, 1 978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Subject' West Sak 25647 No. 12, Permit No. 78-40 Dear Sir- Enclosed is a Monthly Report of Drilling Operations for the above mentioned well. Very truly yours, P.A. VanDusen District Drilling Engineer PAV/mr Enclosure ., Aflan ~iCRichfieldCompany ¢ North Arneric~_~-'~ Producing Division North Alas~ ;,strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 December ll, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' West Bay State #1 Permit No. 78-30 Dear Sir' Enclosed please find the Completion Report along with the Drilling History and Test summary for the above-mentioned well. We consider this hole extremely tight and would appreciate your cooperation in placing this report in secured storage where it will receive minimum exposure. Please acknowledge receipt of the attached report by returning one signed copy of this letter for our files. Thank you for your attention in this matter. Very truly yours, P. A. VanDusen District Drilling Engineer PAV'mln Enclosures Si gnatur~e ~ Date ! Form P--7 SUBMIT IN D1 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE TE* (Se. ,,~hertn- st ructions on reverse sitte I i i.ii i i WELL COMPLETION OR RECOMPLETION REPORT AND LOG* Xa. TYPE OF WELL: OXL [] & 6A* [~ F~ WELL WELL DRY Other b. TYPE OF COMPLETION: NEW ~ WORK ~ DEEP- ~ PLUG ~ DIFF. ~ S nd ,v~ ov~a ~x ,.,OK gsSVg. Other. uspe, ed NAME OF OPERATOR Atlantic Richfield Company ADDRESS OF OPERATOR P. 0. Box 360, Anchorage, Alaska 99510 LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* At surface 2500'FNL & 2500'FWL, Sec. 1, TllN, R14E At top prod, Interval reported below 2500'FNL & 2500'FWL, Sec. 1, TllN, R14E At total depth 2500'FNL &' 2500'FWL, Sec 1, TllN, R14E 5, AP1 NU1VLEHJCAL CODE 50-029-20304 6. LF_JkSE DESIGNATION A.ND SERIAL NO. ADL 28302 7, IF INDIA.N, AJ_,LO'I~i'EE OR TRIBE NA_5/LE 8. UNIT FA.I:UVI OR LEASE NAME Z / 9. WELL NO. 1 10. FIELD ~D POOL, OR WILDCAT Wildcat 11. SEC., T., R., M., (I~OTTOM OI3.1ECTIV E) Sec. 1, T11N, R14E, UM 12. PERJVIIT N'O. 78-30 i 78 ! I /18/78 8/5/ 10/6/78 54.5' KB -. · '~. TOTAL DIb~PTH, ~ & TVD[19. PLUG, tlA~CK MD & 'l~v'D~t0. ~ ~LT~LE CO~L., [ 21. 'INTERVALS DRILLED BY 0 38~I [ F [g .~O~~' · ~ ROTARY TOOLS [ CABI,E TOOl, 8 1 , MD & TVD 9000:MD & TVD ~ng elective one x 23. WAS DIREC~ONAL ~. PRODUCING INT~VAL(S), OF '~'HIS CO~'~'IO~ BOSOM, N~E (~ AND ~)* 8810 - 8902.{Bottom ~:ntervaI) ~o~/) , 8697 - 874~5~(Middle interval) (oil) t Yes 8560- n~q /Tnn ~,~,,~-1~ .(gas) ~4. T~ ~T~.~C ~DFO~- DIL/SP/BHCS/FDC/GR/CAL, CNL, Proximity microlog, CBL, VDL, CCL, Mudlog OAS~G R~CO~ (Re~rt all strings set i~ weld 20" 94~ H-40' 176- b~lo~ a~ 24'"' 175 sx ~rct~csrt'II cmt. 13-3/8" 72~ Butt ~-80 [ 2738' [17-1/2" 4300 sx ?ermafrost II cm . 9-5/8' 47~ ~utt ~-80 ~ 8523' 11~-1./4" 1000 sx Cla~s ~ cmt. ' s-9 I I ', 8790' 8674~ .~ ' . 8109' 29. 'ACID, Si!Or, FX~C]'GRE, CESIENT SQU~XZig, ETC. D~i INT~V~ (MD) [ AMOUNt 2~D }liND OF 8810. 8902 J. pumPed 4500 gal. 2a%, Hg 8697 - 8745 pumped 4000 flal. 28% HCI ' ' 8560 - 8639 Pumped 6200 9al. 2890 HCl . PKODUCION DATE FIRST PXODUC~OH [ ~ODUCTION ME'IIfOD (F~owh~g, gas lift, pump~g~size and type of pump) [V~ELL STATUS (Producing or NOTE: No production data available. Well is completed but no hook-[up to production ' I t I I raca~ ataes. 1 ' ' -- ' ' =' N = "' q '"~ ' 31. DISPOSITION Or GAS (Sold, used lop luet, vented, etc.) Dlb~~ ~ST ,,',T. ~0 .,~ :: STATE OF ~ '" Dc:II:nE H.:stocy, Test Summaw ......... ~ ...... ' ..... :~ 33. I hereby ~.~'.d: .,--: .... certify ~t the fgregoing and attached information Is complete and corral[ as determined f~om all~:'aflabf~ Fe~dh SIGNED ~.. _ ~~--~'. . ~: TITLE ~~' DATE · (See Instructions and S~ces [or AdditiOnal Data on Reverse Side) 26. LINER 1R~E C O I°~D SIZI~ '[ TOP (B, ID) [ BOTTOM (hiD) [ SACKS C~{ENT. 10~383 450 sx i i ' i i i ' i 2~. PERFORATIONS OP~ TO PRODUc'i;ION {interval, size and number) 8890 - 8902, 8834 - 56, 8810 - 22 (48')Ali 1 shot/ft. a69y- a 45 (48') -Shot/ft. 8560 - 8639 (79') All 1 shot/ft. INSTRUCTIONS General: This form is designed for submitting a complete and correct welt completion report and lag on~ all types of lanJs and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in cther spaces on this form and in any attachmer~ts. Items 20, and 22:: If this well is completed for separatc, prcduction from more than one nterval zone (multiple completion), so state in item 20, and in item ?2 show the p~cJuci~:~] interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each addition~l interval to be seperately produce,d, show- ing the ackiitional data pertinent to such interval. Item26: "Sacks Cement": 'Attached supplemental recOrds for this well shoulJ show the details of any mul- Iiple stage cementing and the location of the cementing tool:. 28: Submit a separate completion report on this form for each interval to be separately produc~t. See instruction for items 20 and 22 above). '34. SUMMAItY OF'~b ION T~:I'S INCLUt)IN(; INq"EFtVAL TESTED, Pa~UnE 9ava ~ ~ovgm~ oF om] ~AS, 35. G~GIC ' ' ;"'" WAT~ AND MUD . , .. . AN'D; DE-rECall) SI'iOn'S OF OIL. GAS O11 W-A~I. '"' ' . · ~ i-, ......... ,,, .~-~ DRILLING HISTORY --~. West Bay State #1 API 50-029-20304, ADL 28302, Permit No. 78-30 Spudded well @ 0230 hrs 6/18/78. NU diverter system & annul preventer. Drld to 2760'. RU & ran 13-3/8" csg w/shoe @ 2738'. Cmtd w/4300 sx Permafrost II cmt. Drld to 2770'. Tstd form to 12.5 ppg equiv. Drld to 8536'. Ran DIL/ BHCS/FDC/ GR/Caliper. Ran sidewall core. Ran 9-5/8" csg w/shoe @ 8523'. Cmtd w/lO00 sx Class G cmt w/1% CFR-2 & HR-7. Tstd FO's. Did Arctic Pack job. Drld FC & cmt to 8508' Ran CBL & velocity survey. Displ mud w/wtr. Displ wtr w/10.3 oil phase mu~. Drld shoe & 10' new form. Tstd to 12.5 equiv. Drld to 8595'. PU core bbl ,Core #1_~ 8595'-8652' "core #2 8652'-8712' . , rec 60 , ~_ , , rec 58.5'; c~.re #3, 8712'-8773', rec 58'; core #4, 8773'-8833', rec 60'. PU drlg BHA, drld to ~53' PU core bbl. Core-'#5' 9453'-9513' ' · , rec 59 . PU drlg BHA, drld to 9707' PU core bbl. Core #6, 9707' -9766', rec 59'. Ran FDC/CNL/GR/Caliper & GR/SP~DIL. RIH w/core bbl. Core #7, 9766'-9806', rec 40'. RIH w/tst tools & press recorder. Opened tool w~'iight blow. Closed tools for build up press. POH w/tst tools· RIH w/core bbl. C__o~_e #8, 9806'-9865', rec 59', c~re #9, 9865'-9923', rec 60' Ran GR/FDC/CNL & GR/BHCS logs. Ran dipmeter. Displ oil faze mud w/wtr base ~ud. Drld to 10,383'. Ran DIL/SP/GR, BHC/Sonic/GR, FDC/ CNL/CAL/GR. Ran proximity microlog. Ran velocity survey. RU & ran 54 jts 7" 29# N-80 Butt lnr. Pumped 30 bbl wtr ahead of 20 bbl CW-7 mix. Mixed 450 sx Class G, slurry 15.8 ppg. Displ w/220 bbl mud. Tagged top of lnr @ 8203'. Tstd csg to 2500 psi, OK. PU 9-5/8" tst tool. Ran 3700' wtr cushion. Set pkr @ 8150'. Had weak blow for 10 min. Well dead remaining I hr. 50 min. Closed tool. Rev out wtr cushion. Ran CBL/VDL/GR/CCL. Displ w/10.3 CaC12 wtr. Ran temp sur. RU & ran 3-1/2" 9.3# CSCB tbg. Set pkr @ 9648' w/tailpipe @ 9773'. Displ tbg w/diesel._p~F~.!~d~9904'-9914', 9884'-9904'. Flowed est rate 80-100 bbl/day. Ran fluid sampler. Rev out tbg after tst. PU 5 jts. Rev out below perfs. Ran junk bskt & gauge ring to 10,000'. Ran 7" EZ drl cmt ret. Set @ 9844'. POH. Pull wear ring. Set tst plug· Tst 5" rams to 5000 psi, OK. PU ret. Trip over DP. Stabbed into ret. Tst lines to 5000 psi, OK. Broke down form @ 1600 psi. Injected 4 bbl/min to 2500 psi. Pumped 40 bbl fresh wtr ahead of 100 sx Class G cmt. Final shut in pres 2800 psi. Release pres from DP ann. PO of stinger. Rev out DP. TIH w/3-1/2" tbg & tst assy. Tstd lines 5000 psi. Displ tbg w/81 bbl diesel. Set pkr. Perf'd 9761-9769'. POH. No flow. Perf'd 9704- 9722'. No flow. Perf'd 9678-9696'. POH. No flow. Perf'd 9704-9722'.-~'N0 flow. Perf'd 9678 ' 2-9696'. No flow. POH. Established injection rate 25 bbl diesel to 4,~ D6i/min @ 3800 psi. Pumped 2250 gal diesel w/10% free flow EB mutual solvent. Start injecting ball sealers after 500 gal. Balled out w/same. Final pres 7000 psi. Shut in for 30 min. Pres bled to 2500 psi. Surge balls off perfs. Shut in for 30 min. Pumped additional 45 bbl diesel. Pumped 2800 gal of 28% HCL. Pump started losing suction. Switched to diesel. Displ acid to perfs w/diesel. Final rate 3.5 bbl/min 3500 psi. Instant shut-in, 3100 psi. 30 mir shut-in 2700 psi. Surge balls off perfs. Shut in well. Ran temp log. Positioned HP for tst. Open well for flow. Turned well to burn pit. Well shut in. 900 psi buildup. Warmed acid & diesel. Tstd lines to 8000#, OK. Establish injection rate, 4 bbl/min, 3500 psi, OK. Pump 5000 gal 28% HCL using 70 1.3 SG balls. Maximum pres 7000 psi. Surge balls off perf. RIH w/HP & Amerada bombs. Tool failed. Chg tool. RIH. Open well to flow. Pres fell from 1700 psi to O. Bot hole pres dropped from 5100 to 4000 psi. Flowed well. Made approx. 171 bbl in 24 hr. Ran gradient sur. Flowed well on 1/4" choke. Well died. Ran bot hole sampler. SI well for pres buildup. Kill well. Pump 60 bbl 10.3 high vis pill. Displ pill to perf. Bled off pres to O. Rev out tbg. Unseat pkr. POH w/same. R!H & set HoWco EZ drl SV bridge plug @ 9638'. POH. Closed rams & tstd csg to 3000#, OK. Install tst plug. Tstd Hydril to 3000#, 3-1/2" pipe rams to 5000#. Cut drl line. Making up surf equip for tst 3. Ran tbg to 8982'. Set pkr. Tstd same to 2500# on backside. Opened by-pass. Displ tbg w/75 bbl warm diesel. Close by-pass. RIH. _Perf'd~. 9100-9076'. No~f~,~L~k~,~k~erf'd 9076-9070', no flow. Perf'd 9066-9054', no ~ Y)IST~IBUTED ~TATE OF ALASKA ~]¥ISION O2F OIL & flow. Perf'd 9046'-9034', w/gun #3, no flow. RIH w/HP. Opened well to flow. Well woul---~-Oi~-'-'~-~6~i .... -R-O-to acidize. Injection rate w/diesel 4.5 bbl/min, 2700#. Pumped diesel mutual solvent mixture @ 50 gal/perf ft. Dropped 80 1.3 SG balls. Had pres increase to 6100 psi breaking back to 5100 psi. Surge balls off perf. Pumped 3500 gal 28% HCL dropping 61.3 SG balls. Maximum treating pres 4700 psi. Displ w/diesel to perf. Surge balls off perfs. RIH w/HP & Amerada bombs w/temp tool. Flowed well thru 1/2" choke. Surf declined from 1750 psi to 80 psi. Produced total of 410 bbl of fluid. Total fluid injected into zone 390 bbl. Final produced crude 24.5 API gravity. Shut in well for pres buildup. RU to kill well. Pumped 60 bbl high vis pill followed by clean CaC12. C,h, eck for flow. No flow. Unseated pkr. Rev out hole. POH w/tbg. Install 5 rams & tst same. Ran junk bskt to 9020'. RU & ran EZ drl bridge plug. Set @ 9000'. Tst csg to 3000#, OK. Ran 4" csg gun & perf'd 4 shots/ft. 8800-8802'. PU EZ drl ret @ setting tool on DP.. RIH. Set s~me-ca~8727'.'~ '-PS~d--i-n form @ 3 bbl/min 3200#. Pumped 25 bbl fresh wtr followed by 200 sx Class G w/1% CFR2 & 0.15% HR7 followed by 15 bbl wtr followed by 70 bbl CaC12. Placed 15 bbl wtr outside tool. Stung into ret. Placed 185 sx cmt below ret. Maximum pres 2800 psi @ i bbl/min. Rev out 15 sx. POH. RIH w/4" csg gun. _Pm~lc_~f~.._d__8_6~8~ ,8686 , 4 shots/ft PU 7" EZ drl & setting tool & TIH w/DP Set @ 8600'. Tstd EZ drl on outside of DO to 2000 psi, OK. Broke down form w/4200 psi. Injected 2-1/2 bbl/min, 3800 psi. Spotted 25 bbl wtr followed by 200 sx Class G w/1% CFR2 & .1% HR7 followed by 15 bbl wtr, 68 bbl CaC1 . Pumped 170 sx cmt into perfs leaving 15 sx above perfs below ret. Rev out 152sx. Max final pres 2500 psi. Unstung from EZ drl. Rev out DP. POH. LD 22 jts 3-1/2" DP. Drld EZ drl & cmt to 8699'. Drld EZ drl @ 8727'. Drld cmt to 8817'. Circ & CO on top of bridge plug @ 9000'. POH. PU 7" csg scraper. TIH. Circ bot up. POH. Set tst plug. Chg 5" rams to 3-1/2" rams. Tstd Hydril to 3000#, 2 sets of 3-1/2" rams to 5000#, OK. PU 2-7/8" tailpipe & BHA. TIH. PU tst head. Tstd all valves to 6000#, OK. Hooked up pump lines. Circ 150 bbl CaC12 down tbg, OK. Set RTTS @ 8611'. Opened bypass. Displ tbg w/73 bbl warm diesel. Pump thru & tstd all tst lines to 2000#, OK. Perf'_d 8834__~8_5~6~~' ...... ' w/1 shot/ft. Perf'd~O'~-~8902' & 8810'-8822'. POH. RU for acid job. After perf, no surf pr~]~=~ ~ep {-~ ~-~p ~-6'~6T-fl~'a~h Pumped 2000 gal diesel w/lO% U-66. Used 120 1.3 SG balls. Displ w/81 bbl diesel. Did not get ball out. Pumped 4500 gal 28% HCL. Used 95 1.3 SC balls. Displ w/diesel @ 4 bbl/min. Did not get ball out. Tstd BOPE. RIH w/Amerada HP temp sur. Opened well. Pres dropped from 1300 psi surf pres to 900 Psi. Rec 93 bbl diesel & acid wtr. Well started making gas. Turned to flare pit. At 0530 9-1-78 bot hole pres 9777, tbg pres 1071 1/2" choke, 2578 BOPD, GOR 611. Flowed well for 6 hrs. on 1/2" choke. Flowed well for 12 hrs. on 3/4" choke. Had severe foaming problem in separator. POH w/HP. Had to rehead line. While doing so, RU to inject defoamer in line. At 0100 hrs. 9-2-78 on 3/4" choke 2587 BOPD, 2.7 MCFD, GOR 1045. Flowed well on 1" choke. At 0530 9-3-78 bot hole pres 3326, tbg pres 880, choke size 1" bbl/day = 2961, 1.9 MCFD, GOR 671, 27.4 gvty oil @ 60©. Flowed well on 1'~ choke to 1100 hrs. 9-3-78. Shut in well for pres buildup from 900 psi surf pres to 1625. Bot hole pres from 3215 - 3~837'. Final flow was 3026 bbl/day, ,2.3 MCFD, GOR 771. Completed shut in @ 2300 hrs 9-4-78. Bot hole pres 4052#. Flowed well 3/4 hrs. Shut in well for 2 hr buildup. POH w/Amerada HP rec. Took wireline fluid samples. Pumped 60 bbl 10.3 Hi-Vis Lost-Circ kill pill. Tbg pres bled to O. Opened bypass. Lost 14 bbl fluid in ann, 10 bbl fluid in tbg. Closed tool. Mixed 2nd kill pill. Displ kill pill to perfs. Opened bypass. Fluid dropped in ann slowly, I bbl/every 3 min. Mixed 3rd kill pill. Pumped 71 bbl 10.3 Hi Vis kill pill, 3 bbl/min. Opened bypass. Had good returns up ann. ("ONFID NTIAL Closed bypass. Pumped pill into form @ 1-1/2 bbl/min. Pumped total 76 bbl pill in form. Waited on pill for 3 hrs. Opened bypass. Hole taking fluid 1 bbl every 4 min. Circ down tbg, up bypass. Lost total 39 bbl in 3-1/2 hrs. Pull pkr loose. Lost add 24 bbl. Lost hole for I hr. Lost add 7 bbl. POH w/tbg. RU Schl. RIH w/Howco EZ drl bridge plug. Set @ 8795'. PU tailpipe, Amerada bombs~. TIH w/3-1/2" tbg & RTTS. Pumped 2 volumes of CaC12 down tbg & around pkr. Tstd csg to 1500#, OK. Set pkr @ 8369'. Tstd on ann w/2000 psi, OK. Opened bypass. Displ tbg w/73 bbl warm diesel. Tstd lub to 5000 psi, OK. RIH w/gun #1. Perf 8721 - 8745_.', OK. Perf..gun..~#.~8697 - 8721', OK. Established injection rate of 4 bbl/min, 3300# w/1800 bbl diesel. Pumped 2000 gal diesel w/10% U-66. Dropped 91.3 SG balls. Pumped @ 4 bbl/min 3100 psi. Displ w/83 bbl diesel. Had good ball action. Maintained 4 bbl/min during displ. Final pres 6400 psi. Pumped 4000 gal 28% HCL. Dropped 83 1.1 SG balls & displ 4 bbl/min 2900 psi. Final pres 4 bbl/min, 3500 psi. Surge balls off perfs. RIH w/temp HP Amerada bombs. Opened well to flow. Shut in well. POH w/bad HP tool. Opened well back up on 1" choke. 0530 hrs. 9-10-78 bot hole pres 3489, tbg pres 850, 1" choke, 3350 BOPD, 2.9 MCFD, 870 GOR. Flowed well until 1000 hrs. 9-10-78. Shut in well for pres buildup. 0230 hrs. 9-12-78 shut in bot hole pres 4080, shut in tbg pres 1932. Well remained shut in until 0430 hrs. RIH w/fluid sampler. Took sample @ 8680'. Made up sampler #2. Took sample #2 @ 8680'. Made up sample #3. Again sampled @ 8680'. Made up gun #1. Tstd lub. Perf'd 8628 - 8639'. POH. Gun had misfired. PU gun #2. Perf'd 8616 -8639'. ~3 perf'd 8606 - 8616', 8595 - 8606' PU gun #4. Perf'd 85~---~1 - 8595'. PU gun #5. Fired 8560 - 8571'. Flowed weli I hr on 1/2" choke. Flowing tbg pres 1225 psi 1/2" choke, 2630 bbl/day, GOR 798, Oil gvty 27.60. Gas gvty 0.782. RU to kill well. Pumped 1st pill. Well cont' to take fluid. Pumped 2nd lost circ pill. Cont taking fluid. Pumped 3rd pill. Well killed. Opened bypass. Rev circ capacity of tbgs. Lost 70 bbl of mud. Released tool. POH. Lost 80 bbl while POH. LD tst tools. RIH w/junk bskt to 8688'. RIH w/Howco EZ drl. Bridge plug set @ 8675' PU 2-7/8" tailpipe, 7" tst tools. TIH w/3-1/2" tbg & tst tools. RU tst manifold. RU to acidize. Heated acid. Displ tbg w/diesel. Set pkr. Pres ann to 2000 psi. Pumped 90 bbl of diesel U-66 mix. Drop 142 1.3 SG balls. Displ w/78 bbl diesel. Had good balling action. Pumped 6200 gal. 28% HCL using 160 1.3 SG balls. Displ w/diesel. Maximum treating pres 7000 psi. Final pres 3900 psi. Ran temp sur. RIH to 8550'. Flowed well. Shut in well for buildup. Pumped in 88 bbl hi vis kill pill, 9.8 ppg. Shut well in. Letting pill soak. Opened bypass. Fluid dropped. Closed bypass. Took 27 bbl to fill ann. Pumped 100 bbl 10.2# hi vis pill. Opened bypass. Lost 36 bbl. Closed bypass. Pumped 150 bbl 9.8 ppg hi vis pill. Shut in well. Let pill soak. Unseat pkr. Start out of hole. Losing fluid very slowly. POH w/tbg. RD tools. PU BHA & TIH ~v/3-1/2" DP. Cond CaC12 @ 8678'. Hole taking fluid, approx 30 bbl/hr Pulled I std. Pumped 150 bbl hi'vis pill. Hole taking fluid @ 6/bbl/hr rate w/mud static. Drld ret @ 8692'. Losing 12 bbl/hr of CaC12 to form. Circ & cond mud @ 8794 while adding Dril-S, safe seal additives to CaC12. Presently losing 15 bbl/hr CaC12. Drld ret @ 8794'. Pushed to 8810'. Losing 50 bbl/hr fluid, mixed 142 bbl hi vis pill. Spotted same in place. TOH for new bit. TIH w/bit. Drld ret 8959'. CO hole to 9014'. Cond & circ mud. PU 7" & 9-5/8" csg scrapers. TIH. Circ bot up. Losing approx 60 bbl/hr to form. Pumped 100 bbl hi vis pill. TOH w/RTTS. LD scrapers. TIH w/RTTS. Set pkr @ 2525'. Closed rams. Tstd 9-5/8" to 3000# on csg DP ann. POH. LD RTTS tools & DC's. RIH w/7" 29# gauge ring to 8970'. Ran Baker 7" 29# F-1 production pkr on wireline. Set @ 8790'~ Made up 2-7/,5'? BHA below Bake~' 7" FB-1 pkr. Tagged F-1 pkr w/stinger in DP. PU & pumped 50 bbl CaC12 to insure tbg clear. Stab into F-1 pkr w/seals. Dropped 1-7/8" setting ball. Set FV-1 pkr @ 8675' w/4000 psi. Sheared tension studs. Increased tbg pres to 5500# & sheared ball. TOH. CONFIDEI IAL DISTRIBUTED ~'TATE OF ALA.SI~ Started 3-1/2" compl assy. PU Baker AL-5 dual 9-5/8" production pkr. Sperry Sun bottom hole pres monitor, 3-1/2" tbg. Started in hole w/compl assy. Installed BV nipple & gas lift mandrels. Installed 1/4" line on BV & tstd same to 5000 psi. Install Sperry Sun .094 hollow line on short string side of pkr. Spaced out tbg. PU OCT 3-1/2" tbg hanger. Install 1/4" control line on 1 side of tbg hgr Sperry Sun .094 sensor line in other connection on tbg hgr. Pres tstd control line to 5000 psi. Checked out Sperry Sun line, OK. Circ 75 bbl CaC12 down tbg. Drained & washed out BOP stack. Landed 3-1/2" tbg. Installed service connection to control line of Sperry Sun sensor line. Tstd same to 5000 psi. Installed BPV. ND BOP's. NU Xmas tree. Pull BPV. Set tree, tst plug. Tstd tree to 5000 psi, OK. Pulled tst plug. Pulled dummy valve. Dropped ball & Set AL-5 pkr~ Opened sl.iding sleeve. Reran dummy valve. Flowed well. Pulled dummy valve. C~!osed slidi sleeve Flowed well on 1/2" choke. RIH w/plug. Set in D nipple @ 875v . Opened ~g-7/8" sliding sleeve. Flowed middle oil zone on 1/2" choke. Closed sliding sleeve. Opened 3-1/2" sliding sleeve. Flowed well on 1/2" choke. Closed sliding sleeve. SI well. Removed fill. Rec plug. Set dummy valve. Flowed upper gas zone & bottom oil zone. Pulled dummy valve. Ran flapper valve. Released rig @ 0600 hrs. 10-6-78. CONFIDENTIAL DISTRIBUTED TO:. STATE OF ALA$1~ DIVISION OF OIL & ~ WEST BAY STATE NO. 1 TEST SUMMARY Date 8/12 - 8/13/78 8/15 - 8/20/78 8/21 - 8/23/78 8/30 - 9/03/78 9/08 - 9/13/78 9/12 - 9/17/78 Interval 9884-9914 9678 - 9769 9O34 - 9046, 9070 - 9100 8810 - 8902 8697 - 8745 8560 - 8639 F1 uid Rate (iBB1/Day) 40* 8O 8O 2950** 3300** Water Cut % 100 5 0 0 Gas Rate (MMCFD) 2.2 2.3 23.6** FTP 0 100 900. 900 2500 FBHP 4018 1882 2000 3215 3433 4197 *Unstimulated **Zones completed for production AtlanticFtichliMdC'ompar~y ~,!orlh A)ner?_~.~} Producing Division Alaska Reg Post Of Hce box 360 Anchorage, Alaska 99510 Telephone 907 277' 5637 SAMPLE TRTLNSMI YTAL SHIPPED TO: State of Alaska Division of Oil & Gas Conservation 3001 Porcupine Drive Anchorage, AK 99501 DATE' sept. 27, 1978 OPEP~TOR: ARCO SA~PLE TYPE'~ Dry Ditch SA~LES SENT: 2760 - 4440 4440 - 6180 6180 - 7770 7770 - 8580 8580 - 9310 9310 - 10050 10050 - 10~83 WEST BAY STATE #1 NUMBER OF BOXES' 7 SHIPPED BY' UPON RECEIPT OF THESE SA~.~?LES PLEASE NOTE 7~NY DISCREPANCIES AND MAIL A SIGNED COPY OF THIS FORM TO' ATLANTIC RICHFIELD CO. v.o. BOX Anchorage, Alaska 99510 ~t/7/7~ Attn' R, L. Brooks RECEIVED BY: ~//t~/~V~ Atlantic Ricltfield Compan' North Alaska ]).istrict State Of Alaska Division Of Oil and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska i t'L42, ~ :-I [ r i AL R.A.Mclntosh/North Geological November 3, 1978 Date: Transmitted herewith are the following: West Bay State #1 Logs (1 blueline and 1 sepia each) Borehole Compensated Sonic LOg Cement Bond Log (7-2-78 & 8-10-78) Dual Induction Laterlog Compensated Formation Density (Run 1, 2" als0) Compensated Neutron Formation Density Mudlog .Proximity-Microlog Temperature Log (Run 1, 2" also) Casing Collar Log and Perforating RecOrd Run 1,3,4 2",5" Scale Run 1 5" Scale Run 1,2,3,4 2",5" Scale Run 1,2,3,4 5" Scale Run 2,3,.4 5" Scale (2760-10383) Run 1 2",5" Scale Run 1,2,3,4,5 5" Scale Run 1,2,3,4,5 5" Scale .Return receipt to: Atlantic Richf:[e]d Co~npany Attn' District Geo].ogis~ P.O. Box 360 Anchorage, Alaska 99510 Proc:cs;.qe.d by' Dan P. Nice AflanticRichfieldCompany North Amer~n Producing Division Alaska Re~. Post Office Bo× 360 Anchorage, Alaska 99510 Telephone 907 277 5637 October 5, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Subject' West Bay State #1 Permit No. 78-30 Dear Si r' Enclosed please find the Monthly Report of Drilling Operations for the above-mentioned well. We consider this hole extremely tight and would appreciate your cooperation in placing this report in secured storage where it will receive minimum exposure. Please acknowledge receipt of the attached report by returning one signed copy of thiS letter for'our files. Thank you for your attention in this matter. , L i si L Very truly yours, ! P. A. VanDusen (acting) District Drilling Engineer PAV'jh Enclosure gnature/// Ti tl e ~ m No. 4,0404 ,V. 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. AP! NUMERICAL CODE 50-029-20304 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME Atlantic Richfield Company West Bay State 3. ADDRESS OF OPERATOR 9. WELL NO. P. 0. Box 360, Anchorage, Alaska 99510 1 4. LOCATION OF WELL 2500'FNL & 2500'FWL Sec. 1, TllN, R14E, UM 10. FIELD AND POOL, OR WILDCAT Wildcat 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 1, TllN, R14E, UM 12. PERMIT NO. 78-30 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. See Attachment. 14. I hereby th;~going~ig)true and correct S,GNED T,TLEDistrict Drilling EngineerDATE NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month.unless otherwise directed. Report of Operations for the Month of September, Punped 2000 gal diesel w/10% U-66. Used 120 1.3 SG balls Dis~i~d~8~F~'' ~' ~'~ ~ ''~ Did not get ball out. Pumped 4500 gal 28% HCL Used 95 ~.3 SC balls. D'tsPt.'~/diesel @ 4 bbl/min. Did not get ball out. Tstd BOPE. RIH w/Amerada HP temp sur. Opened well. Pres dropped from 1300 psi surf pres to 900 psi. Rec 93 bbl diesel & acid wtr. Well started making gas. Turned to flare pit. At 0530 9-1-78 bot hole pres 3777, tbg pres 1071 1/2" choke, 2578 BOPD, GOR 611. Flowed well for 6 hrs. on 1/2" choke. Flowed well for 12 hrs. on 3/4" choke. Had severe foaming problem in separator. POH w/HP. Had to rehead line. While doing .so, RU to inject defoamer in line. At 0100 hrs. 9-2-78 on 3/4" choke 2587 BOPB, 2.7 MCFD, GOR 1045. Flowed well on 1" choke. At 0530 9-3-78 bot hole pres 3326, tbg pres 880, choke size 1", bbl/day - 2961, 1.9 MCFD, GOR 671, 27.4 gvty oil @ 60°. Flowed well on 1" choke to 1100 hrs. 9-3-78' Shut in well for pres buildup from 900 psi.' surf pres to 1625. Bot hole pres from 3215 - 3837' Final flow was 3026 bbl/day, 2.3 MCFD, GOR 771. Completed shut in @ 2300 hrs. 9-~-78. Bot hole pres 4052#. Flowed well 3/4 hrs. Shut in well for 2 hr buildup. POH w/^merada HP.rec. Took wireline fluid samples. Pumped 60 bbl 10.3 Hi-Vis Lost-Circ kill pill. Tbg pres bled to O. Opened bypass. Lost 14 bbl fluid in ann, 10 bbl fluid in tbg. Closed tool. Mixed 2nd kill pill. Displ kill pill to perfs. Opened bypass. Fluid dropped in ann slowly, I bbl/every 3 min. Mixed 3rd kill pill. Pumped 71 bbl 10.3 Hi' Vis kill pill, 3 bbl/min. Opened bypass. Had good returns up ann. Closed bypass. Pumped pill into form @ 1-1/2 bbl/min. Pumped total 76 bbl pill in form. Waited on pill for 3 hrs. Opened bypass. Hole taking fluid I bbl every 4 min. Circ down tbg, up bypass. Lost total 39 bbl in 3- 1/2 hrs. Pull pkr loose. Lost add 24 bbl. Lost hole for I hr. Lost add 7 bbl. POH w/tbg. RU Schl. RIH w/Howco EZ drl bridge plug. Set @ 8795'~ PU tailpipe, Amerada bombs. TIH w/3-1/2" tbg & RTTS. Pumped 2 volumes of CaC12 down tbg & around pkr. Tstd csg to 1500#, OK. Set pkr @ 836'9' Tstd 'on ann w/2000 psi, OK. Opened bypass. Displ tbg w/73 bbl warm diesel Tst~ lub to 5000 psi', OK. RIH w/gun #1. Perf 8721 - 8745', OK. Perf gun #2 8697 - 8721', OK. Established injection rate of 4 bbl/min, 3300# w/1800 bbl diesel. Pumped 2000 gal diesel w/10% U-66. Dropped90 1.3 SG balls. Pumped @ 4 bbl/min 3100 psi. Displ w/83 bbl diesel. Had good ball action. Maintained 4 bbl/min during displ. Final pres 6400 psi. Pumped 4000 gal 28% HCL. Dropped 83 1.1 SG balls & displ 4 bbl/min 2900 psi. Final pres 4 bbl/min, 3500 psi. Surge balls off perfs. RIH w/temp HP Amerada bombs. Opened well to flow. Shut in well. POH w/bad HP tool. Opened well baCk up on 1" choke. 0530 hrs. 9-10-78 bot hole pres 3489, tbg pres 850, 1" choke, 3350 BOPD, 2.9 MCFD, 870 GOR. Flowed well until 1000 hrs. 9-10-78. Shut in well for pres buildup. 0230 hrs. 9-12-78 shut in bot hole pres 4080, shut in tbg pres 1932. Well remained shut in until 0430 hrs. RIH w/fluid sampler. Took sample @ 8680'. Made up sampler #2. Took sample #2 @ 8680'. Made up sample #3. Again sampled @ 8680'. Made up gun #1. Tstd lub. Perf'd 8,628 - 8639'. POH. Gun had misfired. PU gun #2. ~ Perf'd 8616 -8639'. Gun #3 perf d 8606 - 8616', 8595 - 8606'. PU gQn #4. Perf'd 8571 - 8595'. PU gun #5. Fired 8560- 8571'. Flowed well I hr on 1/2" chOke Flowing tbg pres 1225 psi 1/2" choke, 2630 bbl/day, GOR 798, Oil gvty 27.60. Gas ~vty 0.782. RU'to kill well. Pumped 1st pill. Well cont to take fluid. Pumped 2nd lost circ pill. Cont taking fluid. Pumped 3rd pill. Well killed. Opened bypass. Rev circ capacity of tbgs. Lost 70 bbl of mud. Released tool. POH. Lost 80 bbl while POH. LD tst tools. RIH w/junk bskt to 8688'. RIH w/Howco EZ drl. Bridge plug set @ 8675'. PU 2-7/8" tailpipe, 7" tst tools. TIH w/3-1/2" tbg & tst tools. RU tst manifold. RU to acidize. Heated acid. Displ tbg w/diesel. Set pkr. Pres ann to 2000 psi. Pumped 90 bbl of diesel U-66 mix; Drop 142 1.3 SG balls. Displ w/78 bbl diesel. Had good balling action. Pumped 6200 gal. 28% HCL using 160 1.3 SG balls. Displ w/diesel. COUB m L Report of Operations for the Month of September, 1978 Page 2 Maximum treating pres 7000 psi. Final pres 3900 psi. Ran temp sur. RIH to 8550'. F1 owed well. Shut in well for buildup. Pumped in 88 bbl hi vis kill pill, 9.8 ppg. Shut well in. Letting pill soak. Opened bypass. Fluid dropped. Closed bypass. Took 27 bbl to fill ann. Pumped 100 bbl 10.2# hi vis pill. Opened bypass. Lost 36 bbl. Closed bypass. Pumped 150 bbl 9.8 ppg hi vis pill. Shut in well. Let pill soak. Unseat pkr. Start out of hole. Losing fluid very slowly. POH w/tbg. RD tools. PU BHA & TIH w/3-1/2" DP. Cond CaC12 @ 8678'. Hole taking fluid, approx 30 bbl/hr. Pulled I std. Pumped 150'bbl hi vis pill. Hole taking fluid @ 6/bbl/hr rate w/mud static. Drld ret @ 8692'. Losing 12 bbl/hr of CaCl2 to form. Circ & cond mud @ 8794 while adding Dril-S, safe seal additives to CaC12. Presently losing 15~'bbl/hr CaC12. Drld ret @ 8794'. Pushed to 8810' Losing 50 bbl/hr fluid, mixed 142 bbl hi vis pill, Spotted same in place. TOH fo~ 'new bit. TIH w/bit. Drld ret 8959'. CO hole to 9014' Cond & circ mud. PU 7" & 9-5/8" csg scrapers. TIH. Circ bot up. Losing approx 6~ bbl/hr to form. Pumped'~100 bbl hi vis pill. TOH w/RTTS. LD scrapers. TIH w/RTTS. Set pkr @ 2525'. Closed rams. Tstd 9-5/8" to 3000# on csg DP ann. POH. LD RTTS tools & DC's. RIH w/7" 29# gauge ring to 8970'. Ran Baker 7" 29# F-1 production pkr on wireline. Set @ 8790'. Made up 2-7/8" BHA below Baker 7" FB-1 pkr. Tagged F-1 pkr w/stinger.in DP PU & pumped 50 bb! CaC12 to insure tbg clear. Stab into F-1 pkr w/seals. Dropped 1-7/8" setting ball. Set FV-1 pkr @ 8675' w/4000 psi. Sheared"tension studs. Increased 'tbg pres to 5500# & sheared ball. TOH. LDDP. Started 3-1/2" compl assy, 'PU Baker AL-5 dual 9-5/8" production pkr~ Sperry Sun bottom hole pres'monitor, 3-1/2" tbg. Started in hole w/compl assy. Installed BV nipple & gas lift mandrels. Installed 1/4" line on BV & tstd same to 5000 psi. Install Sperry Sun .094 hollow' line on'short string side of pkr. Spaced out tbg. PU OCT 3-1/2" tbg hanger. Install 1/4" control line on 1 side of tbg hgr Sperry Sun .094 sensor line in other connection on tbg hgr, Pres tstd control line to 5000 psi. Checked out Sperry Sun-line, OK. Circ 75 bbl CaC!2 down tbg. Drained & washed out BOP stack, Landed 3-1/2" tbg. Installed service connection to control line of Sperry Sun sensor line. Tstd same to 5000 psi. Installed BPV. ND BOP's. NU Xmas tree. Pull BPV. Set tree, tst plug, Tstd tree to 5000 psi, OK. Pulled tst plug. Pulled dummy valve. Dropped ball & set AL-5 pkr, Opened sliding sleeve. Reran dummy valve. Flowed well. Pulled dummy valve. Closed sliding sleeve. As of Sept. 30 flowing well on 1/2" choke. AtlanticRi'chfie[dCompany North American Producing Division North Alas~ ' District Post Offic~ ~x 360 Anchorage, Alaska S95t0 Telephone 907 277 5637 September 18, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' West Bay State #1 .Permit No. 78-30 Dear Sir- Enclosed please find the Monthly Report of Drilling Operations for the above-mentioned well. We consider this hole extremely tight and would appreciate your cooperation in placing this report in secured storage where it will receive minimum exposure. Please acknowledge receipt of the attached report by returning one signed copy of this letter for our files. Thank you for your attention in this matter. Very truly yours, F. M. Brown District Drilling Engineer FMB:mln Enclosures Title Date Form No. P--4 REV, 3,-I-7'0 STATE Or- ALASKA OIL AND GAS CONSERVATION COMMIT'tEE SUBMIT IN DUPLICATE MONTHLY REPORT O'F DRILLING AND WORKOVER OPERATIONS ~ API NUA{ERICAL CODE 50-029-20304 6 LEASE DESIGNATION AND SElqIAL NO ADL 28302 7 IF INDIA~,~. AL,OTTEE OR TRIBE NAME 1. OIL ~ GAS ~ OTHEB WELL WELL 2. NAME OF OP~:~ATOR Atlantic Richfield Compan7 3. ADDRESS OF OPEI~ATOR P.O. Box 360, Anchorage, AK 4. LOCATION OF WELL 2500' 8. L~.'IT FAHA{ OR LEASE NAME 99510 FNL & 2500' FWL Sec l, TllN, R14E, UM West BaS State 9 WELL NO 10 FIELD A.'qD POOL, OR %VILDCAT Wildcat I1 SEC.. T., R., 1%~.. (BO'I'TOM HOLE om,rEcrrvE) Sec l, TllN, R14E, UM 12. Pglt.lVlIT NO 78-30 13. REPORT TOTAL DKPTH AT END OF MONTH. CHANGES IN HOLE SIZE. CASING AND C~-ME, NTING JOBS INCLUDING DEPTH SET ANI) VOLLrMES USED. PERFORATIONS. X'ESTS A.N-D RESULTS FISHING JOBS JUNK LN HOLEAND SIDE-TI{ACKED HOLE A/~D ANY OTHER SIGNIFICANT CH.A.N~ES IN HOL~ CONDITIONS. SEE ATTACHED !~ivislon ~,1 0il and Gas bo~servali(~n Anchorao, r~ s~omm ,_.. ,~ ~- :~-~District Drilling EngineerD^~.. Y NOTE--Report on this form is required for each calendar month% regardless of the status of operations, and must ~ flied In duplicate with the oil and gas conservation commiHee by the 15~ of the succ~ding mon~, unle~ otherwise directed, REPORT OF OPERATIONS FOR THE MONTH OF AUGUST, 1978 ;;]vir~ion ct Oil and Gas Cen~ervation Ran dipmeter. Displ oil faze mud w/wtr base mud. Drld to 10,383'..~¢?m,~,~-~,~¢ Ran DIL/SP/6R, BHC/Sonic/6R, FDC/CNL/CAL/6R. Ran proximity microlog. Ran velocity survey. RU & ran 54 jts 7" 29¢ N-80 Butt lnr. Pumped 30 bbl wtr ahead of 20 bbl 6W-7 mix. Mixed 450 sx Class 6, slurw 15.8 ppg. Displ w/220 bbl mud. Tagged top of lnr O 8203'. Tstd csg to 2500 psi, OK. PU 9-5/8" tst tool. Ran 3700' wtr cushion. Set pkr O 8150'. Had weak blow for 10 min. Well dead remaining 1 hr. 50 min. Closed tool. Rev out wtr cushion. Ran CBL/VDL/6R/CCL. Displ w/lO.3 6aCl2 wtr. Ran temp sur. RU & ran 3-1/2" 9.3¢ CSCB tbg. Set pkr O 9648' w/tailpipe e 9773.,. Displ tbg w/diesel. PertLd 9904-9914', 9884-9904' Flowed~st rate 80-100 bb~d,¢.¢y. ~6 fluid sampler. Rev out tbg ~fter tst. PU 5 jts. Rev out below perfs. Ran junk bskt & gauge ring to 10,000'. Ran 7" EZ drl cmt ret. Set O 9844' POH. Pull wear ring. Set tst plug. Tst 5" rams to 5000 psi, OK. ~U ret. Trip over DP. Stabbed into ret. Tst lines to 5000 psi, OK. Broke down form O 1600 psi. Injected 4 bbl/min to 2500 psi. Pumped 40 bbl fresh wtr ahead of 100 sx Class G cmt. Final shut in pres 2800 psi. Release pres from DP ann. PO of stinger. Rev out DP. TIH w/3-1/2" tbg & tst assy. Tstd lines 5000 psi. Displ tbg w/81 bbl diesel. Set pkr. Perf'd 9761-9769'. POH. No flow Perf'd 9704-9722'. No flow. Perf'd 9678-9696' No flow. POH. ~stablished injection rate 25 bbl diesel to 4.5 bbl)min O 3800 psi. Pumped 2250 gal diesel w/lO% free flow EB mutual solvent. Start injecting ball sealers after bO0 gal. Balled out w/same. Final pres 7000 psi. Shut in for 30 min. Pres bled to 2500 psi. Surge bal'ls off perfs. Shut in for 30 min. Pumped additional 45 bbl diesel. Pumped 2800 gal of 28% HCL. Pump started losing suction. Switched to diesel. Displ acid to perfs w/diesel; Final rate 3.5 bbl/min 3500 psi. Instant shut-in, 3100 psi. 30 min shut-in 2700 psi. Surge balls off perfs. Shut in well. Ran temp log. Positioned HP for tst. Open well for flow. Turned well to burn pit. Well shut in. 900 psi buildup. Warmed acid & diesel. Tstd lines to 8000¢, OK. Establish injection rate, 4 bbl/min, 3500 psi, OK. Pump 5000. gal 28% NCL usi.ng 71.3 SG balls. Maximum pres 7000 psi. Surge balls off perf. RU Schl. RIH w/HP & Amerada bombs. Tool failed. Chg tool. RIH. Open well to flow. Pres fell from 1700 psi to O. Bot hole pres' dropped from 5100 to 4000 psi. Flowed well. Made approx. 17! bbl in 24 hr. 'Ran gradient sur. FlOwed well on 1/4" choke. Well ~.' 'R~'~"b'6'~(~"~i~'~ sampler. SI well for pres buildup. Kill well. Pump 60 bbl 10.3 high vis pill. Displ pill to perf. Bled off pres to O. RU, rev out tbg. Unseat pkr. POH w/same. RIH & set Howco EZ drl SV bridge plug O 9638'. POH. Closed rams & tstd csg to 3000~, OK. Install tst Pl'ug. Tstd Hydril to 3000~, 3-1/2 pipe rams to 5000~. Cut drl line. Ma'king up surf equip for tst 3. Ran tbg to 8982'. Set pkr. Tstd same to 2500~ on backside. Opened by-paSs.. Displ tbg w/75 bbl warm diesel. Close by-pass. R!H. Perf'd 9100-9076'. NO flow. Gun ~2, perf'd 9076-9070', no flow. Perf'd 9066-9054', no flow. Perf'd 9046-9034', w/gun ~3, no flow. RIH w/HP. Opened well to flow. Well would not flow. RU to acidize. Injection rate w/diesel 4.5 bbl/min, 2700~. Pumped diesel mutual solvent mixture @ 50 gal/perf ft. Dropped 81.3 SG balls. Had pres increase to 6100 psi breaking back to 5100 psi. Surge balls off perf. Pumped 3500 gal 28% HCL dropping 61.3 SG balls. Maximum treating pres 4700 psi. Displ w/diesel to perf. Surge balls off perfs. RIH w/HP & Amerada bombs 'w/temp tool. Flowed well thru 1/2" choke. Surf declined from 1750 psi to 80 psi. Produced total of 410 bbl Total fluid injected into zone 390 bbl. Final proa-u'c~~~u~6-~4'.5 API gravity. Shut in well for pres buildup. RU to kill well. Pumped 60 bbl high vis pill followed by clean CaC12. Check for flow. No flow. Unseated pkr. Rev out hole. POH w/tbg. Install 5" rams & tst same. Ran junk bskt to 9020'. RU & ran EZ drl bridge plug. Set @ 9000'. Tst Csg to 3000#, OK. Ran 4" csg gun & perf'd 4 shots/ft. 8800-8802'. PU EZ drl ret @ setting tool on DP. RIH. Set same @ 8727'. Pumped in form @ 3 bbl/min 3200#~ Pumped 25 bbl fresh wtr followed by 200 sx Class G w/l% CFR2 & 0.15% HR7 followed by 15 bbl wtr followed by 70 bbl CaC1 Placed 15 bbl wtr outside tool Stung into ret. Placed 185 sx -cm~ ~low ret. Maximum pres 2800 psi ~ 1 bbl/min. Rev out 15 sx. POH. RIH w/4" csg gun. Perf'd 8684-8686', 4 shots/ft. PU 7" EZ drl & setting tool & TIH w/DP. Set @ 8600' Tstd EZ drl on outside of DP to 2000 psi, OK. BrOke down form w/4~O0 psi. Injected 2-1/2 bbl/min, 3800 psi. Spotted 25 bbl wtr followed by 200 sx Class G w/l% CFR2 & .1% HR7 followed by 15 bbl wtr, 68 bbl CaC12. Pumped 170 sx cmt into perfs leaving 15 sx above perfs below ret. Rev out 15 sx. Max final pres 2500 psi. Unstung from EZ drl. Rev out DP. POH. LD 22 jts 3-1/2" DP. Drld EZ drl & cmt to 8699'. Drld EZ drl @ 8727,. Drld cmt to 8817'. Circ & CO on top of bri.dge pl~ug @ 9000'.,,5 POH. PU 7" Csg scraper. TIH. Circ bot up. POH. Set tst plug. Chg rams to 3-1/2"' rams. Tstd Hydril to 3000#, 2 sets of 3-1/2" rams to 5000#, OK. PU 2-7/8" tailpipe & BHA. TIH. PU tst head. Tstd all valves to 6000#, OK. Hooked up pump lines. Circ 150 bbl CaC12 down tbg, OK. Set RTTS @ 8611' Opened bypass. Displ tbg w/73 bbl warm di~eSel. Pump thru & tstd ail tst lines to 2000#, OK. As of August 31, perf'd 8834-8856' w/1 shot/ft. Perf'd 8890-8902' & 8810-88'22'. POH. RU for acid job. AFter perf, no surf pres. Prep to pump diesel flUsh' AflanticRlchfieidCompany .... Nodh Ameri~-~n Producing Division North AI~$J JsJric~ Po~'i Office Box 360 Anchorage, A~ask~ 995~0 Telephone 907 ~77 5637 August 14, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: West Bay State #1 Permit No. 78-30 Dear Sir: Enclosed please find the Monthly Report of Drilling Operations for the above-mentioned well. We consider this hole extremely tight and would appreciate your cooperation in placing this report in secured storage where it will receive minimum exposure. Please acknowledge receipt of the attached report by returning one signed copy of this letter for our files. Thank you for your attention in this matter. Very trnly yours, :~/~_~ Frank M. Brown District Drilling Engineer FMB ir Enclosure ' /" Signature Date Title Form N*o, P--4 STATE Or ALASKA SUBMIT IN DUPLICA'I'E OIL. AND GAS CONSERVATION COMMITTEE MONTHLY RE!PORT O'F DRILLING AND WORKOVER OPERATIONS WKLL WELL OTHEI~ 2. NAME OF OPERATOR Atlantic Richfield Company 3..~DDRESS OF OPERATOR P. O. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL 2500'FNL & 2500'FWL Sec. 1, TllN, R14E, OM APl NU~{ER1CAL '~ODE 50-029-20304 LEASE DESIGNATION AND SERIAL NO. ADL 28302 ?. IF INDIAI4', ALOT1-F.E OH TRIBE NAME 8. L.~IT,F.~'-,~I OR LEASE NAME West Bay State 9. WELL NO 10, FIELD A_NDPOOL, OR WILDCAT Wildcat 11. Sl~.C., T., R., M.. {BO"I'TOM HOI~E Sec. 1, 111~, R14[, U~ 12. PEP. MIT NO. 78-30 13. REPORT TOTAL DEPTH AT END OF MONTH, CH~'N'GES IN HOLE SIZE. CASING AND CEMENTING JOBS INCLUDING DEPTH SET AlXq~ VOLIJqVIE'$ USED, P~ORATIONS, TESTS ANT) H_ESULTS. FISHING JOB~. JU-NK LN HOLE A. ND SIDE-TR3%CKED HOLE AffCD ANY OTHER SIGNIFICANT CHANGES IN HOLI~ CONDITIONS. Report of Operations for the Month of July, 1978 Ran 9-5/8" csg w/shoe @ 8523'. Cmtd w/lO00 sx Class G cmt w/1% CFR-2 & HR-7. Tstd FO's. Did Arctic Pack job. Drld FC &cmt to 8508'. Ran CBL & velocity survey. Displ mud w/wtr. Displ wtr w/10.3 oil phase mud. Drld shoe & 10' new form. Tstd to 12.'5 equiv. Drld to 8595' PU core bbl Core #1, 8595'-8652' ' ' . , rec 60 ; core #2, 8652'-8712', rec 58.5 ; core ~3, 8712'-8773' ' , rec 58 ; core #4, 8773'-8833' ' , rec 60 PU drlg BHA, drld to 9453'. PU core bbl. Core #5, 9453'-9513', rec 59'. PU drlg BHA, d~ld to 9707'. PU core bbl. Core #6, 9707'-9766', rec 59'. Ran FDC/CNL/GR/Caliper & GR/SP/DIL. RIH w/core bbl. Core #7, 9766'-9806', rec 40'. RIH w/tst tools & press recorder. Opened tool w/slight blow. Closed tools for build up press. POH w/tst tools. RIH w/core bbl. Core #8, 9806'-9865', rec 59'; core #9, 9865'-9923', rec 60'. As of July 31, ran GR/FDC/CNL & GR/BHCS logs. CONFiDENTI , ; ,,, ~1s'tRII~UTEI) %T>,TI'~ OF ALASKA Di\;'ISiON OF OIL & C, 14. I hereby certj,~v ~.IN~ :fPrt~'~'~m~.~i~-trl, l'~and correct ".. s,e~¢~ ~~/z~--~~ D~strict Drill~,9 Engine~, _. NOTE --Report on this form il required for each calendar ~nth$ regardless of the .lotus of operations, and must ~ flied 'In duplicate with th I oil and gQ. conservation commiflee by the i5~ of the succ~ding mon~, unle~ otherwise directed. A~?:~r~ticRi~:', ~!ietdCornpany No;th Amen_an Producing Division No~h A!a-: 3istrict Post Oifice box 380 Anchorage, Alaska 995!3 Telephone 907 277 5637 July 14, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Division of Oil and Gas 3001 porcupine Drive Anchorage, Alaska 99501 Resources Subject: West Bay State #1 Permit No. 78-30 C. ,C4E OL -- 'C. F. Nq¢ ...... .......... .......... .......... . ,.: ;-%.; , .. -..~ . ...,. . __ .... ' "D L'a:'r Enclosed please find the Monthly Report of Drilling Operatfo-h~ for the above mentioned well. We consider this hole extremely tight and would appreciate your cooperation in placing this report in secured storage where it will receive minimum exposure. Please acknowledge receipt of the attached report by returning one signed copy of this letter for our files. Thank you for your attention in this matter. Very truly yours, Frank I'4. Brown District Drilling Engineer cks Enclosures Si gnature CONFIDENTIAL ~. tt.~/Tl~l BL~ED ~;! :~,~ E. OF D~V~(~N: OF OIL Date AflanficRichfieldCompany -- North Amed.~q Producing Division North Alask ~strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 July 14, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 POrcupine Drive Anchorage, Alaska 99501 Subject- West Bay State #1 Permit No. 78-30 Enclosed please find the Monthly Report of Drilling Operations for the above mentioned well. We consider this hole extremely tight and would appreciate your cooperation in placing this report in secured storage where it will receive minimum exposure. Please acknowledge receipt of the attached report by returning one signed copy of this letter for our files. Thank you for your attention in this matter. Very truly yours, Frank M. Brown District Drilling Engineer cks Enclosures '::/' ~ ~;;;8'i gnat,re 'Date Title STATE OF ALASKA SUBMIT I~ DU'PLICA.'~J: OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS CODE 50-029-20304 6 LEASE DESIG~A"FION AND SERIAL NO. ADL 28302 1, 7. IF INDIA~, AiXD3 ! l~k. OR TRIBE NAME 0,L ~X] oas 2. N~E OF OP~TOR 8. L~IT,F.~ OR LEASE At]ant~c R~chf~e]d Company West Bay State ~RESS OF OPhiR 9. WE~ NO P.0. Box 360, Anchocage AK 995]0 4. LOCA~ON OF W~ 10. FIE~ ~ND P~L. OR WILDCAT 2500' FNL & 2500' FWL, Sec l, TllN, R14E, UM Wildcat I1. SEC., T., R., M.. (BO'I~I'OM HOI~E Sec l, TllN, R14E, UM 12, P]~,.MIT NO. 78-30 ~3. REPORT TOTAL DI~TH AT END OF MONTH, CHA?¢GES IN HOLE SIZE, CASING AND CI2LYZENTING JOBS INCLUDING DEPTH SET AN'I) VOLUqVI~-g~ USED, P~ORATIONS, ~TS .A/qqD iqJgSULTS. FISHING JOEUS. JUNK LN HOL~E AiqD SIDE-TRACKED HOLE AND A. NY OTHER SIGNIFICANT OFiA. NG~ IN HOL]~ CONIDITIONS. REPORT OF OPERATIONS FOR THE MONTH OF JUNE, 1978 Spudded well @ 0230 hrs 6/18/78. NU diverter system & annul preventer. Drld to 2760'. RU & ran 13-3/8" csg w/shoe @ 2738. Cmtd w/4300 sx Permafrost II cmt. Drld to 2770. Tstd form to 12.5 ppg equiv. Drld to 8536'. Ran DIL/BHCS/FDC/GR/Caliper. Ran sidewall core. As of June 30, preparing to run 9-5/8" csg. ce that th egotng is true and correct District Drilling Engr. DA~E July 14, 1978 NOTE --Re'art on this form is required for each calendar month~ regardless of Ihs Status of operations, and must be filed In duplicate with th · oil end gas conservation committee by the 15th of the succeeding month, unle~ otherwise directed. lcn of Oil and C~s Con~~ O. K. Gilbreth, Jr.. m~/~ June 23, 1978 D/rector Hoyle H. t~3miltmn '~~'~/J C%Jef Petroleum Engineer Harold R. Ha~ ~ / Petl~leum Inspector'S½{~ BOP Test, ~ West Bay State No. 1 ~c. 1, T1]~L R14E, Peri,it 'No. 78-30 y, June 19, 1978 - I left my house at 4:45 PM for a check in at Mr A~ 5 :iS PM for a flight to Prudhoe at 6:15 PM. Purpose of trip to witness BOP test. I left Anchorage by Wien Air and arrived in Prudhoe at 8:45 PM and arrived at West Bay State NO. 1 at 9:45 PM. I m~t Tony Zieto, supervisor for Arco. Cementing of the 13 3/8 ~arface pipe had just started. ~sday, June 20, 1978 - Nippling up of BOP's in progress. ~tne~y, JUn~ 21, 1~978_ - BOP test started at 1:30 AM and f/nished ~ 7:30 A~4. Belc~ are the results. Test plug was set in casinghead and annular preventer ~ms tested first to 3000 psi. The top pipe rams were tested next with the inside kill valve and inside choke valve closed to 5000 psi. The bottom pipe rams ~ tested next to 5000 psi. The test stem ~ms pulled and the blind rams~ ~ outside choke~~ ~n HCR valve and. outside kill valve w~_re teste~ to 5000 psi. With the blind rams still closed, seven valves a%~y frc~ sta~k in cellar tested to 5000 psi. One of these valves failed and has to be r~paired. There were 7 valves and 22 flanges, c~e positive and c~e manual choke, plus a Swaco superchoke cn manifold. C~e valve c~ manifold failed ~ 5000 psi test and has to be r~paired. The c~ck valve on kill line also tested to 5000 psi. The ~ and lower kelly both te~ to 5000 psi. There was also a dart valve and a drill ~ safety ball valve on floor OK. The accu~3!_~tor master gauge read 3000 psi, the manifold pressure was 1500 psi. There w~re six nitrogen backup bottles with 2400, 2400, 2200, 2400, 2300 and 2300 psi each. The location was free of debris. The mud pit was open but %~11 ~. ~ was no well sign on location. Bo~h master and remote c~ntrols .cpera~ satisfactorily. In s~_: I witnessed the test c~ the blowout _equipment for Arco on West Bay State No. 1, plus checking out accumulator. Tests were satisfactory except for c~e valve on manifold and cne val%~ in cellar failing, plus no well sign. Arco is to call our office within ~ days on repairs. A~t 6/22/78 T~ny Zieto, Arco supervisor ~n West Bay State No. 1, called at 9:20 AM.. Both valves were rep,~_ired m~ tested to 5000 psi and well sign with all v~ll data installed on rig. Drlg. Permit Opera tor~ p?/:~ ..... Satisfactory Type Inspection Yes No Item (/~ Location,General ( ) (~ lo Well Sign ~) () (.x,) () (>~ () () () () () ) () ) () ) () ) () 2. General Housekeepin.Q ~. Reserve Pit-(A)open( )filled 4. Rig ( ) Safety Valve Tests 5. Surface-No. Wells 6. Subsurface-No. Wells ( ) Well Test Data 7. Well Nos.~_, , , 8. Hrs. obser , , , 9. BS&W , , , 10. Gr. Bbls. ( ) Final Abandonment AI~ a Oil and Gas Conservation Commi e Field Inspection Report We 1 l / P 1 a t fm Se c`/___T//j~__~_R_/_~//~? M Represented Satisfactory Type Inspection Yes No Item (~ BOPE Tests ~') ( ) ~5 ~C~-' ?~L fl~id-~)wt~:-(' )m~d ( ) ~il ~x) () ~) () (~')( ) ~) () (:~)() (X) () (>:)( ) (x) () (~')() (~')() ~) () 16 17 18 19 20 21 Master H.yd. Control Sys.- psiQ Remote Controls Drilling spool- ~iZ"outlets Kill Line-~.') Check valve 22 Choke F1 owline ~) HCR valve 23. Choke Manifold No valvs$7_ flgs~ 24. Chokes-(~')Remote (,~)Pos. 25. Test Plu~-(D()Wellhd( )csq( )none 26. Annular Preventer.~?~psiQ (~') ( ) 27. Blind Rams~_-~z~>_ps~m ) ( ) l l. P&A Marker (~X) ( ) 28. Pipe Rams ~m/,'psiq ) ( ) 12. Water well-( )capped( )plugged (m~) ( ) 29. Kelly & Kelly-cock 9%m,~' psig ) ( ) 13. Clean-up (~) ( ) 30. Lower Kelly valve~?m~,psio ( ) ( ) 1~. Pad leveled (A) ( ) 31 Safety Floor valve~BV (~)Dart Total inspection observation time__~ hrs/days Total number leaks and/or equip, failures .... ~ ..... ~marks_/ ~)A~~ E jj, ~~~x,.~ ~/A~',m_,A ~L~ ~~Z.-j~T,/.4z~_~ .... cc: ~:X=__~:x=%' :otify in ~:ays or when read.y Inspected bypath::/,::: .... Date:~/:: Jur~ 7, 1978 mst ~ State No. 1 Atlan~-ic Richfield ~~ny P~nit ~. 78-30 F. M. Brown District Drilling Enm~ineer P. O. ~ 360 Anchorage~., Alaska 99510 Sir: Enclosed is ~ app~ ~licaticn for pennit %o drill th~ ~ referenc~t ~1 at a locatic~ in ~ 32, Township 10N, Range 19E, U.M. Well samples, core c~hips, ~ a hud log are ..required. A directional is not r mir . b~ny ri~s in Alaska ~ their drainage s~m~ have been classified as /mpo~t ~ ~ spaw~/ng or migra~cn of ana~ fish. Operations J~n ~se ~ are subj~ to AS 16.50.870 and the regulations ~gated th~/eunf~r (Title 5, Alaska Adm/n/strative Code). Prior to ~ing operatic~s you may be ccntac~ by the Habitat Coor~tor's offioe, Departn~nt of Fish ~ ~. Polluti~ of any waters of ~he State is prohibited by AS 46, Chapter 03, Article 7 ~ ~ r~Tulaticns prc,m~gated there~ (Title 18, Alaska Adm/anistrati~ ~, ~ 70) ~ by the Federal Water Pollutic~ Control ~, as ~. Prior to ~ing operations you may be con~ ~ a representative of ~ De~t of Env~tal Cc~~a~. Pursuant to ~ 38.40, ~ F~ire L~nder State Leases, the Alaska De~t of Labor is ~ notified of the issuance of this permit to drill. To aid us in sche~ field %Drk, w~ ~ appreciate your notifying this office with/n 48 ~ a~ ~ well is spudded. We w~uld also like to be notified ~ that a re4u~esentative of the Division may be present to witness testing of blc~out prexn~l"~r equ/~l~nt before surface casing shoe is drilled. F. M. Brown -2- W. Bay S%o #1 June 7, 1978 In thee vent of ~ic~orabandonmsnt please give this offioe adequate a~notificaticnsothat~mayha~a witnesspresent. Very t~aly yours, O. Ko Gilbre~h, Jr. ~part~nt of Fish and Gam~, Habitat Sectic~ ~/o encl. Department of ~tal CcF~_rva~ w/o encl. Division %~/o encl. ~tlanticRichfieidCompany North Arneri~-~ Producing Division North Alask, ,strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 June 5, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subj~ect- West Bay State #1 Dear Si r' Enclosed find our Sundry Notice to add a surface diverter system to our 20" BOPE assemblY~ This system is shown on attached drawing. Very truly yours, Frank M. Brown District Drilling Engineer FMB' j h Enclosures Fc,~;n 10-403 REV~. 1-10,.73 Submit "Intentions" In Triplicate & "Subsequent Reports" In Duplicate STATE OF ALASKA OIL AND GAS cONSERVATION COMMITTEE .. SUNDRY NOTICES AND REPORTS ON WELLS (Do not u~e th[~ -r..'- .~ f~,.r proposals to drill or to deepen Use "APPLICA"I iO,~ POP. PERMIT--" for such proposals.) WELLGAS E~ OTHER NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. O. Box 360, Anchorage, AK 4. LOCATION OF WELL At surface 2500'FNL, 2500'FWL, Sec. Vertical Hole 99510 1, T11N, R14E, 13. ELEVATIONS (Show whether DF, RT, GR, etc.) Approx. 25' G.L. 14. Check Appropriate Box To Indicate Nature of Notice, Re 5, APl NUMERICAL CODE 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME West Bay State 9, WELL NO, 1 10. FIELD AND POOL, OR WILDCAT Wildcat 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec ~32, .T~'' ~- 12. PERMIT NO. )orr, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF Li._J FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE= Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state ell pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. A surface diverter system as described on attached drawing will be installed in 20" BOPE hookup. JUN - 6 i9/8 16. I hereby ce~ that the foregoing is ~.{~ and correct TITLE District Drilling Engineer DATE 6/5/78 CONDITIONS I~APPROVAL, IF ANY; TITLE See Instructions On Reverse Side Approved Copy 6" To Sump .. SURF \CE DI.VERTER SYSTEg 1. 20" Bradenhead 2. 20" 2000 psi drilling spool 3. 20" 2000 psi annular .prevente 4. 6" butterfly valves 6" To Sump Drlg. Per'mi~No. Operator~ Ali ~a Oil and Gas Conservation Commi' e Field Inspection Report ~ ?~4/~? Wel 1/~ Sec T R Represented by ~/~,-..=. Name &Number z~,~ ;~-_ Satisfactory Yes () () () () (~ (~ () () () () () Type Inspection No Item ( ) Location,General ) lo Well Sign ) 2. General Housekeepinm ~ ~.. Reserve Pit-( )open( )filled ) 4. Rig (~)~Safety Valve Tests ) 5. Surface-No. Wells_/ ) 6. Subsurface-No. Wells ( ) Well Test Data ) 7. Well Nos. , , , ) 8. Hrs. obser , , , ) 9. BS~W , , , ) 10. Gr. Bbls. , , , ( ) Final Abandonment ) llo P&A Marker Satisfactory Type Inspection Yes No Item ( ) BOPE Tests ( ) ( ) 15 ( ) ( ) 16 ( ) ( ) 17 ( ) ( ) 18 ( ) ( ) 19 ( ) ( ) 20 ( ) ( ) 21 () ( ) 22 ( ) ( ) 23 () ( ) 24 () () 25 ( ) ( ) 26 ( ) ( ) 27 ( ) ( ) 28 "Casinq set ~a TesL fluid-( )wt'~--(' )mud ( ) oil Master Hyd. Control Sys.- psig ~!2 btls .... psig Remote C~ntrols Drilling spool- "outlets Kill Line-( ) Check valve Choke Flowline ( ) HCR valve Choke Manifold No. valvs flms Chokes.-( )Remote( )Pos.('-~-~'-dj. Test Plue-( )Wellhd( )CSQ( )none Annular Preventer,_ .... ?siQ Blind Rams, psim Pipe Rams .... psiq ( ) ) t~. Water well-( )capped( )plugged ( ) ( ) 29 ( ) ) 13. Clean-up ( ) ( ) 30 ( ) ) 14. Pad leveled ( ) ( ) 31 Total inspection observation time ~ hrs/days Total number Remarks Kelly & Kelly-cock psig Lower Kelly valve psio Safety Floor valves-~]BV ( )Dart eaks and/or equip, failures ~ Notify in days or when ready DEP~ OF NA~ ~ Divisio~ of Oil and Gas Conserva~on Hoyle H. D'~tor Lonnie C. Smith Chief Petroleun En~ Petroleum Inspector October 12, 1978 SSV and SSSV tests on Arco's Bay State $1 ~s~_~_~,, OCtO.~ 2., 1978 - I de.~_~, my ~ at 5:15 ~4 for a 5:40 PM '~ 6:40 PM depa~ via Wien flight $19 to Deadhorse, arriving via FairbaD~s at 9:05 PM. I proceeded to Drill Site $6 f~r an impending BOPE test ~n DS 6-8, the subject of a separate report, k~ather was +14° F, snc~, light wind. ~sda. y, October 3, 1978 - S~ by at DS 6-8. Thursday,. ~ 5,. 1978 - Standing by for BO.PE tests on DS 14-2, the ~/b~ of a separate` report. Fri ~d~__X_, ~6,,....1978~- ~lie Ross, Aroo drilling engineer, and I arrived at West Bay State #1 at 12:05 AM as Camco was setting the ball valve. Tests be~v~u at 1:30 AFl with the SSV closed and a shut-in tubing pressure of 1350 psig. Pressure was then bled to 800 psig downstream of the SSV and m~tored for five minutes. SSV was then opened and pres~ above the closed SSSV bled to 900 psig and mmnitored for five minutes. Aunulas pressures w~re zero and tests v~_re ooncluded at 1:45 A field J_nsp~on report was pre~ with a copy given to Charlie Ross, a copy mailed to Bob Hines, and the original attached to this report. I returned ltd Drill Site #14 at 2:00 .AM. BOPE tests o~ DS 14-2 completed at 11:45 PM. ~_~_turday_, Oct,_ 7., 1978. - I departed Deadhorse via Wien flight ~,20 ~I0:1~~ ~' arriving in Anchorag~ via Fair~q at 12:35 AM and at ray hcme at 1:05 ~M. ~s~: I witnessed successful SSV and SSSV tests on Arco's $~t Bay State #1. Attachment DEPAR~ OF NAIbT~L R~0~PCF$ Division of Oil and ~Cas Crnservaticn O. K. Gilbreth, Jr Director, April 21, 1978 78-38 Arco~est Bay #1 well We recc~d app~ of the plan of operat/cn with an added stipulation that all fu~l storage facilities be surr~ by a ben~ and ~ably 1~ in czdar to cc~a!n the full ~ capacity of th~ facilities. AflanticRichfieldCompany North Ameri~.n Producing Division North A~ask ~strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 March 17, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject- West Bay State #1 Dear Sir' Enclosed herewith is our Application for Permit to Drill West Bay State #1 and a $100.00 filing fee. The required survey plat will be sent as soon as it is available. Very truly yours, Frank M. Brown District Drill ing Engineer /am Enclosure Form 10-401 REV. )-1-71 2. STATE OF ALASKA SUBMIT IN T. .CATE (Other instruct, as on ~ ~ l~eve~s~si~du) OIL AND GAS CONSERVATION COMMIT,~,,~.~ g '2 i97~ - PERMIT TO la. TYPE OF WORK DRI EL ~ b. TYPE OF WELL WELL . X~LL OTHER DRILL OR DEEPEN Division oi "0~.,i anti ~.1;~:~ i..,.~;,v?_'do~: DEEPEN [-q An(~hora~, SINGLE MULTIPLE ZONE ~ ZONE NAME OF OPERATOR Atlanti.c Richfield CompanY ADDRESS OF OPERATOR P.O. Box 360, ^nchorage, ^K LOCATION OF WELL 2NSs~Y~FN'L, 2500.'F~./L, Sec. 99510 ' 1, T11N, R14E well-Same as above API No. 50-029-20304 6. LEASE I)ESIGNATION ANI) SERIAL NO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME g. UNIT FARM OR LEASE NAME West Bay State 9. ~,~,T;LL NO. 1 10. FIELD AND POOL, OR WILDCAT Wildcat At proposed prod. zone Vertical 13.DISTANCE IN MILES AND DIRECTION Ft~OM NEAREST TOWN OR POST OFFICE* Approx. 9 Miles North of Deadhorse, Alaska 14. BOND INFORMATION: n~= Statewides=.~.a.~/o,.~o. 8011-38-40 (Federal Insurance Co. ) Am .... t $100,000 lS. 17. 11.SEC., 'r., R., M.. (BOTTOM tlOLE OBJECTIVE) ~. 22, TION P. 197 ~? 18. D,STANCE~RO.',PROPOSED' 2780'W of E Line ~OCATIOS TO NEAREST PROPeRTY OR LEASE LI~:. ~. 2500'S of ~ Li~e (.~So to nearest dfig, uMt. ff any)ADL 28302 ~,SVANC~ r~o~ P~o~s~o ~AnO~ TO. NEAREST g~TLL DRILLING, COMPLIED, OR APPLIED FOR. ~. 8GI~5 gSk Js 1200' South 16. 19. No. OF ACRES IN LEASE 2560 PROPOSED DEPTH 10,450' MD=TVB NO,ACRES ASSIGNED TO THIS WELL 640 20. ROTARY OR CABLE TOOLS Rotary 21. ELEVATIONS (Show wheth~ DF, RT. CR, etc.) ] 22. APPROX. DATE WORK WILL STARI' Not Surveyed - Approx. 25'GL May 15, 1978 23: PROPOSED CASING AND CEMENTING PROGRAM sIZE OF HOLI~' ' SIZE O( CASING VQEIGHT PER FOOT GRA. DE [ SETT'ING I)EPTtt Q .... tity ,,f ......... t '"26' 20 " 94 H-40 .J +80'GL' Cmt t© surf-Approx' '200'sx "17'1/2 .... 13-3/8 72 N-80 ! +2750' Cmt to surf-Approx 5500 sx '12::1./4. 9.-5/81' 47 N-80 & S0095 +8530' Approx 750 sx 8-!/2 7" · 29 t +1-0450' Circ liner lap approx 400 sx Dual co'mp et'ion.2_7/~,, 6.5I, 0-55 As-:yet undetermined .... or better The Atlantic Richfield Company proposes to drill an exploratory well North of the NGI pad to approximately 10450'TVD=MD to test selected intervals in the Lisburne zones. Logs, cores, cutting samples will be taken at selected intervals. An oil base coring fluid will be used below the 9-5/8" shoe. A dual string of 2-7/8" is proposed for this well to carry out a 6-8 mo. production test. A 20-3/4" 2000 psi Hydril will be used on the 20" casing. A 13-5/8" 5000 psi Hydril w/3 5000 psi ram preventers will be installed on the 13-3/8" and 9-5/8" casing. BOPE will be pressure tested weekly and operationally tested each trip. Stage cementers will be placed at +2250' in the 9-5/8". A non-freezing fluid will be left in all uncemented ann~.i,-wiLth~rr~dh"61~maf~-ost interval IN ,~BOVE SPACE DESCRiBE PROPOSED PROGILAM: If proposal is to deepen give data on present productiyr,.zoao, av4~p, tOl:~g~('~.: ,.--:e- ' produc~ve zone. II proposal is to drill or deepen direcuonally, ~ve pemnent data on subsurface lo¢.atmas and measured hnd trqq., ~. 24. I hereby c,~'fy that the'F%regomgi~Trueand Correct : ,¥, [ ): ~ . ~.; ,(;f'tl.'1 SIGNED L/~ ~. ~ . DATE. March 17, 1978::'"':":'TITLE Dist. Drlg. Engineer (This space for State office use) SAMPLES AND CORE CHIPS REQL'IRED J MUDLOG EkYES [] SO {~ YES DIRECTIONAL SURVEY REQUIRED [] YES [BANG CONDITIONS oF APPROVAL. IF ANY: OTHER REQUIREMENTS: [] NO A,P.I. NUMERICAL CODE 50-029-20304 PERMIT NO 78-30 APPROVAL DATE June 7, 1978 TITLE Chairman *See Instruction On Reverse Side APPOVED BY June 7, 1978 I)ATE 02-001B (Rev. 10/761 STATE of ALASKA To: ~O. K. Gilbreth, D. O & G FROM: Pete Nelson /_~ I__,a__nd Manag~nt Of DATE: 4/13/78 FILE NO: TELEPHONE NO: SUBJECT: LO/NS 78-38 ARCO - West Bay ~1 Well A%%closed please find copy of the referenced proposed operations with map. Please review and send me your ~ts as soon as possible. you. AtlanticRichfieldCompany North American Producing Division Alaska Re Post Office ..... 360 Anchora§e, Alaska 99510 Telephone 907 277 5837 SAMPLE TRANSMITTAL SHIPPED TO: State of Alaska Division of Oil and Gas Conservation 3001 Porcupine Dr. Anchorage, Alaska 99501 Attn: Mr. Wm. YanAllen DATE: November 2, 1978 OPERATOR: ARCO SAb~LE TYPE: core chips sA~LES SENT: 8596.7 - 9924.5 N.~.~: W. Bay State #1 ( 305 samples) NUMBER OF BOXES: one SHIPPED BY: UPON RECEIPT OF THESE sAMPLES PLEASE NOTE ANY DISCREPANCIES AND b~IL A SIGNED COPY OF THIS FO~\l TO: ATLANTIC RICtIFIELD CO. P. O. BOX 360 f~/?~t ~y' Anchorage / -', Attn: R. L. Brooks RECEIVED BY DATE A~an~eldCompany North Arn~ Producing Division North AIz ~strict Post Office Sox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 March 22, 1978 Ms. Ethel H. Nelson Land Management Officer Division of Minerals and Energy Management State of Alaska 323 E. 4th Avenue Anchorage, Alaska 99501 Subject: LO/NS #78-38 West'Bay #1 Well North Slope, Alaska Div. of Minerals & Energy Mgt. Anchorage, Ak. Dear "Pete": Atlantic Richfield Company hereby requests a lease operations permit for our West Bay #1 proj~ect, the particulars of which are set forth herein: 1. Location: Twenty-five hundred feet from the north line and 2500' from the west line, Section 1, TllN, R14E, Umiat Meridian. 2. State Lease: ADL-28302 3. Timing: Projected spud date is June 1, 1978; preliminary pad construction should commence by May 1, 1978. Drilling is scheduled to be completed and the rig moved off-site about September 20, 1978. 4. Construction: The exploratory drill pad will be about 300' x 500' and will be 5' thick. Extensions to the pad for a flare pit and SDS lagoon will conform to the dimensions indicated on Exhibit #1, Pad Layout. 5. Access: To access the drill site, construction of a gravel road is proposed. Such road would extend east from the existing roadway, as shown on Exhibit #2. Cross- sections of the road are attached as Exhibit #3. 6. Gravel: Construction of the road and the exploratory drill pad will require approximately 32,000 cubic yards of gravel. Upon approval, gravel will be taken from the Put River in Section 23, TllN, R14E, Umiat Meridian. 7. Water: An estimated 60,000 gallons of water per day will be needed for drilling operations. Water sources are existing pothole lakes along the access road and, if necessary, Webster Lake. Ms. Ethel H. Nelson, Land Management Officer Division of Minerals and Energy Management State of Alaska page 2 March 22, 1978 8. Drilling: A decision on the particular rig to be used has not yet been made, but will be a rig that has met with approval on other projects and is equipped with acceptable sewage treatment equipment. A mobile camp housing about fifty people will accompany the rig to the drill pad. Drilling plans include measures for the control of any spill that might result from operations. Exhibit #4 addresses the main activities proposed to remedy such occurrence, and a more specific, detailed plan will be prepared for us by drilling personnel. The Company Spill Prevention, Control and Countermeasure Plan is used, and will be avail- able on-site during all drilling operations. Your review and approval of this lease operations permit application will be appreciated. Should you require further information, please advise. Very truly yours, ATLANTIC RICHFIELD COMPANY Thomas L. Holland Landman TLH/gr APti- 5 I.a,78 Diw. of Minerals .,g. Energy Mgl;. Anchorage, Ak. GENERAL SPCC PLAN WEST BAY #1 Atlantic Richfield Company proposes to drill a Kuparuk exploratory well with a surface location of 2500" from the north line and 2500' from the west line, Section 1, TllN, R14E, Umiat Heridian. A new 400' x 200' x 5' gravel pad will be placed for the well.~ The object of the well is to test and evaluate the Kaparuk River Sands. No gas cap is expected and minimum oil rate expected is 2000 BOPD. Spillage Prevention The rig contracted to drill this well will be equipped with all standard blowout control equipment. As required by the Department of Natural Resources, Division of Oil and Gas, the blowout control equipment is tested on a routine basis. The Atlantic Richfield on-site supervisor periodically discusses drilling, testing and well control procedures with responsible Contract supervisors to insure all personnel are instructed in tripping practices and operations of blowout preventor systems. Blowout drills are scheduled weekly for each crew. Control and Countermeasure Spills from uncontrolled wells can be divided into two classes. Small spills can be directed to existing well site sumps; these sumps will accomodate 20,000 barrels. The oil trapped in the sumps would be trucked to existing burn areas or injection facilities. Should a large spill occur, a snow, ice, and/or gravel berm could be built to the east. The collection basins are sufficiently large to contain all flow until a relief well is drilled. Adequate amounts of heavy equipment, vacuum trucks, and absorbent materials are currently available at Prudhoe Bay to clean up an oil spill following containment. ~llllll I I I ~l~ , _ EXHIBIT #4: SPCC ,, .... CROWN WIDTH -. , ,, 24' · ~, · · - '"'?~,.~;'/ [',' ' '.' "///. '. ~11,":'"'"'.. · :' .. ,///~., BASE WIDTH .-E7.'.HIBIT ~'/3: WEST BAY fi-~i,20AD EXTENSIOn.__ lTYPICAL ROADWAY CROSS SECTION i I NORT~ SLOPE, ALASKA - 6 --. ,.~- , PUT RIVER ~RAVEL SOURCE ACCESS ROAD '.~ ~ %:'<-'? :.- ~-:::_. .':"(~Gull Island ., PROPOSED WEST BAY LOCATION W/ACCES ROAD / PRUDHO/, .:: ....EXISTING ROAD TO WEST DOCK i'."'" '%-'~ ~: l '~'." '" ~-:..~.' ¥" ' l- -" ' ~ %' '..'% ~.,- " "" ?~ - '~"Z ~-:" ~}~:~HIBIT #2: VEST BAY #1,LOGATION PLA~ .1 /I SDS L RGO01'I /~"-- 3 THICK PRD SU~z~CE LOCqTION---~ UAIN ~' IHICK RESERVE PIT 180' 1, VEST BAY LOCATION LAYOUT PIT S' THICK BEF~MS __. EXHIBIT l~i: · PAD LAYOUT mm (]iqEbN t_LL) i i-Lit, :,'-,', ,,L,_L r'Lr~:',L ib t. Is the permit fee attached . 2. Is ',.,,ell to be located in a defined pool 3. Is a registered survey plat attached 8. Is ,,..'ell located :re?er distance from property line Yes I,io Remarks 5. Is ;.,'ell loc::t~J ~':cper distance from other '.,,,'ells 6. Is suffic:ent ur:ieditated acreage available in ti~is ?ool ..... 7. Is '.,.,'ell to be de'.'iated ........... Is ope':atoi' ti~e only affected party . 9. Can permit be a?proved before ten-day wait . t0. Does operator have a bond in force ' . Il. Is a conservation order needed , ,,_. ~:~ ~zministrative a=,proval:, needed . . . . . . . 13. Is conductor string provided .............. 14. Is enouqh cement used to circulate on conductor and surface . . .., 15. Will cement tie in surface and intermediate or production strings 1F Will cement cover all known productive'horizons . .' . . ..... 17. Will surface casing protect fresh water zones ...... 18. Will all casing give adequate safety in collapse, tension & burst 19. Does BOP£ have sufficient pressure rating - Test to ~:,,~';, psig 20. Has DHEIt approved Plan of Operation ..... . ....... Additional Requirements' Revised 11/17/76 ~ ChECk...~IST £'OR Nk---~q WELL P 'F/~ITS 1. Is the ~r:~it fee attached ..................... 2. Is well to ~ located in a defined pool .............. 3. Is a regi:~tered survey plat attached ................ 4. Is well !coated proper distance from property line ......... 5. Is well located proper distance from., outer wells .......... 6. Is suf=lc:.untC' :"~ ~dedicated acreage available in this pool ...... 7.- Is well to be deviated ....................... 8. Is operator the only affected party ................ 9. Can permit be approved before ten-day x~it ............. 10. Does operator have a bond in force . .. ............... 11. Is a conservation order needed ................... 12. Is administrative approval needed ................. Comp_any ,: '(~,0. Yes No R~mark s Item Approve Date - (1) Fee /--i ~ !: ~ !"~';'~ 13. Is ccnductor string provided .................... 14. Is enough cement used to circulate on conductor and surface .... 15. Will cement tie in surface and intermediate or production strings . 16. Will cement cover all known productive horizons .......... 17. Will surface casing protect fresh water zones ........... 18. Will all casing give adequate safety in collapse, tension & burst . 19. Does BOPE have sufficient pressure rating - Test to ~9 psig . ,4) Casg. ,, '"~ , - (5) BOPE :: :~ ................ ~': '~: Approval neccmmnended: :- Additional Requirements: C~eo!ogy: Engineering: 11~,E4 LCS RAD Revised 4/14/78