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183-143
RECEIVED m3-`4 3 • 2�321 JUN 2 8 2017 WELL LOG TRANSMITTAL#903957406 AOGCC To: Alaska Oil and Gas Conservation Comm. June 23, 2017 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 inizo,7 g f�.K.BENDER RE: Leak Detect Log: L3-08 Run Date: 4/29/2017 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 L3-08 Digital Log Image files 1 CD Rom 50-029-21019-00 SCANNED JUL, 0 `i2017 Leak Detection Log 1 Color Log 50-029-21019-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: t4% STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate Q Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 183-143 3. Address: P.O.Box 196612 Anchorage, Development Q Exploratory 0 AK 99519-6612 Stratigraphic 0 Service 0 6. API Number: 50-029-21019-00-00 7. Property Y Designation(Lease Number): ADL 0028322 8. Well Name and Number: LISB L3-08 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,LISBURNE OIL 11.Present Well Condition Summary: Total Depth: measured 9973 feet Plugs measured See Attachment feet RECEIVED true vertical 9970 feet Junk measured 9160 feet JUN 0 2 2016 0i6 Effective Depth: measured 9160 feet Packer measured 8754 feet true vertical 9158 feet Packer true vertical 8752 feet OG C Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 81 20"91.5#H-40 41 -122 41-122 1490 470 Surface 3742 13-3/8"72#L-80 40-3782 40-3782 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 8858 8872 feet feet 8882-8936 feet 8966-8986 feet 8986-9006 feet 9006-9016 feet 9026-9062 feet 9086-9150 feet 9241-9270 feet 9516-9566 feet True vertical depth: 8856-8870 feet feet 8880-8934 feet 8964-8984 feet 8984-9004 feet 9004-9014 feet 9024-9060 feet 9084-9148 feet 9238-9267 feet 9513-9563 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and 2-7/8"Baker SAB Packer 8754 8752 true vertical depth) 2-7/8"Camco TRDP-1A SSV 2207 2207 12.Stimulation or cement squeeze summary: Intervals treated(measured): s NNED DEC 0 82016 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 90 100 659 1120 531 Subsequent to operation: 125 3214 691 1050 . 673 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory 0 Development Q Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 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: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature Phone +1 907 564 4424 Date 6/2/16 06-411- 61742\-- Form 10-404 Revised 5/2015 Y7-L__ 7-/91/6,, Submit OriginalOnl Only jos RBDMS Lu d 3 1016 , • • Plugs Attachment LISB L3-08 SW Name Date MD Description L3-08 02/20/1984 8969 Sand Plug L3-08 01/02/1984 9225 EZ Drill Cmt Retainer L3-08 12/27/1983 9450 EZ Drill Cmt Retainer • • 0) Q, O O O O O O O o 0 0 co O. N- CO CO st N CO LO (DC' LO CO O CO N- O szr O N U7 LO U N- 71; CD 0 CD 0 0 0 0 0 0 0 0 0 i 0) CO N- U) N CO O N- OLo~ 3 V 0) 00 0 N- N O c3 N cpO U7 m V Cfl co co o in in O N N C)) V CA 00 CDCO NN- CO CO r CO CO N N O N- CO M CO CO Cr) N N Nr CO CO 03 H CO O Cr) V U) O) O 00 N- CO • V CO CO O CO CO N N V CO }r C G) NE N Q) N- O N 0) O O CO 00 O M 00 O 6) O N- CO O N N- CO CO N CO N N O) N- CO • CO r- CO CO O) N N Cr CO CO V " o " " III 4-, CO Q O N- O CO O N- U7 CA 0 CN 0 0) LO JCO CO CO LO M CO N N CO CO u) O 000 OO 000 000 00 C (n CO J U) J U) J J d 4t 4,t J " l •N LO LC) N tf) - (.0 0) - CO 10 CO CO V1 c— O � w NN CO _ co U N. 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U Z _o L \ : cca_ ❑ ❑ � � ❑ : : a' Jaa' aaaQam * HH oo * cr1 : ❑ o (0 W H CO O ›- 0 0 0 W H N N N _0 N- N N 5 CO N - CO V m H Nt in in in 0 Q TREE= 5"X7"FMC 120 L S WELLHEAD= GRAY r SAFETY NOTES:"RSH IN WELL" !ACTUATOR= BAKER C L3-08 EXACT DEPTH UNKNOWN.DIAGRAM OKB.ELEV= 60.5 2a'cOND --I 81' J I f I OF FISH IN W E11-RLE. BF.ELEV= WA -d KOP= N/A 91.5#,H-40 Max Angie= 3'@ 8700' D=19.124' Datum MD= 8963 TOP OF —{ 1636' I^r 2199' --I2-7/8"CAMCO TROP 1A TRSSSV,D=2.312" Datum TVD= 8900'SS 11-3/4"LNR u 13-3/8"nsG,72#,L-80,D=12.347' H 3781' 5"TBG,15#,J-55,BAKER HEAT SAVER I I —1 4972' N. / 4972' H5"15#,J-55 OUTER X 2-7/8'6.5#, X0 11-3/4"CSG,60#,S-95,D=10.772" —1 6480' I a k GAS LET MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 5035 5035 1 CA-KBMG DOME BK 16 01/03/16 2 8690 8690 3 CA-KBMG SO BK 20 01/03/16 Minimum ID =2.250" @ 8796' 2-7/8" CAMCO D NIPPLE TOP OF 7"LNR —1 8543' J 8753' —17"X 2-7/8"BKR SAB HYDRO PKR E „/ 8758' —16'BKR MLLOLTT EXTENSION,D=? 8763' —14-1/2•X 2-718"XO,D=2.387" I II 8796' —{2-7/8-CAMCO 0NP,D=2.250' 2-718"TBG-PC,6.5#,N-80 WE, —1 8806' / .0058 bpf,0=2.441" ��---1 8806' —2-718'TTL,BKR SHEAROUT SUB 9-5/8"CSG,47#,L-80/S-95 D=8.681" ' —1 8836' [[ FERFORATION SUMRMRY [ REF LOG:LDT/CNL SOS ON 11/03/83 a ANGLE AT TOP FERE: NA ? —i FISH TOOL STRING(25'X 1-3/4•) Note:Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sgz DATE 411111111r [ 2-1/8" 4 8858-8872 0 10101/94 9160' --I TOP OF SAND(07/18/84) 2-1/8" 4 8882-8936 0 10/01/94 2" 6 8966-9016 0 05/03/16 9200' --1 TOP OF CEMENT 2-1/8" 4 9026-9062 O 10/01/94 9225' —{EZ-SV CMT RETAINER 4 9086-9150 O 10/01/94 4 9241-9270 S 12/01/83 4 9516-9566 S 12/01/83 9440' --1 TOP OF CEMENT 9450' —1 EZ DRL CMT RETAWER [ PBTD H 9652' I 1111111 11111111111411 7'LN2,29#,L-80, .0371 bpf,D=6.184" --I 9700' DATE REV BY COMMENTS DATE REV BY COMMENTS LISBURPE WIT 03/08/84 N1ES ORIGINAL COMPLETION 05/04/16 C!S/JMD ACPERFS(05/03/16) VVELL L3-08 12/04/01 RNRP CO CTIONS PERMIT Pb:'1831430 03/12/02 ClVTP CORRECTIONS AR No; 50-029-21019-00 07/28/15 DLVJMD TREE CIO(06/26/15) SEC 22,T11N,R15E,401'FML&751'FWL 10/07/15 TFA/JMD FULL®CA-2 PLUG(10/04/15) 01/05/16 DLWJMD GLV 00(01/03/16) BP Exploration(Alaska) • • bp BP Exploration (Alaska) Inc. 0 Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 20, 2012 14444k1 AUG Ct j Z Gt' Mr. Jim Regg 2 Alaska Oil and Gas Conservation Commission s 3 333 West 7 Avenue 3 �) Anchorage, Alaska 99501 �0 `e7 Subject: Corrosion Inhibitor Treatments of GPMA Lisburne 3 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPMA L3 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • l I BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10404) GPMA t.isbume 3 Date: 03/08/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date L3-01 1890750 50029219590000 0.0 N/A 0.0 N/A 10.20 11/29/2011 L3-02 1861540 50029216440000 0.0 N/A 0.0 N/A 10.20 11/20/2011 L3-05 1851950 50029214210000 0.0 N/A 0.0 N/A 8.50 11/29/2011 ----7 1.3.08 1831430 50029210190000 3.0 N/A 3.0 N/A 27.20 11/29/2011 L3-11 1852310 50029214520000 0.0 WA 0.0 N/A 7.65 11/29/2011 L3-12 1861610 50029216510000 Dust Cover N/A 0.0 N/A N/A 3/8/2012 L3-15 1852660 50029214760000 0.0 N/A 0.0 N/A 8.50 11/29/2011 L3-18 1861670 50029216570000 0.0 N/A 0.0 N/A 11.90 11/20/2011 L3-19 1852860 50029214940000 0.0 N/A 0.0 N/A 7.65 11/29/2011 L3-22 1861750 50029216630000 0.0 N/A 0.0 N/A 10.20 11/20/2011 L3-23 1853060 50029215130000 0.0 N/A 0.0 N/A 10.20 11/20/2011 L3-24 1861820 50029216700000 0.0 WA 0.0 N/A 8.50 11/29/2011 L3-28 1890660 50029219550000 P&A 12/93 NA NA NA NA NA L3-30 1861850 50029216730000 0.0 N/A 0.0 N/A 10.20 11/29/2011 L3-31 1860340 50029215440000 0.0 N/A 0.0 N/A 8.50 11/29/2011 11/24/10 Schkikulpi NO. 5648 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD OWDW -SE BBSK -00030 RST REDO — 09/23/10 1 1 OWDW -SW BBSK -00034 I RST 09124110 1 1 1-2 -07A BG27 -00008 RST 09/28/10 1 1 1-2 -16 BG27-00007 RST 09127110 1 1 15 -37C BAUJ -00031 MCNL 06130/10 1 1 C -37B AWJI -00107 MCNL n 1,11 s 09/10110 1 nUeJ4 1 05 -OBA AWJI -00108 MCNL go a 09/11110 1 1 18 -10C BCUE -00078 MCNL 09/28110 1 1 04-03 BCRD -00059 RST 09128110 1 1 • 1-2 -33 139RH -00036 RST 09/30110 1 1 1-3-19 BCRJ -00043 RST 10 102/10 1 1 1-3-08 83SQ -00094 RST 10101110 1 1 1-2 -28 BGZ7.00009 RST a 09129110 1 a 1 1-3.05 BCRJ -00042 RST 10/01/10 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Sheet, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 64q 0 f -t- z e ",-- • 1�� 06/26/09 *?~~~f~m~~~~~~' ~ i. ~. 1z~ ~S• ,~^y - C (~~~y NO. 5289 +:'~~tr1ZJ~~~~i3/ ~ ~1 `~,.. yi .: ~ U V ~ Alaska Data F~ Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 40o Alaska Oii & Gas Cons Comm t~nchorage, AK. 995o3-2s38 Attn: Christine Mahnken l1TTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 \Nell Job # Log Description Date BL Color CD • ~ L J A-44 09AKA0048 OH MWD/LWD EDIT ` 04/26/09 2 1 4-04A/T-30 09AKA0040 OH MWD/LWD EDIT 03/28/09 2 1 18-O1A B2WY-00003 MCNL OM30/09 1 1 15-296 09AKA0143 OH MWD/LWD EDIT - 05/30/09 2 1 05-35A 40017778 OH MWD/LWD EDIT ~U~S °~ 09/10/08 2 1 V-115L2 11962618 OH WIRELINE 08/22/08 1 1 MPS-41 11966289 OH WIRELINE ~-l~j /~a 11/19/08 6 1 G-01A BOOR-00006 MCNL ~~~.- ~~ ~ ~'~- 04/01/09 1 1 4-04A/T-30 BOCV-00014 ~ CH EDI ~ rv~,~-GR (SCMT) (REVISE DATA) - ~ 7/09 1 05-35A AWJI-00008 CH EDIT PDCL-GR (MEM CORRELATION) .. ~ 12/03/08 1 07-146 AYQ~-00029 CH EDIT PDCL-GR (LDL) - L 05/26/09 1 L3-08 AWL9-00028 RST / 06/11/09 1 1 ~ ~/~Jf~ Mlil~IYV VYI~CVIIC IICVGIr 1 G i JI171V11Y17 NIVU F'IC 1 UFfIV11VU VIVC l.VY7 CHVI'7 1 V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 11 /12/07 ~chlumb~rger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Joh # ~l./~~ 1 nn naccrin4inn n~ro NO. 4496 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Lisburne RI Cnln. !`n L3-08 11637143 LDL - 10/27/07 1 L3-08 11637143 LDL -. L 3 10/28/07 1 N-12 11626132 LDL ( ~ -~ fG 11/03/07 1 14-186 11637368 ISOLATION SCANNER -3-- 10/26/07 1 NGf-13A 11637144 CEMENT BOND & IMAGE LOG 10/28/07 1 GNI-04 11676971 USIT ~-- J~- 11/05/07 1 r ~~r+v a. ~vr~1~vY~LLVVC nGVCII-/ ~/ JIV1~1119V NI\V RGIIJRIYIIY\7 VIYC liVrT CNlil1 IV: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 I~ T (~ $ p.~...~ 900 E. Benson Blvd. Anchorage, Alaska 99508 ~3 ll Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~` Received by: ~. Schlumberger Alaska Data & Consulting Services 2525 Gambell Street. Suite 400 Anchorage, AK 99503-2838 A TTN: Beth 1 '1J\)1 f:>.\)\) Ö /.. 'S~t\r;j) Well Job# Loa Descriction Date BL 05-33A 11366499 MCNL IJoo -IA.,q 1t' Á"I r ,oç 9 10/20/06 1 11-36 11594490 RST JO <'!-/)lðL. "fI' 1'\ ""7I 04/21/07 1 11-37 11626086 RST }t:>¡(/}-'1L! i:1' I,::,:;~- fU 04/22/07 1 L3-08 11626491 RST /11_7¡ - p.!.':?, "1f 16~?"-tC¡ OS/22/07 1 L2-28 11221616 RST /Jr(\ /1<.-Ç_·tL76"" -#- 10/13/06 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: t\UG 2 7 20117 Œ! g, Commission 6' NO. 4378 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Color Field: Prudhoe Bay Endicott CD 1 1 1 1 1 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503·2838 ATTN: Beth Received by: 08/27/07 . . RECEIVED Scblumbepgep MAY 2 4 2006 NO. 3812 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503·2838 ATTN: Beth ~ C1t & Gas Cons. Com!T~G: ~ Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay \ qs '3 - l·Lt ó Well Job# Log Description Date BL Color c.o D-23A 10942207 MCNL /C;G- h:-k. 04/22/05 1 LV '/ O'l r of_'d" L. ¡",. L3-08 11136738 RST I/,r~ - I<'/~ 11/04/05 1 1 L3-08 11212839 RST l"?f ~ - t../3 03/29/06 1 1 03·14A 11212846 USIT ,;::}CG" /~ ':J 71- 04/24/06 1 D.S. 3-09 11212840 US IT 1'1'1 - ò 9,;).. 03/31/06 1 D.S.15-17 11221562 SCMT ¡ ~4 - 1").ç"Ì 04/10/06 1 NGI-08 11225958 USIT LI'Ie... l'r (~ - Ö:«~ 04/11/06 1 D.S.01-04A N/A USIT 'd(> 1_ /5";:¡ 05/06/06 1 12-08C 11221571 US IT riò;} - I ~ Lo 05/06/06 1 AGI-07 11221569 USIT U'!:c.. \'1:'i -6;::)-:} 05/05/06 1 E-15B 11212857 US IT I Cì¿:ì -04::), 05/18/06 1 L-50PB1 40012467 OH LDWG EDIT OF MWD/LWD ~ /~,~ - I ~ C-, 10/18/05 1 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd, Anchorage. Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage. AK 99503-2838 ATTN: Beth 0-~Jk- ~/9 s1ar¡4 05/19/06 e e , . ~ r"'\ .. . fr:" t:.;"';;¡ rt.-' :::-::'l r~;'.' i\l.! I¡ I,. II,! -', -'" !! j - \ \, :! : ~.-:.. tiu U ll\j U ll-:. .."'-, .' '.^J ¡ fì\ i r , ¡ L. lllJ U-" -':', i'l (", '-;~'\ :-',0 rio, Ir'-\ Ii !/1\ (I,U 1.1 !(¡\ ¡ 1\\ if: \ \ -', '-,\ r ( ! 1\: ifù L~ Lf~~ @ J \j lf1i ¡ ! FRANK H. MURKOWSKI, GOVERNOR ,I ! ALAS KA 0 IL AND GAS CONSERVATI ON COMMISSION , 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 May 12, 2004 Mr. Bruce 1. Williams GPB Operations Integrity Manager BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage,AJ< 99519-6612 ¡(Þ3-/'f3 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 PBU L1 PBU L2 PBU L3 Date ofSVS Test April 23, 2004 April 26, 2004 April 27, 2004 Failure Rate 30.0% 16.7% 50.0% Copies of the SVS Test Reports are attached. Regulation at 20 AAC 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 ofthe 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 L1, 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 "ù th SVS test. Sincerely, J . Norman, Chair C~missioner 2J~ Daniel T. Seamount, Jr. Commissioner 3 Attachments cc: AOGCC Inspectors (via email) r---- ,-.... " I 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: 04/27/2004 Unit/Fie1d/Pad: Greater Pt McIntyre/Lisburne/L3 Separator psi: LPS 450 HPS 450 "WA~- -,- ... lfJ'lIlllll4RmJlIlfJJt'1 ~..~~. --,-~-w-- , -"...,-', . '"",~.. ,"""""-",=~."=',,,, ,~~~ 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 13-01 1890750 12/4/1993 SI 13-02 1861540 450 350 350 P 6 P OIL 13-05 1851950 1/14/2003 SI 13-08 1831430 7/2/1994 SI L3-11 1852310 9/9/2003 SI 13-12 1861610 4/19/1997 SI 13-15 1852660 12/22/1996 SI L3-l8 1861670 2/16/1997 SI 13-19 1852860 11/17/2001 SI 13-22 1861750 6/4/2003 SI 13-23 1853060 6/26/1995 SI L3-24 1861820 5/12/1997 SI 13-28 1890660 9/7/1993 SI 13-30 1861850 11/25/1996 SI 13-31 1860340 7/28/2003 SI Wells: 1 Components: 2 Failures: 1 Failure Rate: Remarks: L3-02 4/27/2004: Grease crew notified to service SSV Page 1 of 1 SVS PBU LIS L3 04-27 -04.xls 03/13~03 Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 2698 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Lisburne Color Well Job # Log Description Date Blueline Prints CD L3-08 I~.~"lq .~ 23005 RST-SlGMA li/14/02 1 1 L3-ii I ~.~-~-~T 23008 RST-SIGMA 11/14/02 1 L5-15 ./~-Inq 230~0 RST-S~GMA 11/13~08 1 1 , , ,, ,, PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: OA~NE~;:',¢ SEF t 5 2003 RECEIVED MAP, 2. O~ & Gas ions. Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A'PI'N: Beth WALTER J. HIGKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 May 13, 1991 Sue Morgan c/o Dr. Keith Watts Geophysical Institute 301-B University of Alaska Fairbanks- Fairbanks, AK 99775 Re: Data on PBU L2-06, L3-08, L4-15 Dear Ms Morgan: Please find enclosed the well histories for PBU L2-06, L3-08, L4-15. Each well file contains a completion report and lists of data available for each well. I have also enclosed an informational sheet listing the services and data provided by the AOGCC and services. offered by various companies in the Anchorage area.' If you have further questions please feel free to call me at 279-1433 or call the company direct. Microfilm Equipment Operator Enclosures Summary Core Descriptions West Beach #lA pressure cores Core #1 Core #2 Core #3 Core #4 Core #5 Core #6 Core #7 Core #8 9700-9709.4 9709.4-9717.8 9825.3-9833.8 9833.8-9842.4 9892.7-9901.9 9901.9-9908.2 9992-10000 10000-10009.3 Sandstone and pebble conglomerate with thin (3-5") beds of silty claystone Medium to coarse sandstone and pebble conglomerate Medium to coarse grained sandstone Medium to coarse grained sandstone Medium to fine grained sandstone Medium grained sandstone with shaly rubble at top Fine grained sandstone grading downwards into silty shale Fine grained, uniform sandstone ARCO Alaska, ,,~-"", Post Of, Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 SAMPLE TRANSMITTAL TO: State of Alaska Oil & Gas Conservation Comm. 3001 Porcupine Dr. Anchorage, Ak. 99501 Attn: Robert Crandall DATE: 2-1-90 AIRBILL #: Airland /1379993 AFT#: 0-02-05-41 CHARGE CODE# 18562 OPERATOR: Arco NAME: W. Beach St. lA & S. Bay St. #1 SAMPLE TYPE: pressure core chips NUMBER OF BOXES: 8 in one SAMPLES SENT: W Beach St lA -9~~830.5 f 9700.4 / 9831.2 iX 9905.5 9701.4 I 9832.6 9906.4 9702.7 I 9833.4 ~ 9907.3 9703.6 / 9833.9 9704.6 9834.8 9705.6 ~ 9835.7 9706.7 ~! 9707.6 9708.5 9709.4 9709.5 9710.6 9711.6 9713.1 9714.2 9715.8 ~,/ 9716.5 9825.8 I 9899.2 9826.5 [ 9900.4 9827.7~? 9901.4 9828.4~2_, 9902.2 9829.6 9903.3 9836.4 9838.6 9839.4 9840.5 9841.9 9893.3 9894.8 9895.8 9896.4 9897.5 9898.2 9992.6 9993.5 9994.6 9995.8 9996.7 9997.4 9998.3 9999.6 10001.5 10002.1 10002.9 10003.9 10004.9 10005.3 10006.3 10007.3 10008.3,,~ 10,0.09.3 SENT BY: Teresa Gorup South Bay 8448.5 8449.6 8450.3 8452.5 8453.2 8454.2 8455.4 8456.2 8457.2. 8458.7 8459.8 8460.4 8461.9 8462.8 8463.4 8464.7 8465 ~--r---~ 8466.7 8467.9 8475.9 8476.7 8480.8 8481.2 #1 8576.1 8577.5 8578.7 8579.1 8580.1 8589.6 8591.2 8618.2 8619.5__ 8620.~----~ 8621.6 8622.7 8623.8 8624.4 8625.2 8626.5 8627.6 8628.5 8629.5 8630.6 8631.2 8632.5 8633.4~-'- 8635.9 8636.4 8637.4 8638.6 8639.7 8640.3 8641.5 UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COPY OF THIS FORM TO: ArcoAlaska, Inc. P. O. Box 100360 Anchorage, AK. 99510 Attn: ABV-100 RECEIVED BY' DATE' ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR313-6003-C A1RCO AILASI~A lINC,' DATE' !-4-88 FROM: PAM LAMBERT ' ENCLOSED IS THE FOLLOWING DATA FOR LISBURNE: OH Finals for L2-8(~) BHC Acoustilog/GR 11-25-87 Run 1. 2"&5" WAI .~_~Comp Neutorn/GR Cased.'Hole ~t-25-87 RUn I 5" WAI Comp Neutron/GR 11-25-87 run i 2"&5" WAI ~'-~Spectralog 11-25-87 Run i 2"&5" WAI -"-~DIFL/GR 11-25-87 Run i 2"&5" WAI CH Finals ~ ,~.,L3~8 Production Profile Spin-TemP W.H.U.T. Density 11-18-87 Run I 5" Camco ~' ~L3-18 Production Profile Log 11-18-87 Run i 5" Camco RECEIVED BY' ~. ~';i~:-'~ 0ii &-Gas Cons. Commisslo[~ Anchorafle PLEASE SIGN AND RETURN TO: PAM LAMBERT ARCO ALASKA INC. 700 G STREET ATO 477 ANCHORAGE, AK. 99510 CENTRAL FILES PLANO D&M EXXON STANDARD ?'STATE"Old'ALASKA. TRANSMITTIAL # 368 STATE OF ALASKA AL, <A OIL AND GAS CONSERVATION CC. ,ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing -d WELL NAME CHANGE A ter Casing ~ Other ~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P.0. Box 100360. Anchorage, AK 99510-0360 4. Location of well at surface 400' FNL, 751' FWL, Sec.22, T11N, R15E, UM At top of productive interval 400' FNL, 751' FWL, Sec.22, T11N, R15E, UM At effective depth 400' FNL, 751' FWL, Sec.22, T11N, ELSE, UM At total depth 400' FNL~ 751' FWL~ Seco22~ T11N~ R15E~ UM 11. Present well condition summary Total depth: measured true vertical feet Plugs (measured) feet 5. Datum elevation (DF or KB) RKB 61 ' 6. Unit or Property name Prudhoe Bay Unit/Lisburne 7. Well number L3-8 8. Approval number 4.~ 9. APl number 50-- 029-21019 10. Pool Lisburne 0il Pool Feet True Vertical depth Submit in Duplicate 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 "SoUth Bay State #1" to "L3-8" Perforation depth: measured true vertical Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) 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 Tubing Pressure 14. Attachments None Daily Report of Well Operations [] Copies of Logs and Surveys Run [] that the foregoing is true and correct to the best of my knowledge ~ ~--c~ ~ ~/'~ 15. I hereby certify Signed Form 10-404 Rev. 12-1-85 Title Associ ate Engineer (JG} SW02/105 A~CO ALASKA INC. L?SBURNE ENCINEEltl'NC Date: 5-19-87 , , From: Pam Lamb.er t ~ Enclosed are the following: CH Finals for Lisburne Wells L2-33 Temp Fluid Density Flowmeter Log 5-8-87 Run 1 5" Camco L3-8 Waterhold Up Temp Flowmeter Log 5-4-87 Run 1 5" Camco L3-24 Flopetrol Prod Logging 4-30-87 Run 1 5" Sch L3-30 Post Temp GR Log 5-2-87 RUn 1 5" Camco 5" L3-30 Collar Log & Perforating Record 5-7-87 Run i Sch LJ-30 Major Acid Treatment Temp GR 5-11-87 Run 1 5" Camco L3-30 Mini Breakdown Treatment Temp GR 5-11-87 Run 1 5" Camco -sm Received by: Please sign and return t~Pam Lambert ARCO AK INC. AnchomrJe 700 G Street ATO 477 Anchorage, AK. 99510 D&M EXXON STANDARD FILE ROOM CENTRAL FILES TRANSMITTAL # 237 "~---'" STATE OF ALASKA ALASKJ.. ,IL AND GAS CONSERVATION COMMI. ,ON APPLICATION-FOR SUNDRY APPROVALS 1. Type of Request..: Abandon [] Suspend ~ ,~, Operation Shutdown [] Re-enter suspended well [] Alter casing .~ Time extension [] Change approved program Wl Plugging [] Stimulate ~ Pull tubing [] Amend order ,~ Perforate ~ Other~r~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage.- AK 9951¢) 4. Location of well at surface 400'FNL, 751'FWL, Sec.22, T11N, R15E, UM At top of productive interval 400'FNL, 751'FWL, $ec.22, T11N, R15E, UM At effective depth 400'FNL, 751'FWL, Sec.22, T11N, R15E, UM At total depth 400'FNL, 751'FWL, 5ec.22, T11N, R15E, UM 5. Datum elevation (DF or KB) 61 ' RKB 6. Unit or Property name 7. Well number 8. Permit number 9. APl number 50-- 029 -21019 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Length 80' 3781 ' Casing Conductor Surface 9973 ' MD feet feet 9973 , TVD feet 9200 'MD feet 9200'TVD Size 20" 13-3/8" Intermediate 4844' 11-3/4" Production 8836' 9-5/8" Liner 1157' Perforation depth: measured 7,! Plugs (measured) Junk (measured) 10. Pool Lisburne Oil Pool 9516' 9241 ' - 9566' - 9270' 9086'-9150' True Vertical depth 81 'TVD 3781 'TVD 6480'TVD 8836'TVD None Cemented Measured depth 1910# Poleset 81'MD 2400 sx Fondu & 3781'MD 400 sx PF "C" 500sxClassG&2OOsxCSI 6480'MD 550 sx Class G & 8836'MD 300 sx CS I 175 sx Class G 9700'HD 9700'TVD , 8900'-8936', 8882'-8900', 8858'-8872' true vertical (same as above) Tubing (Size, grade and measured depth) 2-7/8" ~ 8806' Packers and SSSV (type and measured depth) Pkr ~ 10,015', SSSV ~ 2199' RECEIVED APR2 9 1986 AJaska Oil & Gas Gons. Gommi~si~n Description summary of proposal ~ Detailed operations program [] BO~',~t~c-~" F~ 12.Attachments 13. Estimated date for commencing operation As soon as possible 14. If proposal was verbally approved Date approved Name of approver Date c. 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~)~ ~,~ Title Associate Engineer Commission UseOnly (JG) SA/O17 Conditions of approval Notify commission so representative may witness [] Plug integrity il! [t)~iE Jk S~IIIt [] BOP Test [] Location clearanceI Approval No. ~/_~ ~Fr.~roved Cc~p¥ Commissioner the commission Date Approved by Form 10-403 Rev 12-1-85 Submit in triplicate ...... ,, ..., J ARCO Alaska, Inc., proposes to change the well number designation from "South Bay State #1" to "L3-8". APR 2 9 1986 Nasa Oil & Gas Cons. Commission Anchorage SA/OO2a:tw ARCO Alaska, Inc. Subsidia~ of AtlanticRichfieldCompany Well Contractor Operatiou at 0600 J Size & Depth Last CSG J Days Actual J Depth Today JDepth YesterdaY~ JDaily Cost . Mud Data Pump Data Jweight Ivis. lP.V. IY.P. IGe~s. IP". IW.L. I~'~'/~ ~, Icbm, Cj.-'J ILiner size IspM IGPM IP.S.,. INoz. Ve,. I Bit No. Torque ~/~. / / Rot. Wt. ZOo ~ BOTTOM HOLE ASSEMBLY: (iNCLUDING DRILL PIPE SiZE & GRADE) JDays Predicted Progress t' Drilling Report -- Daily Accum. Cost Ko, A.V.- JHrs. DRLG Time I =. eD ,-.. j ~ G s" m ilo-i,~ i/i J cit.,/.~/~- A.V. - D.C. Slow Pump Rate ICondition Accum. Rot. Hrs. ME ,'~'$ H uJ D/° M.D. IANGLE cf, H'l'l, l° I I DIRECTION T.V.D. J VERT. SEC. N "lo ~ TOTAL COORDINATES NORTH/SOUTH EAST/WEST PORE PRESSURE OVERBALANCE wp c/z./'g-i SHOCK SUB HRS gRILLING JARS HRS 1 ~ I/~ =It:D I I ~ ! F. TIME o~oo -- Zt~5~ ZI~5"'- 7_500 O l'-I~" -ox3o 0'5~,o- off3o 0 H3 o 05'30 -o60o 0600 - OPERATIONS FROM 0600 TO 0600 ACCEPT SPUD .. r'FF_ ltl[I,,t APRO 8 1986 Anchorage Ser. Pers. on Loc. 'z-6- ~o~4~ E-CS ~..-I~o_~ 1- M.~. /- G~ Diesel on2~L~. ~/~ J Diesel Os~ 0 0 ~ Il Die~l~oR~'d. 0 J Gas Us~ (MCF) Temp C.F. VisibiliW J Wind Vel. J Sign~ . /~ ' NORTH A~S~ ~/.~,'~ 5~' ~ ~ ~/ ITOTAL /"~ H Accidents I Date Last Kick Drili J Date Last BOP Test IWater CAMP /-~20 0 From &/~ ,,5'0 /U,.5' 7. DIRECTIONAL SURVr' 1983 DATE TIME DEPTH, FT' ' ' " TAKEN MEASURED 'i'VD DRIFT AZIMUTH SURVEY SURVEY COMPANY IYPE , , , - . 10/5 .,, 645' ,,1-1/2° Rowan Single Shot 1022' 3/4° Rowan Single Shot , ,, ' 1470' , 3/4° ,Rowan Single Shot 2026' 1/4° Rowan ~ Single Shot 10/6 2510' 1-1~2°I Rowan Single Sho ~- 3030' ' 1-1/4° Rowan Single Shot 3511' 1 ° .. Rowan' Single Shot 3800' 1~2° Rowan Single Shot , , 10/8 4300' 1 .o Rowan Single Shot '4800"' 1 '" c ..... Rowan Single Shot 'r ,, 5310' 1-3,~,~° , Rowan·,, , ,Single Shot 5807' 1-1/2c Rowan Single Shot , 5877' 1-3/4° Rowan Single Shot 10/9 6377' 2 o Rowan Single Shot 6854' 2 o Rowan Single Shot .... 7364' ........ 1-1/2° '~·" 'Rowan Sing l'e shot i0/10 7866" ' 1"3/4° ' Rowan ..... Single Shot 'i0/11 8314' 123/-4° ' Rowan '" single Shot -il/21 9136i 2 J o " ' "' Sper~:'Sun" ~ Mihut~ .......... ~urvey uame~ .. 11/24 9242' 2 ¢ .. Sperry Sun ,, 11/28 9354' 2 c Sperry Sun ,, · _11/30 9477'~ 2 "c ,.Sperry Sun ,, ' .. 12/9 9874' 2 c Sperry Sun ,, ... · . · · -- . ... · . . · · · .... c.~t ,~,~ .. THE ANALYSTS ARCO Alaska, Inc. ARCO Explo~ n -Alaska Operations Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276-1215 hand carried S~.-IP LE TRANSMITTAL SHIPPED TO'State of Alaska Ak. Oil & Gas Conservation Comm. 3001.Porcupine Dr. Anchorage, Ak. 99501 Attn: John Boyle DATE' December lq~ 1985 OPERATOR: ARCO Pingut St. #1 (PBU L4-15) N~IE- South Bay at_ ~1 (PBU L3-8) S:%MPLE TYPE' dry ditch NUMBER OF BOXES' 8 SAMPLES SENT' South Bay St. #1: 4000 - 6770' 6770 - 8770'~ 8770 - 8840' 9480 ? 9815' Pingut St. #1: 6000 -- 8220' 8220 - 9190' 9190 - 10600 10600 - 11467 ARCO ALASIC&, INC. P.O. BOX 100360 ANCHORAGE, ALASKA 99510 ATTN: Paleo Lab .... ABV/100 ~ ' RECEIVED BY' DATE: ARCO Alaska, Inc. Is a Subsidiary of AtlanticRichfleldCompany Lisburne Engineering TRANSMITTAL To: State of Alaska Address: 3001 PorcUpine DR. Anchorage, Alaska 99502 From: Date: Attn: Transmitted herewith are the following: Pmm T.~mhmrt . Mr. John Boyle CH log for Lisburne Well: South Bay State #1 (L3-8) Spinner 8-23-85 Run 1 5" GO Return Receipt to: ARCO ~laska Inc. '/' &" A/asR 0il & Gas Cons. Commission Lisburne Engineering Anchorage Attn: Kelly Prockish, AT0-477 P. O. Box 100360 Anchorage, Alaska 99510-0360 Transmittal No.: '~7 ARCO Alaska. Inc. Is a Subsidiary of AllanllcRichfleldCompany ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 26, 1985 Mr. C. V. Chatterton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 RE: Well L2-6, L2-24, L2-28, and L3-8 Monthly Report of Drilling and Workover Operations Dear Mr. Chatterton: Attached are the Monthly Report of Drilling and Workover Operations (Form 10-404) for Lisburne Wells L2-6, L2-24, L2-28, and L3-8 for completion activities during August. If you have any questions or comments please feel free to contact me at 265-6538. Very truly yours, J. L. Harris Area Operations Engineer JLH: JEK: c lh JLH03-2 Attachment cc: J. S. Dayton J. J. Guerrero S. Hasund RECEIVED OCT 0 4 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, !nc. is a Subsidiary of AtlanticRichfieldCompany ALASKA OIL AND GAS CONSERVATION COMMISSION I ONTHLY REPORT rDRILLING AND WOR ' VER OPERATIONS 1. Drilling well [] Workover operation 2. Name of operator ARCO Alaska, Inc ~ 3. Address P.O. Box lO0360'Anch0rage, AK 99510 4. Location of Well at surface 400' FNL, 750' FWL, Sec. 22, TllN, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) RKB 61' 6. Lease Designation and Serial No. ADL 28322 ALK 2320 7. Permit No. 83--143 8. APl Number 50-029-210~-9 9. Unit or Lease Name Prudhoe Bay Unit-Lisburne 10. Well No. L3-8 11. Field and Pool Prudhoe Bay Field Lisb. Urne Oil Pool For the Month of August ,1985 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks 13. Casing or liner run and quantities of cement, results of pressur~ tests 14. Coring resume and brief description 15. Logs run and depth where run 16. DST data, perforating data, Shows of H2S, miscellaneous data Ran Spinner/Capacitance/Pressure/Temp./CCL across perforated interval (8850-9150) with well flowing at 2200 BPD avg. POOH making gradiemt stops. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--I~poFr/fon/this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10~,04 Re.v. 7-1-80 Submit in duplicate ARCO Alaska Inc. New Projects - Lisburne TRANSMITTAL To: State of Alaska Alaska Oil & Gas Conservation Commission Address: 3001 Porcupine DriVe Anchorage, AK 99501 From: Kelly Prockish Date: September 17, 1985 Attn: C. V. Chatterton Transmitted herewith are the following: Final Survey for Lisburne Well L3-8: · (1 Set) Flowing Gradient (Gearhart) 8-23-85 Receipt AcknOwledgement: Return Receipt to: ARCO Alaska Inc. New Projects - Lisburne Attn: Kelly Prockish, AT0-463 P. O. Box 100360 Anchorage, Alaska 99510-0360 Transmittal No.: (,~'¢~;;~' ARCO ,~aska, ~n¢. is a Subsidiary of At~anticRichfie~dCompany *"'~ ¢ ARCO Alaska Inc. New Projects - Lisburne TRANSMITTAL To: State of Alaska Alaska Oil & Gas Conservation Commission -Address: 3001 Porcupine Drive Anchorage, AK 99501 From: Kelly Prockish Date: September 16, 1985 Attn: C. V. Chatterton Transmitted herewith are the following: (1 Set) Data for Lisburne Well L3-8: (South Bay State #1) '"'~.Flowing and Static Survey, 2-28-85 (Gearhart) "~'Pressure Drawdown Survey, 3-1-85 (Gearhart) Flowing Section, Flow Period 3-1-85 through 3-3-85 (Gearhart Plots) "'aFirst Static Area, Shut in Period #1 2-28-85 through 3-1-85 (Gearhart Plots) Second Static Area, Shut in Period #2 3-4-85 through 3-5-85 (Gearhart Plots) Receipt AcknOwledgement: Return Receipt to: ARCO Alaska Inc. New Projects - Lisburne Attn: Kelly Prockish, AT0-463 P. O. Box 100360 Anchorage, Alaska 99510-0360 Alaska Oil & Gas A. nchor~hge Transmittai No.: ~~ ~ ARCO Alaska, inc. is a Subsidiary of AtlanticRichlieldCompany STATE OF ALASKA ALASKA,~.L AND GAS CONSERVATION CC-~MISSION SUNDRY AND REPORT ., ON WELLS DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchoraqe, Ak. 99510 4. Location ckf Well Surface Loc. 400' FNL, 750' FWL, Sec:22, T-11N, R-15E Bottomhole Loc. Same as above 5, Elevation in feet (indicate KB, DF, etc.) p_w~_ 6!' Pad 2!' 12. I 6. Lease Designation and Serial No. ~_nL 28322 7. Permit No. 83-143 8. APl Number 50- 029-21019 9. Unit or Lease Name Pl~R Tln i ~-../T,i 10. Well Number Z_ 11. Field and Poo~ I Prudhoe Bay Field/Lisb. Lisburne Oil Pool 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 [] Puli 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). Plan to change the name. of the subject well from South Bay state No. 1 to L3:~8. 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. RECEIVED ,JUN 2 '~ Alaska 0il & Gas Cons. Commission Anchora99 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Approved by. 0111GINA[ SIGNED BY R,~IRY W. t[BGLEil Title R~_gi nn~ ] V. ngl neet Approved Cop7 ~eturped_ By Order of COMMISSIONER the Commission Submit "Intentions" in Triplicate Form 10-403 Rev. 7-1-80 and "Subsequent Reports" in Duplicate ALASKA OIL AND 8AS GONSE[II/ATION.GOMMISSiON Bill Sheffield, Governor 3ooi PORCUPINE DRIVE ANCHORAGE,ALAOKA 905014'3'102 TELEPHONE(g07) 279,-143:3 ~oc. ~ We ~sh to ~n~ to ~ou~ a~teuC~o~ that the Co~~ou ~e~ ~ece~ed the ~o~o~ ~e~u~ed ~em~ on t~e ~ubjecL which our records indicated was completed ~ Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled-well. Please submit the above missing material. C.' V. ChatterU¢ Chairman lc:C.024 ARCO Alaska, Inc/~" Post Office, .x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 12, 1985 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Attn: .C. V, Chatterton Chairman Dear Sir: Attached are copies of the correlation coregraph on the following three Lisburne wells: South Point State No. 1 Pingut State No. 1 We request that this information is maintained as confidential. If additional assistance is required, please do not hesitate to call. Sincerely, D. K. Chan~'~y Sr. Area Engineer DKC: D~~p Attachments · · . Cons. C0mmissiorl Anchor~,ge ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 15, 1985 Mr. C. V. Chatterton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Anchorage, Alaska 99501 Dear Mr. Chatterton: Subject: Intent to Commingle Production From Extended Production Test At South Bay State No. 1 In accordance with Regulation 20 ACC 25.215, ARCO Alaska, Inc. gives notice to the AOGCC of our intent to commingle hydrocarbon production from the Lisburne formation with production from the Sadlerochit formation during an extended production test at South Bay State No. 1 (L3-8). This test, which is expected to begin in the second quarter of 1985 and continue for approximately eighteen months, will involve surface commingling of Lisburne and Sadlerochit production at Prudhoe Bay Unit Drill Site No. 11. Commingling of production prior to sales metering still allows for the procurement of essential production information while eliminating the need to flare the gas liberated as the oil drops from separator to stock tank conditions. ~This production scenario is similar to the South Point State No. 1 extended production test, which the Commission previously approved. The plan is to utilize a flowline between South Bay State No. 1 and Drill Site No. 11 (DS 11) to flow Lisburne production into the Sadlerochit facilities (see Attachment for a flowline schematic). Production will b~e_~m~_as_u.~red periodically_ by well test facilities at DS 11 to determine the quality and quantity of produced fluids. This measurement will utilize equipment and techniques acceptable to the Commission, such as AP1 Standards, Recommended · :. ARCO Alaska, Inc. is a Subsidiary o! AtlanticRichfieldCompany '3 1/. -'1. Alaska Oil & ~-a~ &'-' u ............ :.ion Mr. C.V. ~atterton March 15, 1985 Page 2 Practices, and Specifications. The procedure complies with Regulation 20 ACC 25.215 which states, "On the surface, the production from one pool may not be commingled with that from another pool except when the quantities from each source of the production are determined by periodic well tests or other measurements." The well is expected to produce 1,260,000 STB of oil and an estimated 2,520 MMCF of gas during the 18 month test. The gas-oil ratio is expected to be below 2,000 SCF/STB initially but will increase to greater than 2000 SCF/STB by the end of the test. The produced Lisburne gas will not be reinjected but rather substituted for Permo-Triassic gas-and Utilized as f~-'within ~t~e Prudhoe BaY Unit. As such, we re u~_p~_D~ctioned waiver of regulation 20 ACC 25.240, which states that "An oil well may not be produced at gas-oil ratios in excess of 2000 SCF/STB without gas reinjection into the reservoir." The South Bay test will be the second extended test performed in the Wahoo. Testing will begin in April, 1985, and run concurrently with the South Point State No. 1 (L2-6) extended test. Previous production tests have been two months maximum duration. The prior tests were only long enough to give hints of potential operational and GOR problems. Also, minimal decline data was obtained during those relatively short flow tests. While sufficient productivity and reservoir data has been obtained to justify an initial development, additional data is needed to efficiently develop and maximize recovery from this complex reservoir. Acquiring this information in the 1985/1986 time frame will allow time to alter the development drilling and potential waterflood scenarios as suggested by the test results. In addition, comparison of South Bay to South Point extended test data will allow evaluation of areal trends yet to be fully defined. The production decline rate after an artificial fra_~c will be evaluated with this test. Request 'f~r test approval is then in accordance with Conservation Order No. 207, Rule 12, which states, "Upon application, the Commission may administratively approve...well production...tests...necessary for the purpose of developing a prudent enhanced recovery method and reservoir depletion program." Ip summary, ARCO Alaska, Inc. gives notice to the AOGCC of its intent to commingle hydrocarbon production at the surface during an extended Lisburne flow test. Commingling will eliminate the need to flare Lisburne gas; however, the Commission's waiver of ~--~0~-~-1 GOR limitation is required. In order to allow adequate time for flowline Mr. C. V.~ ~.atterton March 15, ~985 Page 3 installation and Permo-Triassic facility tie-in, it is requested that the Commission grant this waiver as soon as possible. If you have any questions or comments, do not hesitate to call me at 265-4206. Sincerely, S. Daytor~ JSD:JEK/kyn cc: K. Brown - Director of Division of Oil & Gas G. S Goss - Exxon · / · ATTACtRiENT I:~e. Lc~ c~ Omm~ ~ '85 DS-L3 Ok FLO~LINE SCHEMATIC Lisburne DS L3 =o Prudhoe Bay DS 11 $ou~h Bay $~a~e No. 1 Ex~en,ded Produc=ion Tes~ STO \\ DS-11 .. FS-2 DS-4 Scale: 1" = 2200' PBOC PROPOSED L I SBURNE: O.S. L-3 1113RTH 5/.13P~: 80Rt~./GW ST,%TE Glr .'~ASKA : ,, ALl_SKI OIL AND GAS CONSERVATION COMMISSION Date: December 3, 1984 Bill Sheffield, Governor 3001 PORCUPINE DRIVE ANCHORAGE,ALASKA 99501 '-3192 TEL EP H ON E (907) 279.--1433 , Transmitted via :":'-: .. Quant i ty : -; ::,. . . . . . . Lucille Johnston ARCO Alaska, Inc. Extension Exploration P. O. Box 100360 Anchorage, Alaska 99501 Re: Bud Andrews, AOGCC LIS Tapes- ARCO So.Bay St. f/1 Description of Item are the following: RetUrned herewith: So. Bay Stl f/1 - LIS Tape fJ69125 - 12/16/83'- Run 4 LSS/WF Listing " " " ' " ' ' (See your transmittal dated May 14, 1984) So. Bay St. fJl = LIS Tape ~68857 = 12/17/83 - Run 4 CORBAN : Il' . Listing " " " :9 (See your transmittal dated· Jan. 25, 1 84) ~lease acknowledge receipt by s~gn~ng and returning one copy of th~s letter. Dated: :::7-::.::' i~' ~' ' · . . --.'::.': ::-'.": :': :"': R E-C-E l'V Fi D . · Alaska 0il & Gas Cons. Commission ' : Anchorage Yours very truly, ALASKA OIL & GAs CONSERVATION COMMISSION .~ W'g~l iam ~n A1 en ARCO ALASKA, ZNC. E>:t. cnslon Explomatlon · Date: L //- /;Y- ~ , Transmitted herewith are the following: /2-/7- Receipt Acknowledgment: Return Receipt to: ~CO Alaska, Inc. VExtension Exploration P~O.-Box 100360 Anchorage, Ak. 99510 Alaska Oi! a Gas Cons, Commission _ Anchorage Processed :~~'~ ATTN: Lucille Johnston ATO-1015 ARCO ALASKA, INC. Extension Exploration TRANSMITTAL .'% Date: , I!- I~- ?~ Transmitted herewith are the following: Alaska Oil & (;as Cons. Commission Anchorage Receipt Acknowledgment: Return Receipt ://~RCO Alaska, Inc. Extension Exploration P~O. Box 100360 Anchorage, Ak. 99510 Processed /. ATTN: Lucille Johnston ATO-1015 ' '--~'~'-~. STATE OF ALASKA ALASK AND GAS CONSERVATION ~ iilSSION WELL COMPLETION OR RECOMPLETIONREPORT AND LOG 1. Status of Well Classification of Service Well REVI SI0N C0NF1 DENT ! AL OIL E~x GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of OPerator ~,,~,I~,.1~,~,~~ 7. Perm it Number ARCO Alaska, Inc. 83-143 3. Address ~~/~,'%'~ 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21019 4. Location of well at surface 9. Unit or Lease Name 400' FNL, 751' FWL, Sec.22, TllN, R15E, UN Prudhoe Bay Unit/Lisburne At Top Producing Interval 10. Well Number 400' FNL, 751' FWL, 5ec.22, TllN, R15E, UM At Total Depth 11. Field and Pool 400' FNL, 751~ FWL, Sec,22, T11N, R15E, UM Prudhoe Bay Field/Lisburne 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Li sburne 0i 1 Pool 61' RKBI ADL 28322 12. Date Spudded10/04/83 13, Date T.D. Reached12/16/83 14' Date C°mp" Susp' °r Aband' 115' Water Depth' if °ffsh°re 116' N°' °f C°mpleti°ns3/8/84 N/A feet MSL 1, 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set i 21. Thickness of Permafrost 9973'MD & TVD 9200'MD & TVD YES [] NO [] 2199 feet MDI 1900' (Approx) 22. Type Electric or Other Logs Run SEE ATTACHED SHEET 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD / CASING SIZE! WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# .H-40 Surf 81 ' 30" 1910# Poleset ., 13-3/8" 72.0# L-80 Surf 3781' 17-1/2" 2400 sx Fondu + 400 sx F "C" 11-3/4" 60.0# S-95 1636' 6480' 12-1/4" 500 sx Class "G" cmt + 00 sx CS I 9-5/8" 47.0# S-95/L-8C Surf 8836' 12-1/4" 550 sx Class "G" cmt + ,"00 sx CS I 7" 29.0# L-80 8543' 9700' 8-1/2" 175 sx Class "G" cmt 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 9086' - 9150' 2-7/8" x 5" 8806' 10~015' 8936' - 8918' plus 2-7/8" 8900' - 8918' w/4 spf 26. ACID, FRACTURE, CEMENTsOUEEZE,ETc. 8900' - 8882' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8858' - 8872' 9516' - 9566' 30 bbl Class "G" cmt 9241' - 9270' 10.2 bb] Class "C" cmt 9026' - 9150~ 100 bbl HCL (15%) 9026' - 9150~ 390 bbl oelled diesel + 200.RCN h, 27. N/A PRODUCTION TEST 1.25 SP GR, (see attached Sheet) Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED=1~ OIL-BBL GAS-MGF WATER-BBL OIL GRAVITY-APl {corr) Press. 24-HOUR RATE 28. CORE DATA · Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. See Core Data Sheet Form 10~,07 Submit in duplicate Rev. 7-1-80 DRN/WC21 CONTINUED ON REVERSE SIDE : . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Alapah 9750~ 9690~ (.5S) DST ~1: f/9750'-9955'(ND), 9690'-9895*(SS), Wahoo IV 9516' ' 9456" (55) 20.4 bbls in 7.6 hfs (fluid level increase; Wahoo Ill 9241' 9181' (SS) . no production to surface), 90% H~O, 10% Wahoo II 9086' 9026' (SS) oil, SI ti~: 14 hrs. Wahoo ! 8858' 8798' (SS) DST~2: f/9450'-9666'(MD), 9390'-9606'(SS), 3.8 bbls in 4.7 hrs (fluid level increase; no production to surface), 100% mud filtrate, SI time: 14 hrs. PT~3: f/95I 6' -9566' (MD), 9456' -9506' (SS), 158.9 bbls in 27.8 hfs, 90% Ha0, 10% oil, SI time: .7 hrs. . DST~4: f/9241'-9270' (MD), 9181 '-9210' (SS), 172 bbls in 28.4 hrs, 68% H~0, 32% oil, SI ti~: 14.6 hrs. DST~5: f/9086'-9150' (MD), 9026' -9090' (SS), 78.2 bbls in 13.4 hrs, 100% oil, SI time: 15 hrs. PT~6: f/9026'-9062' (MD) , 8966'-9002' (SS), f/9086'-9150'(MD), 9026'-9090'(SS), 1808.6 ~s in ~ o k,~, ~nn~ ei~ ~ ~: 31. LIST OF ATTACHMENTS 159 hrs. (see attached sheet) Well Hi~nry> A~hm~n~> Core 9ara &heet 32. I hereby certify that the foregoing is true and correct to'the best of my knowledge Sign~~~~~~~ Title Area Drilling Engr. Date ~/~~~ INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10~,07 South Bay State #1 Attachment #1 Section 22: Borehole Televiewer FDC/CNL/Cal/GR DIL/BHCS/GR LDT/CNL/NGT/GR/Cal LSS/GR Dipmeter RFT CBL Csg Caliper CCL/GR HP/Temp/Spinner/Gradio/GR/CCL GR/CCL HP/Temp/GR/CCL GR/CCL GR/Temp HP/Temp Spinner/Temp/HP/Gradio/GR/CCL GR/CCL/Sinker Bars Section 26 continued: 9026' - 9150': 20,000# 100 mesh sand, 112,000# 20/40/ mesh sand, 1496 bbl gelled diesel. ~ 8858' - 9150': 35 sxs 12/20 mesh sand, 2 sxs 100 mesh sand, 135 bbl gelled . · diesel . 8940' - 9150': 70 bbl 15% HCL acid. Section 30 continued: PT #7: f/9026' - 9062' (MD), 8966' - 9002'(SS), f/9086' - 9150'(MD), 9026' - 9090' (SS), 1093 bbl in 24 hfs, 100 % diesel, SI time: 42 hrs. PT #8: f/8882' - 8936'(MD), 8822' - 8876'(SS), f/9026' - 9062'(MD), 8966' - 9002'(SS), f/9086' - 9138' (MD), 9026' - 9078' (SS), 307.7 bbls in 6.5 hfs, 100% diesel, SI time: 3 hrs. PT #9: PT #8 + f/8858' - 8872'(MD), 8798' - 8812'(SS), 477 bbls in 7 hfs, 100% diesel, Si times not available. PT #10:f/8858' - 8872'(MD), 8798' - 8812'(SS), f/8882' - 8936'(MD), 8822' - 8876' (SS), 2427 bbls in 27.5 hfs, 100% diese, SI time: 58 hrs. PT #11:PT #10 + f/9026' - 9033'(MD), 8966' - 8973' (SS), 1508 bbls in 14.8 hfs, 100% oil, SI times not available. DRN/WC21b:tw South Bay State #1 Core 1 8848' - 8907' Core 2 8907' - 8967' Core Data Core 3 8967' - 9015.5 Core 4 9015.5 - 9076 Core 5 9076' - 9136' Core 6 9136' - 9196' Core 7 9196' - 9242' Core 8 9242' - 9299' Core 9 9299' - 9359' Core 10 9359' - 9419' Core 11 9419' - 9477' Core 12 9819' - 9879' Core 13 9879' - 9939' Core 14 9939' - 9955' Limestone and dolomite with minor chert and shale. Poor to excellent oil shows. DRN/WC21c:tw ARCO Alaska, In; Post Offic,..~ox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 14, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Revised Well Completion Report Dear Mr. Chatterton' Enclosed is a revised Well Completion Report for South Bay State #1. The original report incorrectly listed the location of the well. Sincerely, D. R. Norton Lisburne Engineering Aide DRN/83'tw Enclosure XC' T. L. Fithian J. Gruber R. W. Crick D. Chancey L. Moench RECEIVED SEP 1 8 Alaska 0ii & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany r~, ~ '~' STATE OF ALASKA --- C Al_AsK-'~ %IL AND GAS CONSERVATION ( :MISSIONC4r"~c~I i~ WELL COMPLETION OR RECOMPLETIOlll EPOR LOG 1. Status of Well Classification of Service Well REV I S I ON Confi denti al OIL ~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-143 3. Address .~,_~__--lk~,,~,~,~ 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21019 .. ~--~ 4. Location of well at surface A~,~,~-% '~ T 9. Unit or Lease Name 400' FNL, 751' FWL, Sec.22, T11N, R15E, UMC~\'~~ Prudhoe Bay Unit/Lisburne At Top Producing Interval 10. Well Number 400' FNL, 751' FWL, Sec.22, T11N, R15E, UM South Bay State #1 At Total Depth 11. Field and Pool 400' FNL, 751' FWL, Sec.22, TllN' R15E, UM Prudhoe Bay Field/Lisburne 5. Elevation in feet (indicate KB, DF, etc,) I 6. Lease Designation and Serial No. Li sburne 0i 1 Pool 61' RKBI ADL 28322 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. ] 15. Water Depth, if offshore 116. No. of Completions 10/04/83 1 2/16/83 3/8/84I N/A feet MSL[ 1 17. Total Depth (MD+TVD) 18.Plug Back Depth{MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 9973'MD & TVD 9200'MD & TVD YES [] NOJ~]I 2199 feet MD 1900' (Approx) 22. Type Electric or Other Logs Run SEE ATTACHED SHEET 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surf 81 ' 30" 1910# Poleset 13-3/8" 72.0# L-80 'Surf 3781' 17'1/2" 2400 sx Fondu + 400 sx ['F "C" 11-3/4" 60.0# S-95 1636' 6480' 12-1/4" 500 sx Class "G" cmt + ~00 sx CS I 9-5/8" 47.0# S-95/L~80 Surf 8836' 12-1/4" 550 sx Class "G" cmt + ,:00 sx CS I 7" 29.0# L-80 8543' 9700' 8-1/2" 175 sx Class "G" emt 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 9086' - 9150'~ 2-7/8" x 5" 8806' 10,015' 8936' 8918'~ plus 2-7/8" 8900' 8918' w/4 spf 26. ACID, FRACTURE, CEMENT SQuEEzE, ETC. 8900' 8882' DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 8858' 8872' 9516' - 9566' 30 bbl Class "G" cmt 9241' - 9270' 10,2 bbl Class "G" cmt .. 9026' - 9150' 100 bbl HCL 9026' - 9150' 390 bbl oelled die.~el + ?131~ R~N h; 27. N/A PRODUCTION TEST 1.25 SP GR. (see attached Sheet) Date First Production J Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIo TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED.~ OIL~BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr} Press. 24-HOUR RATE I~ 28. CORE DATA , Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. See Core Data Sheet RECEIVED SEP 1 81 14 Alaska Oil & Gas Cons. Commission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 DRN/WC18 CONTINUED ON REVERSE SIDE . ' :' . , . .: ::~'~':' -':-' -, "'t ]-, . ~ - .- '"~ "]~- 29. "]' : ~ :'(~EO[O~¥(~'I~,FIKEFIS' "';: '-'"' ! ~ '"' ~' ;, :; t. '.. '' '" ":'Foible/lATeeN T~ST~" "' :]'''' .' :'" "!'' ':' -.. NAME Include interval tested, pressure data, all fluids recovered and graviiy, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Alapah 9750' 9690' (SS) DST #1 .. f/9750' -9955' (MD), 9690' -9895' (SS), Wahoo IV 9516' 9456' (SS) 20.4 bbls in 7.6 hfs (fluid level increase; Wahoo Ill 9241' 9181' (SS) no production to surface). Wahoo II 9086' 9026' (SS) DST#2: f/9450'-9666'(MD), 9390' -9606! (SS), Wahoo I 8858' 8798' (SS) 3.8 bbls in 4.7 hfs (fluid level increase; no production to surface). PT#3: f/9516'-9566' (MD) , 9456' -9506' (SS) , 158.9 bbls in 27.8 hrs. DST#4: f/9241 '-9270' (MD) , 9181 '-9210' (SS), 172 bbls in 28.4 hrs. DST#5: f/9086'-9150' (MD), 9026'-9090' (SS), 78.2 bbls in 13.4-hrs. PT#6: f/9026'-9062' (MD), 8966'-9002' (SS), f/9086'-9150'(MD), 9026'-9090' (SS), 1808.6 bbls in 59.2 hrs. (see attached sheet) 31. LIST OF ATTACHMENTS Well Hi story~ Attachment; Core Data Sheet 32. I hereby certify that the foreg~g is true and'correct to the best of my knowledge H ~~ Area Drilling Engr. Signed ~. l ' Tide Date · . .,, INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none" Form 10~407 ADDENDUM WELL: 8/29/86 L3-8 RU DA, ?U Lub/CCL/2.25" blind box/3 sinker bars, RIH to 8700'. Gyro terminated, POH w/tls. RD DA. ])rilling Supervisor ~--~ STATE OF ALASKA ALASKi ~:JL AND GAS CONSERVATION (- ~IMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LO Classification of Service Well 1. Status of Well . CONF I DENT I AL OIL [~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator ~,~,~.,~___1~ ~,~.. 7. Permit Number ARCO Alaska, .Inc. : 83-143 3. Address ' ~ - f,__l~,,~l.,,%'".~,~ 8. APl Number P. 0. Box 100360, Anchorage, AK 99510. - ' 50- 029-21019 4. Location of well at surC~:e~,~' - '"- 9. Unit or Lease Name 400' FNL, 750' F~L, VSec.22,: TllN, R15E,,UM Prudhoe Bay Unit/Lisburne At Top Producing Inter~ ~.~' ..... ~ :. ' 10. Well Number 400' FNL, 750' F~L, Sec.22~ TllN, R15E, UM South Bay State #1 At Total Depth IA) ~-~ - ' ' 11. Field and Pool 400' FNL, 750' F~4~,-Sec.22~ T11N, R15E~ UM Prudhoe Bay Field/Lisburne 5. Elevation in feet (indicate KB, DF, etc.)~ '~ I 6. Lease'Designation and Serial No. Li sburne 0i 1 Pool 61' RKBI ADL 28322 12. Date Spudded10/04/83 13' Date T'D/Reached- 1-2/16/83 ' .14' Date C°mp" Susp' °r Aband' J 15' Water Depth' if °ffsh°re 116' N°' °f C°mpleti°ns3/8/84 N/A feet MS L 1 17' T°tal Depth (MD+TVD)18~Plug Back Depth (MD~TVD)19' Directi°nal SurveY9973'MD & TVD 92001MD & TVD :YES [] NO' ] 20. Depth where SSSV set2199 feet MD I21' Thickness °f Permafr°st1900' (Approx) 22. Type Electric or Other Logs Run SEE ATTACHED SHEET 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surf 81 ' 30" 1910# Poleset 13-3/8" 72.0# L-80 Surf 3781' 17-1/2" 2400 sX Fondu + 400 sx F F "C" 11-3/4" 60.0# S-95 1636, 6480, 12-1/4,, 500 sx Class ,,G,, cmt +3.00 sx PF ,,C,, - 9-5/8" 47.0# S-95/L-80 Surf 8836' 12-1/4" 550 sx Class "G" cmt + ~00 SXS CS I 7" 29.0# L-80 8543' 9700' 8-1/2" 175 sx Class "G" cmt / 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 9086' - 9150'"~ 2-7/8" x 5" 8806' 10~015' 8936' 8918't plus 2-7/8" 8900' 8918' w/4 spf , 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 8900' 8882' DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 8858' 8872' 9516' - 9566' 30 bb] C]ass "G" cmt 9241' - 9270' 10,2 bbl Class "G" cmt 9026' - 9150' 100 bbl HCL (15%) 9026' - 9150' 390 bb] gelled diese] + 200 RCN b~ 27. N/A PRODUCTION TEST 1,25 SP GE, (see attached Sheet) Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of l ithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. See Core Data Sheet i~ ~ , ~ ~ ~..: ~,~, - ~ :,~. Form 10-407 Submit in duplicate Rev. 7-1~80 DRN/WC15 CONTINUED ON REVERSE SIDE .~ ¥:!GEOLO~i'CMARKERS.. '-i* .... :: :': ' :': : FORMATION TESTS -,. -. NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTF GOR, and time of each phase. _ Alapah 9750' 9690' (SS) DST #1: f/9750'-9955'(MD), 9690'-9895'(SS), Wahoo IV 9516' 9456' (ss) 20.4 bbls in 7.6 hfs (fluid level increase; Wahoo Ill 9241' 9181' (SS) no production to surface). Wahoo II 9086' 9026' (SS) DST#2: f/9450'-9666'(MD), 9390' -9606' (SS), Wahoo I 8858' 8798' (SS) 3.8 bbls in 4.7 hrs .(fluid level increase; no production to surface). PT#3: f/9516'-9566' (MD), 9456'-9506' (SS), 158.9 bbls in 27.8 hrs. DST#4: f/9241 '-9270' (MD) , 9181 '-9210' (SS), 172 bbls in 28.4 hrs. DST#5: f/9086'-9150' (MD), 9026'-9090' (SS), 78.2 bbls in 13.4 hrs. PT#6: f/9026'-9062' (MD), 8966"-9002' (SS), f/9086'-9150'(MD), 9026'-9090' (SS), 1808.6 bbls in 59.2 hrs. (see attached sheet) 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge . ~~ Area Drilling Engr. Signed ''~' Z' Title Date. .3 ~ INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska.' Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 South Bay State CONFIDENTIAL Attachment #1 Section 22: Borehole Televiewer FDC/CNL/Cal/GR DIL/BHCS/GR LDT/CNL/NGT/GR/Cal LSS/GR Dipmeter RFT CBL Csg Caliper CCL/GR HP/Temp/Spinner/Gradio/GR/CCL GR/CCL HP/Temp/GR/CCL GR/CCL GR/Temp HP/Temp Spinner/Temp/HP/Gradio/GR/CCL GR/CCL/Sinker Bars Section 26 continued: 9026' - 9150': 20,000# 100 mesh sand, 112,000# 20/40~ mesh sand, 1496 bbl gelled diesel. 8858' - 9150': 35 sxs 12'/20 mesh sand, 2 sxs 100 mesh sand, 135 bbl gelled diesel. 8940' - 9150': 70 bbl 15% HCL acid. Section 30 continued: PT #7: f/9026' - 9062'(MD), 8966' - 9002'(SS), f/9086' - 9150'(MD), 9026' - 9090'(SS), 1093 bbl in 24 hrs. PT #8: f/8882' - 8936'(MD), 8822' - 8876'(SS), f/9026' - 9062'(MD), 8966' - 9002'(SS), f/9086' - 9138' (MD), 9026' - 9078'(SS), 307.7 bbls in 6.5 hrs. PT #9: PT #8 + f/8858' - 8872'(MD), 8798' - 8812'(SS), 477 bbls in 7 hrs. PT #10:f/8858' - 8872'(MD), 8798' - 8812'(SS), f/8882' - 8936' (MD), 8822' - 8876'(S5), 2427 bbls in 27.5 hrs. PT #11:PT #10 + f/9026' - 9033'(MD), 8966' - 8973'(55), 1508 bbls in 14.8 hrs. DRN/WC15b:tw South Bay State #1 Core Data CONFIDENTIAL Core 1 8848' - 8907' Core 2 8907' - 8967' Core 3 8967' - 901 5.5 Core 4 9015.5 - 9076 Core 5 9076' - 9136' Core 6 9136' - 9196' Core 7 9196' - 9242' Core 8 9242' - 9299 Core 9 9299' - 9359 Core 10 9359' - 9419 Core 11 9419' - 9477 Core 12 9819' - 9879 Core 13 9879' - 9939 Core 14 9939' - 9955 Limestone and dolomite with minor chert and shale. Poor to excellent oil shows. DRN/WCl 5c: tw ARCO 011 and Gas Company Well History - Initial Report- Dally Instant. ne: Prepare and lubmit tfte "IMII_ !llle/f" on the .fir~. Wedneadey after i wall I. spudded or workover operations are ,tar,ed. Dally work prior te a~ldtl~r.~lldd be lummlnzeo on the form giving Incluilve date. only. District I County. parish or borough I State Alaska North Slope Borough Alaska Well no. Field ILea~ or Unit South Bay Prudhoe Bay ~ ADL #28322 ' ~c~c !,~I Auth. or W.O. no. /Title AFE 700550 Drlg Lisburne/7015~l Coring Drill, Core, Complete & Perforate Operator IARCO w.I. ARCO Alaska, Inc. Spudded or W.O. begun IDate IHour IPrior status if a W.O. Spudded I 10/04/83 I 1030 Hrs. I N/A Date and depth aa of 8:00 a.m. 10/04/83 10/05/83 10/06/83 10/07/83 10/08/83 thru 10/10/83 Complete record for each day reported The above la correct 20" @ 115' Accept rig @ 0400 hrs, 10/04/83. NU 20" Hydrl & diverter ins. 20" @ 115' 2688', (2568'), Drlg 17½" hole Wt. 9.2, Vis 210, PV 14, YP 55, PH 9.0, Sol 4, Oil 0 Fin NU 20" Hydrl. Spud well @ 1030 hrs, 10/4/83. Drl 17½" hole to 2688'. Surveys: 645', 1-1/2° 1470', 3/4° 2026', 1/4° 13-3/8" @ 3781' 3800', (1112'), TOH w/stab-in sub Wt. 9.5, Vis 180, PV 8,. YP 48, PH 8.5, Sol 8, Oil 0 Drl 1.7½" hole to 3800', CBU, 15 std wiper trip, no fill, TOH. RU & rn 94 jts, 13-3/8", 72#, L-80 butt csg w/FS @ 3781', FC @ 3701'. TIH w/stab-in sub, stab into FC. Surveys: 645', 1-1/2° 1022', 3/4° 2026', 1/4° 2510', 1-1/4° 3030', 1-1/4° 3800', 1/2° 13-3/8" @ 3781' 4291', (491'), Drlg Wt. 8.4, Vis 28, PH 8.0 POOH, LD stab-in sub. ND diverter sys, NU &tst BOPE. PU bit/BHA, RIH, tag cmt @ 3671', drl cmt to FC, tst csg to 1500 psi. DO FC, FS + 10' new hole to 3810' Conduct formation leak-off tst to 12.7 ppg EMW. Drl 12½" hole to 4291'. 13-3/8" @ 3781' 8090', (3799'), Drlg Wt. 9.8, Vis 42, PH 14, YP 5, PH 11, Sol 10, Oil 0 Drl & surv 12¼" hole to 5877', POOH. RIH w/new bit, rm out undergage hole 80' to btm. Drl & surv to 7866', POOH. RIH w/new bit, rm out undergage hole 60' to btm. Drl 12¼" hole to 8090'. Surveys: 4300', 1° 4800', 1° 5310', 1-3/4° 5807', 1-1/2° 5877', 1-3/4° 6377', 2° 7364', 1-1/2° 7364', 1-1/2° 7866', 1-3/4° RECEIVED AUG 2 ? 19 84 lla~r~ Oil &a..~..~.~as Cons. Commissiort. Signature For form pre~re~lon aflcr~:llltributle~, · ee Procedures Manual,/"Se4~lofl 10, Drilling, Pagaa 88 and 87. 1/26/84 Drilling Superintendent 5O% AR3B-459-1-D INumber ail daily well history form. consecutively aa they Am prepared for alCh wall. ARCO Oil and Gas Company Daily Well History--Interim Inetractionl: This Iorm is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach deSCription of all cores. Work ;)erformed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form· 1) Submit -Illterim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the weak in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. ICounty or Parish )Slate District Alaska North Slope Borough Alaska Field ILease or Unit IWell no. Prudhoe Bay ADL #28322 I SBS #1 Date and depth as of 8:00 a.m. 10/11/83 10/12/83 10/13/83 10/14/83 10/15/83 10/16/83 Complete record for each day while drilling or workover in progress 13-3/8" @ 3781' 8314', (224'), RIH Wt. 9.9+, Vis 38, PV 14, YP 6, PH 11.5, Sol 10, Oil 0 Drl 12¼'! hole to 8314', circ, 15 std short trip, C&C f/logs. RU & rn DIL/SP/BHCS/GR f/8304'-3781' RD loggers. RIH. Survey: 8314', 1-3/4° 13-3/8" @ 3781' 8330', (16'), Underrm'g @ 5714' Wt. 10, Vis 42, PV 14, YP 5, PH 11, Sol 10, Oil 0 Fin-RIH, drl 12¼" hole to 8330', CBU, POOH. PU underrm'r/bit, RIH to 13-3/8" shoe @ 3781', underrm hole to 13-1/2" f/3781'-5714'. 13-3/8" @ 3781' 8330', (0'), RIH w/bit & underrm'r Wt. 10.2, Vis 40, PV 16, YP 5, PH 11.5, Sol 12, Oil 0 Underrm hole to 13~" f/5714'-6414', POOH. Chg cutter arms, re-tm 6136'-6414'. Underrm hole to 13½" f/6414'-7490', POOH. Chg cutter arms,.RIH. 13-3/8" @ 3781' 8330', (0'), TOH w/bit & underrm'r Wt. 10.5, Vis 46, PV 16, YP 6, PH 11.6, Sol 14, Oil 0 Fin TIH, rm 40' to 7490', underrm hole to 13½" f/7490'-8330', CBU, att to make short trip. Circ, raise mud wt f/10.2 to 10.5 to contrl sloughing shale. Circ hi-vis pill, 10 std short trip, CBU, TOH. Prep to rn 11-3/4" lnr. 13-3/8" @ 3781' 8330', (0'), Soak & wrk stuck lnr Wt. 10.5, Vis 44, PV 16, YP 6, PH 11.4, Sol 14, Oil 0 Fin TOH. RU & rn 119 jts, 11-3/4", 60#, Hydrl SFJ-P, incl'g BOT hgr & flt equip, on 5"'DP. Stuck lnr @ 6480'. Wrk stuck pipe w/full circ. Hole taking some fluid. 13-3/8" @ 3781' 8330', (0'), Wrk stuck lnr Wt. 10.5, Vis 45, PV 16, YP 5, PH 11.2, Sol 15, Oil 1 Spot pipe lax pill to cover 11-3/4" lnr. Pipe lax pill in place 27 hours. 11-3/4" lnr shoe @ 6480' TOL @ 1636' FC @ 6443' LC @ 6405' The above is correct Signature For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 AR3B-459-2-B IDate ITiile 1/26/84 Drilling Superintendent RE£EIVED AUG 2 · Alaska Oil & Gas Cons. Commission Arich0r~ber a,, ..,,. ~.,, his,o~ , ........... fively J~ they a~e prepared for each well. IPag~ no. ARCO Oil and Gas Company ~, Daily Well History--Interim Inalructionl: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reporled on "lnlerim" 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 string until completion. District Field Alaska Counly or Parish ISrate North Slope Borough Lease or Unit ADL #28322 Prudhoe Bay Alaska IWell no. SBS t~1 Date and depth as of 8:00 a.m. 10/17/83 10/18/83 10/19/83 10/20/83 10/21/83 10/22/83 Complete record for each day while drilling or workover in progress 11-3/4" @ 6480' 8330', (0'), PU 6-1/4" DC Wt. 9.7, Vis 38, PV 12, YP 4, PH 11, Sol 13, Oil 1 Soak & wrk stuck lnr. Circ & reduce mud wt f/10.5 ppg to 9.7 ppg. No pipe movement. Cmt 11-3/4" lnr w/500 sx C1 "G" w/l% CFR-2 & .15% HR-7. 11-3/4" lnr shoe @ 6480' TOL @ 1636' FC @ 6443' LC @ 6405' 11-3/4" @ 6480' 8330', (0'), WOC Wt. 9.6, Vis 34, PV 12, YP 4, PH 11, Sol 14, Oil 2 WOC. MU 13-3/8" RTTS, RIH to sqz 11-3/4" lnr lap. Set RTTS @ 1550', est breakdn rate @ 1~ bbls/min @ 800 psi. M&P 200 sx PF "C" @ 15.6 ppg. Displ cmt, leaving 3 bbls on TOL. Final displ rate of 1~ bbl/min @ 900 psi. Sqz 32 bbls into lnr lap. CIP @ 1930 hrs, 10/17/83. Rel RTTS, circ, TOH. 11-3/4" @ 6480' 8340', (10'), Cln'g mud pits Wt. 10.3, Vis 45, PV 9, YP 16, PH 12.5, Sol 15, Oil 0 WOC. TIH, CO cmt 1630'-1646', circ cln, TOH. Chg bits, TIH, tag top of cmt @ 6226', DO cmt, LC, FC, FS & cmt to 6282', circ. Conduct leak-off tst to 13.0 ppg EMW. TIH, drl 10' new hole to 8340', C&C, 8 std short trip, TOH into 11-3/4" lnr. Dump mud pits. Cln mud pits f/ bland mud sys. 11-3/4" @ 1636'-6480' 8344' (correction), MU coring assy Wt. 10.5, Vis 83, PV 39, YP 35, PH 8.6, Sol 10, Oil .5 Fin cln mud pits, mx bland mud. TIH & displ well f/Ligno mud to bland mud. Circ, wt up sys to 10.5 ppg, TOH. MU core bbl. 11-3/4" @ 1636'-6480' 8371', (27'), Redress core bbl Wt. 10.5, Vis 66, PV 35, YP 25, PH 8+, Sol 11, Oil trc RIH, core #1, 8344'-8371', core bbl jammed, POOH, rec'd 27' 11-3/4" @ 1636'-6480' 8387', (16'), Core #3 Wt. 10.6, Vis 61, PV 32, YP 21, PH 8+, Sol 12, Oil trc Redress core bbl, circ to cln hole. Core #2, 8371'-8379', cut 8', rec'd 4'. Core #3, 8379'-8387', incompl. The above is correct Signature For form prepar~t~n and-di~trJb-ul~n see Procedures Manual Section 10(' Drilling, Pages 86 and 87 Date 1/27/84 ]Title AR3B-459-2-B Drill~nE Superintendent J ECEIVEI) AUG 2 7 ,qRA Alaska Oil & 6as Cons. Commissio~ Anchorage Number all daily well history forms conseculively as they are prepared for each well. JPag~ no. ARCO Oil and Gas Company (~, Daily Well History--Interim Inelfuctlone: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work pedormed. 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 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 strin§ until completion. ICounty or Parish State District Alaska North Slope Borough I Alaska Lease or Unit Well no. Field Prudhoe Bay ADL #28322 SBS #1 Date and depth Complete record for each day while drilling or workover in progress as of 8:00 a.m. 10/23/83 10/24/83 10/25/83 10/26/83 10/27/83 10/28/83 10/29/83 11-3/4" @ 1636'-6480' 8415', (28'), Core #4 Wt. 10.6, Vis 58, PV 31, YP 23, PH 8, Sol 13, Oil trc Fin core #3 8379'-8415', rec'd 12'. Core #4, 8391'-8415', incompl. 11-3/4" @ 1636'-6480' 8447', (32'), CBU Wt. 10.6, Vis 60, PV 41, YP 22, PH 8, Sol 12, Oil trc Fin core #4, 8391'-8416', rec'd 25'. Core #5, 8416'-8447', CBU. 11-3/4" @ 1636'-6480'' 8462', (15'), Core #7 Wt. 10.6, Vis 58, PV 35, YP 23, PH 8, Sol 12, Oil trc CBU, POOH, rec'd 31' of core #5. RIH, wsh & rm 100' to btm. Core #6 (pressure core #1), 8447'-8456', rec'd 4'. Core #7 (pressure core #2), 8456'-8462', incompl. 11-3/4" @ 1636'-6480' 8474', (12'), POOH w/core #8 (PC #3) Wt. 10.6, Vis 56, PV 28, YP 15, PH 7.2, Sol 12, Oil trc Fin Core #7 (PC #2), 8456'-8465', rec'd 9'. RIH, rm 8263'- 8447', rm 6½" hole to 8½" hole f/8447'-8465', C&C mud f/cont'd coring. Cut core #8 (PC #3) 8465'-8474', POOH. 11-3/4" @ 1636'-6480' 8481', (7'), RIH f/core #10 Wt. 10.6, Vis 64, PV 31, YP 18, PH 7+, Sol 12, Oil trc Rec'd 9' of Core #8 (PC #3). Core #9 (PC #4), 8474'-8481', core bbl jammed, POOH, rec'd 7'. 11-3/4" @ 6480' 8571', (90'), Core #11 Wt. 10.6, Vis 60, PV 34, YP 17, PH 7.8, Sol 12, Oil trc Fin TIH, rm 8449'-8481'. Cut Core #10, 8481'-8538', rec'd 56' TIH, rm 8508'-8538' Core #11, .8538'-8571', incompl. 11-3/4" @ 6480' 8594', (23-'), TOH w/core #13 (PC #6) Wt. 10.7, Vis 58, PV 34, YP 17, PH 7.9, Sol 10, Oil trc Fin cutting core #11, 8538'-8576', rec'd 38'. Core #12 (PC #5), 8576'-8585', cut 9'. Core #13 (PC #6), 8585'-8594', cut 9', TOH. The above is correct Signature/~,/)M ~'~"~3 J Date For form ~par-ation and di,~tributi0n see Procedures Manual Sec:lion 10, Drilling, Pages 86 and 87 AUG 2 ? Alaska Oil a Gas Cons AR3B-459-2-B I Title 1/27/84 Drilling Superintendent AUG 2 Alaska Oil & Gas Cons. Commissior~ Anchorage Number all daily well history forms consecutively [Pag~ no. as they are prepared for each well. ARCO Oil and Gas Company Daily Well History--Interim Instruclione: This form is used during drilling or workover operations. If testing, coring, or pedorating, show formation name in describing 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 "lntarim" sheets when filled out bur 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 string until completion. District ICounty°r Parish Istate Alaska North Slope Borough Field ~Lease or Unit Prudhoe Bay I ADL #28322 Alaska Well no. SBS #l Date and depth as of 8:00 a.m. 10/30/83 thru 10/31/83 11/01/83 11/02/83 11/03/83 11/04/83 11/05/83 Complete record for each day while drilling or workover in progress 11-3/4" @ 6480' 8618', (24'), TOH w/core #14 Wt. 10.7, Vis 60, PV 32, YP 19, PH 7.8, Sol 10, Oil trc Fin TOH w/cor~ #13 (PC #6). TIH w/8~" bit, rm 6½" hole f/ 8576'-8594', C&C, pmp hi-vis pill. TIH, core #14, 8594'- 8618', rec'd 24'. Cut core #15 (PC #7), 8618'-8626', cut 8' Core #16 (PC #8), 8626'-8635', cut 9'. 11-3/4" @ 6480' 8644', (9'), Core #18 (PC #10) Wt. 10.7, Vis 54, PV 19, YP 9, Sol 11, Oil trc TIH w/8½" bit, rm press core rn 8618'-8635', CBU. TIH, core #17 (PC #9), 8635'-8644', cut 9'. Prep to cut core #18. 11-3/4" @ 6480' 8685', (41'), Coring Wt. 10.7, Vis 59, PV 22, YP 12, PH 7.9, Sol 11, Oil trc Wsh & rm to btm. Core #18 (PC #10), 8644'-8653'. Core #19, 8653'-8685', incompl. 11-3/4" @ 6480' 8844', (209'), C&C f/logs Wt. 10.7, Vis 60, PV 22, YP 12, PH 7.8, Sol 12, Oil trc Fin core #19, 8653'-8713', rec'd 58'. TIH w/8½" bit, drl to 8844', circ, 8 std short trip, C&C f/logs. 11-3/4" @ 6480' 8844', (0'), POOH w/Bkr tst pkr Wt. 10.7, Vis 53, PV 20, YP 11, PH 7.8, Sol 12, Oil trc C&C f/logs, POOH. RU & rn DIL/BHCS/GR/SP, LDT/CNL/GR/CAL, DLL/GR. Rn RFT tl (10 press stops in Sadlerochit). Perf 11-3/4" x 13-3/8" csg 2610'-2630' @ 4 SPF. RIH w/Bkr Model "C" pkr & set @ 2755' Close ann & pmp in DP & csg ann to ck perfs. Breakdn @ 800 psi - 30 SPM. Rel pkr & POOH. 11-3/4" @ 6480' 8844', (0'), Wsh dn w/12¼" underrm'r @ 6964' Wt. 10.7, Vis 55, PV 22, YP 13, PH 7.8, Sol 12, Oil trc LD tst pkr, PU 9-7/8" bit, RIH, rm 8½" hole to 9-7/8" f/ 8340'-8428', circ out gas cut mud. Rm 8½" hole to 9-7/8" f/ 8428'-8621', POOH. RIH, rm 11-3/4" csg f/6233'-6480'. The above is correct Signature For form preparation ~n-d d~tribution see Procedures Manual SeMion 10. Drilling, Pages 86 and 87 Date ]Title 1/28/84 Drilling Superintendent AR3B-45~2-B Number all daily well his{ory forms consecutively as they are prepared for each well. IPag; no. ARCO Oil and Gas Company Daily Well History--Interim Inltruclleel: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing 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 represenlative 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 string until completion. District ICounty or Parish IState Alaska North Slope Borough Field Lease or Unit Prudhoe Bay ADL #28322 Complete record tor each day while drilling or workover in progress Date and cleptl~ as of 8:00 a.m. 11/06/83 11/07/83 11/08/83 11/09/83 11/10/83 11/11/83 11-3/4" @ 6480' 8844', (0'), Wsh & rm w/underrm'r @ 7670' Wt. 10.7+, Vis 53, Pv 21, YP 11, PH 9, Sol 12, Oil trc Wsh dn w/12¼" underrm'r f/6964'-7593', hole packing off. PU, wsh & wrk pipe, hole bridged off @ 7588', POOH w/ underrm'r. PU 8½" bit, RIH, rm thru bridge @ 7588', single in to 8844', CBU, POOH. PU underrm'r, RIH. 11-3/4" @ 6480' 8844', (0'), Underrm'g hole to 12¼" @ 8490' Wt. 10.7+, Vis 55, PV 23, YP 13, PH 8.9, Sol 12, Oil trc Wsh & rm w/12¼" underrm'r, 7670'-8330'. Hole trying to pack off 8173'-8224', wrk & wsh thru. Underrm hole to 12¼" f/8407'- 8490t. 11-3/4" @ 6480' 8844', (0'), RIH w/underrm'r Wt. 10.7, Vis 55, PV 25, YP 12, PH 9.1, Sol 12, Oil trc Underrm hole to 12¼" f/8490'-8693', POOH to chg cutter arms on underrm'r. 11-3/4" @ 6480' 8844', (9'), Rm'g @ 7660' Wt. 10.7, Vis 49, PV 20, YP 12, PH 9, Sol 12, Oil trc Underrm hole to 12½" f/8693'-8844' & 6482'-7660'. Re-rm @ 7470', 7516'-7555' & 7660'. Hole sloughing, raising MW to 10.9 ppg. 11-3/4" @ 6480' 8844', (0'), Rm'g @ 8500' Wt. 10.9, Vis 48, PV 18, YP 8, PH 11, Sol 12, Oil 3 Rm hole w/12¼" underrm'r to 8844', rm'g out bridge areas 7470', 7516', 7555', 7675', 7799', 7856', 8194' & 8515'. MW to 10.9 ppg. CBU. Rm on btm @ 8844'. Alaska 9-5/8" @ 8836' 8844', (0'), Prep to lnd csg Wt. 10.8, Vis 51, PV 28, YP 14, PH 11.3, Sol 12, Oil 3 Rm 8468'-8844' TD, CBU, TOH. RU & rn 167 jts, Hydrl SFJP S-95 & 40 jts, L-80 butt ERW. Lnd w/FS @ 8836', FC @ 8746'. Cmt w/550 sx C1 "G". Used top & btm plugs. Displ cmt w/rig pmp, bump plug. RU to set csg on emergency slips. Raise Well no. SBS #1 The above is correct For form prepa~aiio~ and dJstr~ution see Procedures Manual Sectiolil 10, Drilling, Pages 86 end 87 IOate [Title 1/28/84 Drilling Superintendent Alaska 0it & Gas Cons. A:;s?.,craoe, AR3B-45~2-B INumber all daily well history forms conseculively as they are prepared for each well. IPag~ no. ARCO Oil and Gas Company Daily Well History--Interim Instrucllone: This form is used during drilling or workover operations. I! testing, coring, or perforating, show formation name in describing 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 "FIital" form. 1) Submit "lnterillt" 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 string until completion. District ICounty or Parish Field Prudhoe Bay #28322 Itease or Unit ADL Date and depth Complete record for each day while drilling or workover in progress as of 8:00 a.m. 11/12/83 Alaska North Slope Borough IState Alaska Well no. SBS t~1 11/13/83 11/14/83 11/15/83 11/16/83 11/17/83 11/18/83 11/19/83 9-5/8" @ 8836' 8847', (3'), Cln'g pits f/Oil Faze mud Set csg on Gray emergency slips. Cut off csg, instl primary & secondary pack-offs. NU BOPE, set & tst 9-5/8" pack-offs to 3000 psi. TIH w/8½" bit, tag top of cmt@ 8742', tst csg to 3000 psi. Drl flts & formation to 8847'. Perform leak-off tst to 13.1 ppg EMW. Dump mud pits, cln'g f/oil faze mud. 9-5/8" @ 8836' 8852', (5'), Cutting Lisburne Core #1 Wt. 9.5, Vis 57, PV 24, YP 12, PH --, Sol 9, Oil 90.2 Chg Over to oil faze mud. Pre-flush w/150 bbls used oil faze & 50 bbls diesel. Cut Lisburne core #1, 8847'-8852', incompl. 9-5/8" @ 8836' 8907', (55'), TOH w/core #1 Wt. 9.6, Vis 53, PV 24, YP 10, Sol 10, Oil 89.2 Fin cut Lisburne core #1, 8847'-8907', TOH. 9-5/8" @ 8836' 8955', (48'), Cut Lisburne core #2 Wt. 9.6, Vis 53, PV 28, YP 10, PH .5, Sol 10, Oil 89.2 LD core #1, service core bbl. Core #2, 8907'-8955', incompl. Per ARCO Geologist: Lisburne top @ 8859'. 9-5/8" @ 8836' 8986', (31'), Cutting core #3 Wt. 9.6, Vis 55, PV 20, YP 8, PH .5, Sol 10, Oil 89.2 Fin Lisburne core #2, 8907'-8967', rec'd 60'. Lisburne core #3, 8967'-8986', incompl. 9-5/8" @ 8836' 9015', (29'), TIH f/Lisburne core #4 Wt. 9.6, Vis 55, PV 17, YP 9, PH .05, Sol 10, Oil 89.5 Fin Lisburne core #3, 8967'-9015', rec'd 48.5'. TIH f/core #4. 9-5/8" @ 8836' 9071', (56'), Lisburne core #4 Wt. 9.6, Vis 53, PV 16, YP 8, PH .05, Sol 10, Oil 89.6 RIH, cut Lisburne core #4, 9015'-9071', incompl. 9-5/8" @ 8836' 9107', (36'), Cutting Lisburne core #5 Wt. 9.6+, Vis 54, PV 17, YP 8, Sol I0, Oil 89.6 Fin Lisburne core #4, 9015'-9076', rec'd 61'. 'Lisburne core #5, 9076'-9107','lncompl. The above is correct Signature For form preparation and di~lliribution see Procedures Manual SeclJon 10, Drilling, Pages 86 and 87 Date [Title 1/28/84' Drilling Superintendent AR3B-459-2-B INumber all daily well history forms Consecutively IPag~ no. as they are prepared for each well. ARCO Oil and Gas Company Daily Well History--Interim Inatructionl: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing 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 "Flnll" 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 string until completion. District Field Date and depth as of 8:00 a.m. Alaska ICounty or Par~ah North Slope Borough I Itease or Unit Prudhoe Bay ADL #28322 Complete record for each day while drilling or workover in progress 11/20/83 11/21/83 11/22/83 11/23/83 11/24/83 11/25/83 JState Alaska Well no. SBS #1 9-5/8" @ 8836' 9144', (37'), Cutting Lisubrne core #6 Wt. 9.6+, Vis 57, PV 18, Sol 11, Oil 88.5 Fin Lisburne core #5, 9076'-9136', rec'd 60'. core #6, 9136'-9144', incompl. Cut Lisburne 9-5/8" @ 8836' 9196', (52'), CBU Wt. 9.7, Vis 56, PV 20, YP 9, Sol 12~ Oil 87.6 Lisburne core #6, 9136'-9181', hole started taking mud. Hole std'g full w/pmp off. Hole taking approx 40 bbl/hr w/pmp on. String in LCM (approx 10 ppb fine Mica + approx 5 ppb nut plug) & circ around. Hole healing up. Est loss @ approx 85 bbls. Fin core #6 to 9196'. Lost approx 15 bbls f/0000 hrs to 0200 hrs. Lost approx 5 bbls f/0200 hrs to 0600 hrs. At 0600 hrs, CBU & prep to POOH w/core #6. Survey: 9136', 2°, N74W 9-5/8" @ 8836' 9218', (22'), Cutting Lisburne core #7 Wt. 9.6+, Vis 61, PV 19, YP 8, Sol 12, Oil 87.6 CBU, POOH, rec'd 45' Lisburne core #6. Tst BOPE. RIH, brk circ @ 6000', wsh & rm to btm - 1' fill. Cut Lisburne core #7, 9196'-9218', incompl. Total est mud loss last 24 hrs : 30 bbls; 20 bbl during trip, 10 bbl while circ & coring. No loss since 2200 hrs. 9-5/8" @ 8836' 9242', (24'), RIH Wt. 9.6+, Vis 63, PV 19, YP 12, Sol 12, Oil 87.4 Core Lisburne #7, 9196'-9242', CBU, POOH, rec'd 55' (rec'd approx'15' lost f/last core - lost 6' f/btm this core). RIH. No mud loss last 24 hrs. 9-5/8" @ 8836' 9290', (48'), Lisburne core #8 Wt. 9.6+, Vis 63, PV 20, YP 10, Sol 12, Oil 87.1 RIH, Lisburne core #8, 9242'-9290', incompl. Survey: 9242', 2°, Naow 9-5/8" @ 8836' 9319', (29'), Lisburne core #9 Wt. 9.7, Vis 63, PV 20, YP 11, Sol 12, Oil 86.8 Fin Lisburne core #8, 9290'-9299', rec'd 57'. Lisburne core #9, 9299'-9319', incompl. The above is correct Signature For form preparation a~d i~stribution see Procedures Manual SeMtJon 10, Drilling, Pages 86 and 87 JOate ]Title 1/28/83 Drilling Superintendent AR3B-459-2-B Number all daily well histo~ forms consecutively ~ as they are prepared for each well. [Pag~ no. ARCO Oil and Gas Company Daily Well History--Interim Instruction-: This form is used during drilling or workover operations. If testing, coring, or perforating, 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 frequenlly than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly lot workoverS and lollowing setting ol oil string until completion. District ICounty or Parish State Alaska North Slope Borough I Alaska Field ILease or Unit Well no. Prudhoe Bay ADL #28322 SBS Date and deptl~ ~omplete record for each day while drilling or workover in progress as of 8:00 a.m. 11/26/83 11/27/83 11/28/83 11/29/83 11/30/83 12/01/83 12/02/83 12/03/83 9-5/8" @ 8836' 9359', (40'), TOH w/Lisburne core #9 Wt. 9.7, Vis 64, PV 20, YP 12, PH .05, Sol 12, Oil 86.8 Fin Lisburne core #9, 9299-9359', CBU, TOH. 9-5/8" @ 8836' 9388', (29'), Lisburne core #10 Wt. 9.7, Vis 61, PV 19, YP 12, PH .05, Sol 12, Oil 87 Rec'd 60' f/Lisburne core #9. Lisburne core #10, 9359'- 9388', incompl. 9-5/8" @ 8836' 9419', (31'), Prep to cut Lisburne core #11 Wt. 9.7, Vis 63, PV 20, YP 10, Sol 12, Oil 86.9 Fin cutting Lisburne core #10, 9359'-9419', rec'd 60. TIH. Survey: 9354', 2°, N80W 9-5/8" @ 8836' 9455', (36'), Lisburne core #11 Wt. 9.7, Vis 60, PV 17, YP 12, PH .05, Sol 12, Oil 86.9 Cut Lisburne core #11, 9419'-9455', incompl. 9-5/8" @ 8836' 9477', (22'), TIH w/8½" bit Wt. 9.7, Vis 64, PV 17, YP 11, PH .05, Sol 12, Oil 86.8 Fin Lisburne core #11, 9419'-9477', rec'd 58' TIH w/8½" bit. Survey: 9477', 2°, N70W 9-5/8" @ 8836' 9538',.(61'), Drlg 8½" hole Wt. 9.7, Vis 62, PV 21, YP 10, PH --, Sol 12, Oil 87 Drl 8½" hole f/9477'-9538'. Bkgrnd gas 100-110 units - H2S 0 ppm. 9-5/8" @ 8836' 9568', (30'), Drlg Wt. 9.7, Vis 64, PV 21, YP 15, Sol 12,' Oil 87 Drl 8½" hole to 9568' Bkgrnd gas = 50-80 units - Trip gas = 9 units. .. 9-5/8" @ 8836' 9599',:(31'), Drlg Wt. 9.7, Vis 60, PV 21, YP 14, Sol 12, Oil 87 Drl 8½" hole to 9599'. Bkgrnd gas = 85 units. The above is correct Signature IDate ITitle z,L~ ~ 1/28/84 For form prepaT'~ti~n and distributij~ see Procedures Manual Section lO~J Drilling, Pages 86 and 87 -F~'--~%~,~,9~' -I~umbE~daily well las they ~epared I AR3B-45~2-B DrillinK SuPerintendent Ior each well. ARCO Oil and Gas Company ~, Daily Well History--Interim Instruct ohs: Th s form is used during drilling or workover operat ons f test ng, coring or perforating, show formation name in describing work performed. Number all dr stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lntllinl" sheets until final complet on Report official or represe~..tatl.ve test on "Final" for.m._ 1) Subm. it "lntarl?'.' .s. hee. ts wh.e.~ ?%d_..o, ut_.b_,ut_no._tJ,e%s_~re_,q_u.e=_n,y than every 30 days, or (2) on Wednesday of the week in which oll string ia set. Submit weekly for worl(overs ano lOllOWing selling Ol Oil ~tlln~ Ulllh ~uIIIpl~llUll. District Alaska Field Prudhoe Bay Date and deptll as of 8:00 a.m. 12/04/83 12/05/83 12/06/83 12/07/83 12/08/83 12/09/83 12/10/83 12/11/83 CountyorParish North Slope Borough ITM Lease or Unit ADL #28322 Complete record for each day while drilling or workover in progress 9-5/8" @ 8836' 9637', (38'), Drlg Wt. 9.7, Vis 60, PV 21, YP 13, Sol 12.5, Oil 86.4 Drl 8½" hole to 9637'. Bkgrnd gas = 100 units - Trip gas = +10 units. 9-5/8" @ 8836' 9703', (66'), Drlg Wt. 9.7, Vis 60, PV 21, YP 14, Sol 12, Oil 87.0 Drl 8½" hole to 9703'. Bkgrnd gas = 90 units. 9-5/8" @ 8836' 9772', (69'), Drlg Wt. 9.7+, Vis 56, PV 21, YP 13, Sol 12, Oil 87 Drl 8½" hole to 9772'. Bkgrnd gas = 90-100 units. 9-5/8" @ 8836' 9824', (52'), Lisburne core #12 Wt. 9.7, Vis 57, PV 20, YP 13, Sol 12, Oil 87 Drl 8½" hole to 9819', CBU. MU core bbl, RIH, Lisburne core #12, 9819'-9824', incompl. 9-5/8" @ 8836' 9863', (39'), Lisburne core #12 Wt. 9.7, Vis 62, PV 19, YP 12, Sol 12, Oil 87 Lisburne core #12 f/9819'-9863', incompl. 9-5/8" @ 8836' 9880', (17'), Lisburne core #13 Wt. 9.7, Vis 64, PV 20, YP 11, Sol 12, Oil 87 Fin Lisburne core #12, 9819'-9879', rec'd 60' #13, 9870'-9880', incompl. 9-5/8" @ 8836' 9910', (30'), Lisburne core #13 Wt. 9.7, Vis 63, PV 19, YP 12, Sol 12, Oil 87 Cutting Lisburne core #13 to 9910', incompl. Bkgrnd gas = 70 units - H2S = 0 ppm. 9-5/8" @ 8836' 9937', (27'), Lisburne core #13 Wt. 9.7, Vis 60, PV 19, YP 12, Sol 12, Oil 87 Cutting Lisburne core #13 to 9937'. Bkgrnd gas = 60 units - H2S = 0 ppm. · Lisburne core Alaska Well no_ SBS #1 The above is correct Signature For form preparation-~nd distributiq~ see Procedures Manual Section tO.I~ Drilling, Pages 86 and 87 IDate ITitle 1/28/84 Drilling Superintendent AR3B-459-2-B Number all daily well history forms conseculively as they are prepared for each well. ARCO Oil and Gas Company Daily Well History--Interim Instruclions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing 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 frequently Ihan 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 string until completion. ICounly or Parish Istate District Alaska North Slope Borough ILease or Unit Pis~d Prudhoe Bay Unit ADL #28322 Alaska IWell no. SBS # 1 Date and depth as of 8:00 a.m. 12/12/83 12/13/83 12/14/83 12/15/83 12/16/83 12/17/83 Complete record Ior each day while drilling or workover in progress 9-5/8" @ 8836' 9954', (17'), TOH w/Lisburne core #14 Wt. 9.7, Vis 64, PV 19, YP 12, Sol 12, Oil 87 Fin cutting Lisburne core #13, 9979'-9939', rec'd 60'. core #14, 9939'-9954', core bbl jammed, CBU, TOH. Lisburne 9-5/8" @ 8836' 9954', (0'), TIH w/8½" bit Wt. 9.7, Vis 64, PV 19, YP 13, Sol 12, Oil 87 Fin TOH w/Lisburne core #14, serv'g core bbl. Tst rams to 5000 psi, TIH w/8½" bit, C&C f/logs. RU & rn bore-hole televiewer f/9954'-8836'. Log #2, FDC/CNL/CAL/GR f/9954'-8836'. 9-5/8" @ 8836' 9954', (0'), DST #1 Wt. 9.7+, Vis 75, PV 22, YP 12, Sol 12, Oil 87 Fin TIH w/8½" bit, C&C f/DST #1. TIH w/DST tls, tst manifold to 3500 psi. Pmp N2 cushion - 2535 psi surf press, est 1500 psi underbalance. Set pkr, open MFE tl, flow well f/10-min, 61' fluid rise. SI well f/4-hr PBU. (Pkr btm @ 9750' w/tail to 9954t). 9-5/8" @ 8836' 9954', (0'), Prep to TOH w/DST #1 Wt. 9.7, Vis 75, PV 20, YP 13, Sol 12, Oil 87 SI well f/PBU, open MFE tl, flow well f/l-hr. SI f/10-hr PBU, open MFE tl, flow well f/6-hr. Unseat pkr, pull pkrs up 11 stds in 9-5/8", rev circ. Collect samples of drl stem fluid. Prep to TOH. 9-5/8" @ 8836' 9964', (10'), Drlg Wt. 9.7, Vis 70, PV 21, YP 13, Sol 12, Oil 87 CBU, POOH, LD DST tls. MU bit, RIH, drl 8½" hole to 9964' Bkgrd gas = 60 units. 9-5/8" @ 8836' 9973', (9'), Logging Wt. 9.7, Vis 75, PV 20, YP 14, Sol 12, Oil 87 Drl 8½" hole to 9973', CBU, POOH. RU Schl, log DIL/BHCS/GR, LDT/CNL/NGT/GR/CAL, LSS/GR, rn Dipmeter. Loggers picks: Top of Lisburne @ 8860', Top of Alapah @ 9760'. The above is correct Signature For form preps~'-at~ a~d ~i~rib~t~n see Procedures Manual Section Drilling, Pages 86 and 87 I Date ITitle .[/28/84I Drilling Superintendent AR3B-459-2-B INumber all daily well history i'orms consecutively as they are prepared for each well. IPag~ no. ARCO Oil and Gas Company Daily Well History--Interim InllrUcflcna: This form is used during drilling or workover operations. If testing coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of ali cores. Work performed by Producing Sect on will be reported on "Interim" sheets until final completion. Report official or representative test on "Flnll" form. 1) Submit 'lnltrlm" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string ia set. Submit weekly for workovers and following setting of oil string until completion. County or Parish IState District Alaska North Slope Borough Alaska Field ILease or Unit Well no. Prudhoe Bay I ADL #28322 PBS #1 Date and depth Complete record for each day while drilling or workover in progress as of 8:00 a.m. 12/18/83 12/19/83 12/20/83 12/21/83 12/22/83 9-5/8" @ 8836' 9973', (0'), C&C hole Wt. 9.7, Vis 70, PV 20, YP 13, Sol 12, Oil 87 Fin rn'g Dipmeter. Rn RFT, rec sample, RD Schl, C&C hole. H2S = 0 ppm. 9-5/8" @ 8836' 9973', (0'), WOC Wt. 9.7, Vis 65, PV 20, YP 12, Sol 12, Oil 87 C&C mud, POOH. PU 21 jts, 3½" DP, RIH to 9973', C&C f/plugging back. M&P 125 C1 "G" w/l% CFR-2 & .15% HR-7 @ 15.8 ppg. Displ w/rig pmp & spot plug w/142 stk oil-faze mud - balanced plug. CIP @ 1800 hrs, 12/18/83. POOH to 9-5/8" shoe, circ & wsh DP cln, POOH. Tst hOPE to 5000 psi. PU bit, RIH to 9-5/8" shoe, circ & WOC. 9-5/8" @ 8836' 9666' PBD, (0'), Tst'g DST surf equip w/N? Wt. 9.7, Vis 72, PV 22, YP 11, Sol 12, OiI 87 Fin circ& WOC. RIH, tag cmt @ 9595', CO & drl cmt to 9666', CBU, POOH. RIH w/open hole DST #2. Tst surf equip. 9-5/8" @ .8836' 9666' PBD, (0'), Circ & prep to POOH Wt. 9.7, Vis 69, PV 20, YP 13, Sol 12, Oil 87 Fin tst'g manifold to 4000 psi w/No. Charge DP to 2100 psi w/N9, open MFE, flow well f/lO-min~ 158' fluid rise. Close MFE, SI ~ell f/4-hrs. Open MFE, flow well f/l-hr, 140' fluid rise. Close MFE, SI f/lO-hr PBU. Open MFE, flow well f/2-1/4 hrs, 88' fluid rise/30-min, no rise next 1-3/4 hrs. PU & unseat pkrs, POOH 9 stds, rev out. Circ & prep to POOH. 9-5/8" @ 8836' 9700' PBD, (0'), RIH w/7" lnr on DP Wt. 9.7, Vis 70, PV 21, YP 14, Sol 12, Oil 86.8 CBU, POOH w/DST #2 tsl - no tst. Each time tl was opened, soft cmt plug let tailpipe drop & close tl. PU bit, RIH, drl cmt 9666'-9700' PBD. C&C f/7" lnr, POOH. Chg upper rams to 7" & tst to 3000 psi. RU & rn 28 jts, + 2 marker jts, 7", 29#, L-80 BT&C csg. RIH on DP, break circ w/lnr in hole. The above is correct Signature For form preparation and distril~Jtion see Procedures Manual Section, fl10, Drilling, Pages 86 and 87 AR3B-45~2-B IDate 1/28/84' ITM Drilling Superintendent "~'~0' O0~.l Numbe. a,, dai,y we., h,.tory, ........ ecu.va,. "[~S they are prepared for each well. IPage no. 12 ARCO Oil and Gas Company Daily Well History--Interim Inlt~ctiolll: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing 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 "Finll" 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 string until completion. District Field Date and depth as of 8:00 a.m. Alaska ICounty or Parish North Slope Borough Prudhoe Bay ILease or Unit ADL #28322 Complete record for each day while drilling or workover in progress 12/23/83 12/24/83 12/25/83 2309'. 12/26/83 12/27/83 IState Alaska I Well no. PBS 7" @ 9700' 9700' PBTD, (0') TOH w/8½" bit Wt. 9.7, Vis 70, PV 20, YP 13, Sol 12, Oil 86.6 Fin TIH w/7" lnr on 5" DP, C&C f/lnr cmt job. M&P 175 sx C1 "G" w/l% CFR-2, 2% Gel, 10#/sx Gilsonite @ 14.0 ppg. Displ cmt w/rig pmps, full circ thruout job. Bump plug. CIP @ 1130 hrs, 12/22/83. Chg rams to 3~", WOC. MU 8½" bit/9-5/8" csg scrprs, TIH, CBU @ 8543'. TOH, LD 5" DP. 7" @ 9700' 9652' PBTD, (0'), Rn'g CBL Wt. 9.7+, Vis 76, PV 21, YP 15, Sol 12, Oil 86.6 Fin TOH. MU 6" bit/7" csg scrpr, TIH, tag top of cmt @ 9487', CO to 9652', press tst 7" & 9-5/8" csg to 2500 psi - lost 25# psi. Circ hole cln, TOH w/6" bit & scrpr. RU & rn CBL. Top 7" lnr @ 8543' - Top of LC @ 9536' - Top of FC @ 9652' 7" @ 9700' 9652' PBTD, (0'), RU CTU Wt. 9.7, Vis 70, PV 20, YP 15, Sol 12, Oil 86.4 Fin rn'g CBL f/9645'-8370'. Chg top rams to 5", tst BOPE to 3000 psi. TIH w/DST #3 tls, space out tl string. Chg DP over to diesel. Set pkr, fire perf guns, att to flow well - 8½ bbls flow. Press bled to 0 psi. Att to flow well. RU CTU. 7" @ 9700' 9652' PBTD, (0'), Prep to TOH w/DST tls Wt. 9.7, Vis 63, PV 19, YP 16, Sol 12, Oil 86.4 Fin RU CTU, tst to 3500 psi. RIH w/CTU to 5000', pmp N_ to unload diesel in DP, TOH w/CTU, flow well. Fluid level2to TIH w/CTU f/6000'-8000', pmp N2, att to gas lift fluid, TOH w/ CTU, flow well. Rev out DP, collect samples. 7" @ 9700' 9450' PBTD (top of retnr), WOC Wt. 9.7, Vis 65, PV 20, YP 14, Sol 12, Oil 86.4 TOH w/DST #3 tls & LD. MU EZ Drl CR, TIH on 3½" DP, set @ 9450' DPM. RU cmt ins & tst. Est breakdn rate @ 2.5 bbls/min @ 800 psi. M&P 150 sx C1 "G" w/l% CFR-2 &.2% HR-7. Displ cmt w/diesel. Stab into retnr, sqz cmt into perfs@ 9516'-9566'. CIP @ 1715 hrs, 12/26/83. Rev out DP, POH. MU 6" bit/7" csg scrpr, TIH to 3000', WOC. Prep to TIH. The above is correct Signature For form preparation and dislribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 AR3B-459-2-B Date [Title 1/28/84 Drilling Superintendent I Number all daily well histo~ t .... consecutively they are prepared for each well. ARCO Oil and 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 describing work performed. Number ail drill stem tests sequentially. Attach description of all cores. Work performed by Producing Seclion will be reported on "lnl~rlm" sheets until final completion. Report official or representative test on 'Fblal" 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. $~lbmit weekly for workovers and following setting of oil string until completion. Oist rict ~1_ a. s k~. Ic°unty °r Parish ITM North Slope Borough Field Prudhoe Bay Itease or unit ADL #28322 Date and dsptll as of 8:00 a.m. 12/28/83 12/29/83 12/30/83 12/31/83 1/01/84 1/02/84 Complete record for each day while drilling or workover in progress 7" @ 9700' 9440' PBTD, (0'), Prep to rn GR/CCL Wt. 9.7, Vis 57, PV 19, YP 10, Sol 12, Oil 86.4 TIH w/6" bit, drl cmt 9364'-9440', circ hole cln, tst csg & retnr to 3000 psi, TOH. MU & TIH w/DST tls #4. RU Schl. 7" @ 9700' 9440' PBTD, (0'), DST #4 - Flowing well Wt. 9.7, Vis 56, PV 17, YP 9, Sol 12, Oil 86.4 Rn GR/CCL, space out DST tl string, set pkr @ 9210'. Pmp N cushion, fire perf guns 9241'-9270'. SI well f/l-hr PBU. Open well, flow f/l-hr. SI well f/10-hr PBU. Open PCT, flow well. 7" @ 8544'-9700' 9440' PBTD, (0'), DST #4 - Flowing well Wt. 9.7, Vis 56, PV 18, YP 10, Sol 12, Oil 86.4 Fin 10-hr PBU, flow well, close PCT. RIH w/1½" CTU, tst to 4000 psi w/Ng, displ DP w/Ng, rec'd diesel, POOH. Open PCT, flow well. RIH w/CTU to 8000', displ w/N?, rec'd diesel (95 bbl total diesel rec'y). Cont flowing weI1. 7" @ 8544'-9700' 9440' PBTD, (0'), DST #4 - Flowing well Wt. 9.7, Vis 59, PV 18, YP 10, Sol 12, Oil 86.4 Stage tst'd well thru perfs 9241'-9270' f/total of 68-1/4 hrs. Perfs @ 9241'-9270' - Pkr @ 9210' - PCT @ 9155' 7" @ 8544'-9700' 9440' PBTD, (0'), RIH w/EZ Drl on 3½" DP Wt. 9.7, Vis 60, PV 17, YP 7, Sol 12, Oil 86.2 Cont stage tst wells f/remainder of 68-1/4 hr. period. Pull pkr loose, C&C hole, POOH, LD DST #4 tls. MU EZ Drl on 3½" DP, RIH. 7" @ 8544'-9700' 9440' PBTD, (0'), Cln cmt out of bit & csg scrpr Wt. 9.7, Vis 65, PV 18, YP 10, Sol 12, Oil 86.2 Fin RIH w/EZ Drl & set @ 9225'. With DP hanging @ 9225', equalized.50 sx C1 "G" w/l% CFR-2, .2% HR-7 @ 15.8 ppg. Displ cmt w/rig pmp. CIP @ 1030 hrs, 1/1/84. Calc top of cmt @ 8945'. RIH w/6" bit/7" csg scrpr to 4000', WOC, tag cmt stringer @ 8493'. stringers Alaska Well no. SBS #1 The above is correct For form prepareti~n an~l dist~ution see Procedures Manual Se~ctio~ 10, Drilling, Pages 86 and 87 IDate ITitle 1/28/84 Drilling SuPerintendent AR3B-459-2-B Alaska Oil & ~.,as C.;]ns. un. omn~is~.io,~ Number all daily well history forms consecutively as they are prepared for each well. ARCO Oil and Gas Company Daily Well History--Interim Inatmctlonl: This form is used during drilling or workover operations. If testing coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Produc ng Secl on will be reported on "lnlerlm' sheets until final completion. Report official or representative teat 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 la set. Submit weekly for workovera and following setting of oil string until completion. Alaska North Slope Borough ICounty or Parish IS"ta IL ......Unit ADL #28322 Alaska District Field Well no. PBS Prudhoe Bay 1/03/84 1/o4/84 1/05/84 1/06/84 1/07/84 Date and deptll as of 8:00 a.m. Complete record for each day while drilling or workover in progress 7" @ 8544'-9700' 9440' PBTD, (0'), Circ w/8½" bit & 9-5/8" scrpr @ TOL Wt. 9.7, Vis 73, PV 18, YP 7, Sol 12, Oil 86.2 RIH w/6" bit/7" csg scrpr to 8493', wsh cmt stringers to 8493'- 9180'. No cm~ on top of retnr @ 9225'. Tst csg & EZ Drl to 3000 psi, circ hole cln, POOH. RIH w/OE 3½" DP to 9225', tag EZSV @ 9225'. Equalized 75 sx C1 "G" cmt w/l% CFR-1 & .2% HR-7 @ 15.8 ppg on top of retnr. Displ w/rig pmp. CIP @ 2345 hrs, 1/2/84. Calc top of cmt @ 8805'. 7" @ 8544'-9700' 9200' PBTD, (0'), C&C mud Wt. 9.7, Vis 60, PV 15, YP 6, Sol 12, Oil 86.2 CBU, POOH, LD 8½" bit/9-5/8"'csg scrpr. PU 6" bit/7" csg scrpr, RIH, tag cmt @ 8868'. Drl firm cmt to 8948', hard cmt to 9200' PBTD. 7" @ 8544'-9700' 9200' ?BTD, (0'), DST #5 - Well SI'f/10-hr PBU Wt. 9.7, Vis 53, PV 15, YP 5, Sol 12, Oil 86.2 Circ hole cln, tst csg to 3000 psi; OK. RIH w/DST #5 tls. Charge DP to 3700 psi w/No, open PCT, flow f/10-min. Close PCT, SI f/5-hr PBU. Open~PCT, flow f/l-hr. Close PCT f/10-hr PBU. DST #5 perfs: 9086'-9150' @ 4 SPF MIDRV @ 8965' PCT @ 9004' Pkr @ 9058' Tailpipe @ 9169' 7" @ 8544'-9700' 9200' PBTD, (0'), DST #5 - Flowing well Wt. 9.7, Vis 54, PV 15, YP 5, Sol 12, Oil 86.2 Cont 10-hr PBU, open PCT, flow well, fluid rise to 2697'. Close PCT. RU & RIH w/CTU to 9000', unload well w/N2. Rec'd samples. Pulled CTU, open PCT, flow well. 7" @ 8544'-9700' 9200' PBTD, (0'), LD DST #5 tls Wt. 9.7, Vis 53, PV 16, YP 5, Sol 12, Oil 86 RIH w/CT to 9000', unload w/N? PCT closed. POH w/CTU, open PCT, flow well, fluid level t8 3874'. Close PCT. RD CTU. Att to open multi ID rev'g vlv, would not open. Rev out DP, catch samples, unseat pkr, CBU. TOH w/DST #5. The above is correct Signature For fo~m prepara~io-n a~ distribution see Procedures Manuak~Section 10, D~lling, Pages 86 ~d 87 IOate 1/28/84 ]Til,a Drilling Superintendent AR3B-45~2-B Alaska Oil & Gas Ct:ns. Oommis;io;-i ,umbor a,,daily wall history, ........... tively AitshC!'2~8 .s ,hey are prepared for each wall. AtlanticRichfieldCompany A Daily Well History-Final Report II~llllallall: Prepare and ~ the ~ I~ al tile first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Fiaal ReI~W' should be labmit~ld ~ ~ oberlflonl am suspended for an Indefinite or appreciable length of time. On workovere when an official test II not required upon completion, rel=e~ ~ Im:l mpreelntltive teat date In blocks provided. The 'Final Rl~erl" form may be used for rsporllng the entire operation If specs is available. Accounting District ]County or Perish Igtate Field .~.aska ICe-se or Unit North Slope Borough Prudhoe Bay I TItl. AFE 700550 Drlg Lisburne-V01521 Coring Auth. or W.O. no. cost center code Alaska ADL #28322 Drill, Core, Complete, Perforate no. SBS #i Operator {A.R.Co. W.I. ARCO Alaska, Inc. 50% Spudded or W.O. begun Date Spudded 10/04/83 Iotal number of wells (active or inactive) on this cst center prior to plugging and I bandonment of this well I our I Prior status if a W.O. 1030 Hrs. I N/A ! Data and depth as of 8:00 ..m. 1/08/84 1/09/84 1/10/84 Complete record for each day reported 7" @ 8544'-9700' 9200' PBTD, (0'), Prep to rn DiaLog csg caliper log Wt. 9.7, Vis 53, PV 16, YP 5, Sol 12, Oil 86 Fin LD DST #5 tls. TIH w/6" bit/7" csg scrpr to 9200', circ hole cln, POH, LD 3½" DP. Chg rams to 7", RU DA. 7" @ 8544'-9700' 9200' PBTD, (0'), NU Xmas tree Rn Dialog csg caliper log f/8520'-surf. Chg rams to 4~". RU & rn 286 jts, 4~" frac string w/Bkr SAB pkr. Lnd tbg w/tail @ 8806'. Chg rams to 5". ND BOPE, NU Xmas tree. Pkr @ 8753' - Tail @ 8806' - "D" Nipple @ 8796' 7" @ 8544'-9700' 9200' PBTD, (0'), Cln'g mud pits & rig 9.7 Oil Faze in tbg - 1500' diesel cap in ann Fin NU Xmas tree, tst to 5000 psi. Drop ball, set pkr. Cln oil-faze fr/mud pits & rig. RR @ 1500 hrs, 1/10/84. BPV set. Old TD Released rig I New TD I IPB Depth 9973 9200' J Dat. )KindofHg 1500 Hrs. 1/10/84 Rotary Classification. (o11, gas, etc.) Oil Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing ~ Lisburne Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production 0il on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature { Date {Title //~/~~ ~' ~- ~l 1/30/84 Drilling Superintendent For for~ preperatlo~ a~ distribution, ~ ~,~ C ~ ~ 'i/ C ~ ~ee Procedu~ M~ual, ~tlon 10, ' ~ - Drilling. Pa~ ~ ~d 87. AR3B-45g-3-B Oil & Gas Cons. Commission INumbar ail daily wail history forms consecutively as they are prepared for each well, iPege no. 16 ARCO Or, .end Gas Company Well Hietory - InlUal Report - Dally IW Pmplul mhd ~bmlt the "lalll~l I!~' on the flint Wedne~l~y ~lt~r a w~ll II ~dcled or wortcover ol~ratlone ~r~ ~m~cl. Drolly wo~ I~tor to ~l~Jd~lng ~lOuld b~ ~ummartz~l on the form giving thcluilv~ ~ only. Field Prudhoe Bay ~ or Unit North Slope Borough Title ~DL #2832,2 Recompletion Auth. or W.O. no, AFE 700550 Ist~e A~aska ell no. ' SBS #1 W/O Operator IARCO W.I. ARCO Alaska, Inc. Workover 3/04/84 2100 Hrs. I N/A Date and depth aa o1' 8:00 a.m. 3/05/84 3/06/84 3/07/84 Complete record for each day reported 50% 7" @ 8544'-9700' 9200' PBTD, ND Wellhead tree Accept rig @ 2100 hrs, 3/04/84. Pull cap off tree, ck f/press under BPV, gas under BPV. Unseat BPV, bled press, still had gas flow. Reseat BPV f/1 hr. Had 100 psi press build up. Bled gas dn. Set BPV, ND wellhead. 7" @-8544'-9700' 9200' PBTD, Att to pull out Bkr Expanda jt ND lub & wellhead tree. NU BOPE, chg pipr rams to 4~", tst BOPE to 5000 psi. Chg ram rubbers, tst Hydrl to 2500 psi; OK. Tat both sets pipe rams & all vlvs to 5000 psi; OK. BO lockdn screws on tbg hgr, att to pull out of Bkr Expanda Jr. 7" @ 8544'-9700' 9200' PBTD, RIH w/2-7/8" tbg 9.6 NaC1/NaBr Pull up out of Bkr Expanda jr. Chg over f/crude oil & Oil Faze mud to 9.6 ppg brine. POOH, LD 4½" tbg. Chg seals in Bkr Expanda jr. Chg pipe rams to 5" on btm - 2-7/8" on top. Tst both sets pipe rams to 3000 psi; OK. RIH w/2-7/8" tbg. AUG 2 ? .u: o4 Alaska Oil & Gas O:~ns. Comm/s.~ioa Ar;ci-,cr~,ga The above is correct Signature For form prep~ation and dlstribl.~n, ~ee Procedures Manual, Section Drilling, Pagea 86 and 87. IDste [ Title D~iillu~ Superinuendenu AR3B-459-1-D INumber ,ell dilly well hleto~/forma con#cutlv~ly U they am prepared for each well. ARCO Oil and Gas Company Daily Well History-Final Report Instrucli~ns: Prepare and submit the "Final R~orl" on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned, or Sold. "Final Rel~rl" 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, rePor~ completion and representative test data in blocks provided. The "Final Raporl" form may be used for reporting the entire operation if space is available. IAccounting cost center code state Alaska District County or Parish A]_ask~ North Slope Borough Field Lease or Unit Prudhoe Bay ADL #28322 Auth. or W.O. no. T tie AFE 700550 Recompletion Well no. SBS #1 ~/0 Operator I A.R.Co. W.I. ARCO Alaska, Thc. Spudded or W.O. begun ~Date I Workover Complete record for each day reported Date and depth as of 8:00 a.m. 3/08/84 5O% 3/04/84 Iotal number of wells (active or inactive) on the% est center prior to plugging and ~ bandonment of this wellI our I Prior status il a W.O. 2100 Hrs. I Completed 7" @ 8544'-9700' 9200' PBTD, RR 9.6 ppg NaC1 in Ann & 40 bbl diesel cap - Diesel in tbg Fin rn'g 119 jts, 2-7/8", 6.5#, N-80 EUE 8RD, R-2 tbg & 156 its, 50 x 24 Bkr Heatsaver II, 22.0#, N-80 AB Mod Butt, R-2 tbg. (5", 15# outer tube; 2-7/8", 6.5# inner tube). Lnd tbg. (BPV in hgr when landed). Rn in lockdn screws. ND BOPE, NU & tst tree to 5000 psi. Displ tbg w/diesel + 40 bbls f/ann. RU slickln, set dummy in GLM @ 8690', POH w/slickln. Tst GLM, tbg & seal assy; OK. Set BPV. Secure well. RR @ 1600 hrs, 3/8/84. Old TO Released rig 1600 Hrs. New TD Date 9973'PBDapIh 9200' I Kind of rg 3/08/84 Rotary Classifications (oil, gas, etc.) Oil Type completion (single, dual, etc.) Single Producing method Official reservoir name(s} Flowing Lisburne Potential test dale Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature I Date Title ~'~2~ ~~--3 I 3/08/84 Drilling Superintendent For form preparation a4 dis~butio~,- seep .... d .... M .... I, Section 10, ~C i ~ ~: ~ DHIling, Pages 86 and 87. ~ ~ ~ ~? ~ AR3B-459-3-C AUG 2 ? ~ , ,INumber ell daily well history forms Page no. Oil &6as:..¢,.¢~rQ_CONS' ~Om~SS~they are prepared, ..... h well. consecutively [ 2 ARCO Otl.nd Gal Company Well Hiltory - Initial Report - Dilly la~neo41ll~ prepare and eubmlt the "Initial !~' on the flint Wan'no,day Ifil, · w~il II Ipoddld or wortover operltlonl afl W. ~Mly work prlor to Ipudcling Ihould be i~mmlrtzid On the form giving Inclulive dltll only. Alaska Field Prudhoe Bay Auth. or W.O. no. AFE 700550 North Slope Borough ~a/e or Unit ADL #28322 Title Pull Blanking Plug - Rel to Prod Alaska BS #1 Operator ARCO Alaska, Inc. Spudded or W,O. begun 3/11/84 Date and depth as of 8:00 a.m. 3/10/84 3/11/84 Current Opr 3/12/84 Current Opr 3/13/84 Current o~r Complete record for each day reported IARCO W.I. Prior atatue If a W.O. N/A 9200' PBTD Work suspended - Moving Nabors 1-ES 9200' PBTD PU Hydrostatic bailer, prep to tst lub Pull BPV, MU slickln unit, tst BOP & lub to 2500 psi; OK. RIH w/1.5 JDC OS to pull prong out of blanking plug in nipple @ 8796'. Wrk catcher over prong, POH, caught piece of soft rubber in OS; did not catch prong. PU 2-1/4" OD impression block, tst lub to 2200 psi, RIH, make impression, POH; no impression. PU 2.2" OD pmp bailer, tst lub to 2000 psi, RIH. Hole ratty thru K-Anchor/pkr/mill out ext area (acts like pieces of rubber). Wrk pmp bailer @ top of blanking plug, POH, rec'd 2 chunks of rubber. PU 2.5" JDC OS, tst lub to 2000 psi, RIH, hit same ratty area, wrk catcher over prong on blanking plug, did not catch, POH, rec'd several pieces rubber in OS. PU 2" hydrostatic bailer, tst lub to 2000 psi, RIH, set dn & set off bailer, POH, no rec'y. 9200' PBTD Prep to fsh PU hydrostatic bailer, tst lub to 2000 psi, RIH, wrk bailer on btm, POH, att to rec rubber covering top of blanking plug in nipple @ 8796', no rec'y. PU JDC OS w/core removed, tst lub to 2000 psi, RIH, rec Hydrl rubber chunks & piece of tbg hgr'seal rubber. Tst lub to 2000 psi, re-rn OS, rec Hydrl rubber. PU hydrostatic bailer, tst lub, RIH, set dn & set off bailer, stuck in ink on top of blanking plug @ 8796'. Wrk spang jars & hydraulic jars, in broke @ counter wheel & slipped ahead into lub. Close BOP on wire, break off lub, strip up & clamp off in. Strip wire back thru lub & clamp off. Instl "Go Devil", & drop to cut in, POH, rec'd all wire. Prep to RIH w/OS to catch "Go Devil". 9200' PBTD RIH to catch blanking plug RIH w/JDC OS w/core removed, latch onto hydrostatic bailer string & jar free. Wellhead press rose to 1300 psi indicating prong f/2.5 CA blanking plug also sheared free, POH. Rec'd all of hydrostatic bailer string & OS full of rubber. Did not rec prong. RIH w/JDC OS (core removed), catch prong, POH, rec'd prong f/blanking plug & small amount of rubber in OS. NU lub, tst, RIH w/JDC OS (core removed) to catch blanking plug. 50% The above is correct Signature For form pTepa~on and dl~l~butl(~n, see Procedures Manual, SeeM'on 10, Drilling, Pagee 86.and 87. JDat. 3/13/84 ITM Drilling Superintendent AR3B-459-1-D AUG 2 7 '!984 INumber ali dally well hlalory forms consecutively Alaska Oil a Gas Cons. Commis['l~'"' "'""'" for each wall ARCO wi and Gas Company Daily Well History-Final Report Inatructinne: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or wall is Plugged, Abandoned, or Sold. "Final Reflert" should be submitted also when ol:~rations 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 Reflort" form may be used for reporting the entire operation if space is available. District ICounty or Parish Lease or Unit Title IAccounting coat center code State Alaska Field Alaska North Slope Borough Prudhoe Bay Auth. or W.O. no. AFE 700550 Operator ARCO Alaska, Inc. ADL #28322 Pull Blanking Plug - Rel to Prod no. SBS # 1 Spudded or W.O. begun IA.R.Co. W.I. Date N/A Date and depth as of 8:00 a.m. Complete record for each day reported Old TD Released rig 50% 3/11/84 Iotal number of wells (active or inactive) on this oat center prior to plugging and I bandonment of this well I our Prior slatus if a W,O. N/A 3/14/84 1600 Hrs. Classifications (o11, gas, etc~) Oil Producing method 9200' PBTD, RR to Production RIH w/JDC OS w/o core & att to catch blanking plug w/o success. RIH w/drive dn bailer, rec'd Hydrl rubber. RIH w/JD OS w/o core, catch blanking plug & jar free, POOH w/blanking plug. Well released to production @ 0600 hrs, 3/14/84. °Present Status of Well: Live °Tbg press = ± 1500 psi °Upper & lower master vlvs & wing vlv all closed °B?V removed °SSSV @ 2199' - Vlv @ surf on single contrl in is closed w/ ±4500 psi trapped in contrl in to hold SSSV flapper open °2 GLM @ 5035' & 8690' -- Dummy vls in both °Seating nipple in tailpipe @ 8796' - blanking plug removed °Tbg filled w/diesel. Crude oil below 8690' °Sand fill partially covering lower perfs (9086'-9150') -- With well flowing @ 2000 - 3000 BPD rate, have found btm w/WL @ 9109' to 9123'. With well SI, tagged btm w/WL @ 9051' INew TD I PB Depth 9973' 9200' IDate ] Kind of rig 3/08/84 Rotary Type completion (single, dual, etc.} Single Official reservoir name(s) Flowing Lisburne Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct /JJ~ /_ _ _~ 3 / 14 / 84 Drt 11tn8 Supar±ntendent AR3B-459-3-C AUG 2 ? ~ ~ AlaskaOil &Gas f'%..~th.,..a,fa.r~[eeere¢l , ..... h well. I ~ Anchorage ~ ~ ~~, ARCO Oil and Gas Company Daily Well History-F InstnJctionl: Prepare and submit the "Filial R~' on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. 'Final R~rt" should be ~ubmlttad all~ whorl Dp, eroSions are suspended for an indefinite or appreciable length of time. On workovers when an official tee required upon completion, report completion and representative test data in blocks provided. The "Final Ret~lrt" form may be used for reporting the anti operation if space is available. IAccounting Slate District County or Parish Alaska Lease North Slope Borough Field or Unit Prudhoe Bay ADL #28322 Auth. or W.O. no. T t e AFE 700550 Recompletion Operator A.R.Co. W.I. ~Total number of wells (active or inactive) on Icost center prior to plugging and ARCO Alaska, Inc. 50% labandonment of this well Spudded or W.O. begun Date IHour IPrior status Workover 3/04/84 ! 2100 Hrs. I Cc Date and depth as of 8:00 a.m. 3/08/84 Complete record for each day reported 7" @ 8544'-9700' 9200' PBTD, RR 9.6 ppg NaC1 in Ann & 40 bbl diesel cap - Diesel in tbg Fin rn'g 119 jts, 2-7/8", 6.5#, N-80 EUE 8RD, R-2 tbg & 15~ its, 50 x 24 Bkr Heatsaver II, 22.0#, N-80 AB Mod Butt, R-2 tbg. (5", 15# outer tube; 2-7/8", 6.5# inner tube). Lnd (BPV in hgr when landed). Rn in lockdn screws. ND BOPE, tat tree to 5000 psi. Displ tbg w/diesel + 40 bbls f/ann. slickln, set dummy in GLM @ 8690', POH w/slickln. Tat GLM, & seal assy; OK. Set BPV. Secure well. RR @ 1600 hrs, 3/8/84. Old TD Released rig 1600 Hrs. New TD I PB Depth 9973' I 9200' IDate IKind °f rig 3/08/84 Rotary Classifications (oil, gas, etc.) Oil " Producing method Flowing Potential test data IType completion (single, dual, etc.) Single Official rese~oir name(s) Lisburne Well no. I Date Reservoir Producing Interval Oil or gasTest time Production Oil on test - Pump size, SPM X length Choke size T.P. C.P. Water % CDR Gravity Allowable corrected The above is correct For form preparation and dis~butio-n,- -- see Procedures Manual, Section 10, Drilling, Pages 86 and 8~. - Title AUG 2 7 i984 Drilling Superinte AR3B-459-3-C Alaska Oil & Gas Cons, C.ommis~ior~ Anchorage I.um.rall dally well histo~ forms cO .... tively aa they era prepared for each well. :0 ALASKA, INC, IT H ,: ~.,. ~:: T A T E .'II.' 1 I ]E.~ 1-.I 0 I:T. BAY :TI..I~ ..... ol... 01:.'1::..~ AL.A"'KAo CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS Il':' I... E I:l E F:' T I"I P E: R i'.t E A B I I... I T Y ( H .0 )' P 0 R (:~ I'~ A :F. N' '" 1B IE R F:' Iii: E: T l'.'l A ,,, .1. H U H 90 I)E G t ..... ' ' "' "" ; 1::. 1'~ 'T I C A I....,'., B E N ~'~m ~r~ ~ ,') . · ~ . ( "x o o ~, :~' · 0 1 ~ Z 7 :I. · 09 0,04 8,3 , '" 4 S S, 4 .. o ~:~ ,.~ 0.0 1 © ' "~'" '7 '" "~ ,'.., 8.,::,~: 0, ~:'. o . '7 ,::. '75 8.9 · . · ~. o ,., :I. , ,..,:1. ~::' ,., , 6 · 1 · "'"' ~:.,:~ 6 · 7 .~:., 78 8 · 9 l'1 ~ t::' ~'1 I'~ I:~ ~., o ,.~,~,, 0 7 o,-,~:- ~ 2 'S ' ~ 2 '::' · o o 0, :I. 1 6,6 ,. ,7,J ~:: S, :1. 8 '" ~'' ':~ ~:' 9 4 2 6 9 "~ o o ~.~ ,.,~ 4 "'"' ()~ 6~ 4 ' ' "~ I~' ""Y I::" t'l 9 8 b ,.~ 6, ,:~ 5 ~ 70. '5, ,., 1 ()~ 0 S ' 4 ~ o ~:. ~ 87 ,.,,7'::' 10 ~' "' ::' '"' '" o o ,.~ ,. , 0 "~ "~ ;.. · 69 ':~ ~ 1 '::' ......· , ()~ 10 ,.,'::' · ,.;. ~:.~ 85 10 ~ 1 11 8""::' ~'' 0 "~ o,.,,:~ . ~ 4 ...,74 9.0 ~.., 45 1 , '::' "' ,.~ ',' (), 06 /' 12 8 "' '::' o ,'~ o ,.~; , S 31 , 1o"' · 1 (), 8 ~.."~, 84 ~.. 6,0 1 S 8860,0 10, 8~ 92 ..... 13 · ':~ "~.., o"' 7 43, ,.,'::' 14 o~,, 27 / ~ 22~ .,...0 ~ "' ,:, o o ~, 0 , 1 '"' ..... ~ "~ o .,. ~ 8 7 41.4 o,:~,:.. , ~.... 5,45 '::' "~ · .~, ,:~ ,:~ 9,79 ~16 8863 · 0 :1., 6 .... ':~ I, .45 1,46 1 S, 0" .~.., 7S'~ 63,7 117 88 6.4, S 0.49 0, .49 0, :1.7 :I. 1 9 ':~ .. , 70 '::' 18 "~" '::' '" .... o ,.~ o ,. ,... ~ ~.. 54, ~:. o o o,., · .~: 0.63 0. '::' ' 0. '::' ' 19 ~' ~ 66,1 0,37 0, "'" " "~ .... ' '" o ' ' 10 7 3 ':~ ,.~ 0,0 ,, 2 0 8 ~' ~ TM 7 o o, , 0 0, z. o ,'~ - ,.,, 0., 24 0, .,:: 011, .4 2, S 4,.~, 7 2~ 8 ~''''' ' '~ oo ,., 22 8 '~ ~ "' '~ .~.:,:~ ' '::' '" c~ o ';' · ~.. 0, "'"' 0, .I. ,., I · o": 6, .4 ~.'., 7 S 41 , 0 ~ 3 ~' 870 · I 0,24 ...... o 0 · 16 0,01 /, 1 77 47,"' 24 "~' '"' o o., I, 0 0,11 0 ~ 06 '::: 0 · 01 S, ~..."' ~:.,."~ '7 S.. .,:. ]., 9"~ 25 ""~'""~ '" o o / ~..: · 4 S, '::' ~ · 4 '::' ,.,', 0 ~ 68 0,02 'S~. 9 2../4 . ,.~ ~' <: :'"~' ,4 "~ "7 0,15 '::' '::' o ,.~.:., S, I ':I '::' , ~:~ o 7.'~, 4 "'"' i , o,', ", ,', · :~ ,:~ · o ~. 2 8 8 8 -',.' '::',.~, 40 ~ 6 5 0,0 8 (), 6 o '~ 4,0 '"~;, Y 1 2 3,9' F:'I... LJ I ]0 S A'f' S · 0:1: I....W TR 17,4 "76,0: 6 0.0 66.9 77.9 ~...S , 5 54,5 7:1. 04 8 S.,.~'::' 77,7 80 05 29 O. · . . 6°0 0 1 S, 0 S 06 :1. °9 14 °4 27 o 8 8 :I. o 6 69° '~ .c.'. 60 o 0 F:'A G E ,:~ T : L A B 0 R A T 0 R Y t .,......; PY These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories, Inc. (all errors and omiss/ons excepted); but Cote Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations, as to the productivity, proper operations, or profitablenes~ of any off, gas or other mineral well or land in connection with which such report is used or relied upon. CO AL..AoI~A, I~(.,~ UTH BAY ' ........ · :::, ¥ A. T I::. ti: 1 CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS. TEXAS F'" O R H A T :1: O N : I... I .:::, Ii, LI I", N E (3 R A :l: N' F:' L U :1: D ,r, ,, "," · ,,:) I"l / ,4) 0 D IZ N, 01 L.. W T R , . S.4oS ~;."; o 70 76 o ~?; "1 S, ~... ,, *") I::' "~ #') .,,j .,.) ~. ...:. ~.:. o 74 56°9 ."' Ii . -' ~,: · 74 60 o 4 So 5 "~ / '~ . :,..0'72 5401 ' 30'" 2 ° 7 5 5 8 , 7 6 , 1 '2. 0 7 :'.~ 51 ° Iii 9 0 S . ...) , ,.,. ° '7.4 6 5 ° 0 5 o .,.:. o 71 60 + 1 4 o 2 ° 76 '::' ' · 5 .1. 4 0 ,. ~,J (;) o ~..."~ o 7:1. 49°0 !?~4' ~,. ° 74 "-' ..... ~ 9 4 7 ':~ o 6 9 ":' ": .... ..... ~ 7 o,.~ 9 o ,:~ ; 2 ' ' ...~70 55.9 5,2 2 6 6 ~'""'- 0 2 0,9 ,,. ' 6 9, - 5 5 0 8 '5 ° ,...'.'" ~..:0 71 56°6 6 0 7 ':~ · 7 4 '5 0 ° 6 .1. "' ° 4 ~..'."' o 71 5 2 o 8 :'::; · 7 '"' 7 .1. 4 8 ° 9 ~.:"' .,. 7 .,.'., ~, ~,. 0 7 0 '"~" "' "' 4 S ':~ ..,:. 0 71 ° .1 .... 0 .1. ".' 71 49..1. 4 ° 5 ~.'.. 0 , '" ;'~'" .4 .1. 4 ~'.'.. o ~'.'. 49 ~ o ~,,:° 72 ',50 ° 2 7; ° 8 I" A {:~ I::.2 A I F:' :1: I... Iii: N (3 : B F: ..... S'"' 8 8 5 ANALYSTS ~ TI...S~RBB PRELIMINARY COPY ' B Iii: S C R :1: P T I 0 N s a~ nlj e; c: h'b 6 ,.: ~,.,., .¢.i~ o \ ~.i.:. ~L', I'l'J e ~ ,2 ~'i 'b (:"' ., 6 :'J (~':' ~.{ ,, 71. s ~ v'["' · ...... '1 ls ~ mx .~ uu.~. *'F'r. ac.. ° * 175 de..:, ° *'f' Y' a c: · * 60 d e :.:~. 60,..,"' e .:.:~ · These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories, Inc. (ali errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations, as to the productivity, proper operations, or profitableness of any oil, gas or other mineral well or sand in connection with which such report is used or relied upon. CORE LABORATORIES, INC. Petroleum Reservoir Engineering I'. A(.',Ik . SA '~CO AL..A~'" ol,,A, INC, )UTI..I BAY STATE :11:1 I) A T li!] I::' 0 R H A 'T' I 0 N C [)R E A N A I... Y" <""' <" .:::, I,:~, R E.:::, L.JI...'T' ] -/'. ' C' ~. I::. ~..~ N'"' S T A R K A N A I... Y S I ,:) q H F'I... E I) E P T H P E R i~'I E A B :1: L.. :[ T Y ( H !:[ ) · j "* '· · A J H B E R F:' E E T H A X :1: H U ?'l:;"' 0 I. I::. (.'., g E R T :1: [, ~..~ I... "'"'"' 0 '"'::' 0 52. 59 8 ? 07,0 00 o,.~ , o,.J '"' 3 1001 6.1. 8909 · 0 I, 31 I 0 ~... . 6,.2 891000 1014 .1., 09 0 C) .¢.'. 63 891 :L ° ~.. ,.:., 1.,... 109,.:.'" I, 57 64 89.1.2,0 1 ° o o 1 , 7"' 1 · 44 "~ ") 49 "~ " 65 8913, .,.. ~..., .,.:., ,i~ 3 .1. ° 19 66 "' "~ 7 '" o 91.40 S ~..: 10 0 ,, 67 '~ '=' o 91,., 04 .1. ''''" 6 8 /'% 1:"' '"~ '') o 916, ,., z. ~... · 10 ~ 00 1 ~ S 1 "~0 0 19 0° 06 69 891 '?~ 5 00 ,..'. 70 '~ '~ ) '"' o ? .1. Iii 0 .1. 0018 0,16 00 (. ,'.'~ 7 .1. '" ' "' o9.1.900 0~.I.o 0 10 <0~0'1 72 Ii) 920, ''~ .,..'. 8° 56 3 ~ 44 o .~. ,... 1,0 100, '5 ' ' ,::~, )' .,'.: ,.... '90 00 ,r),", 7 ,'5 ~, o '" "' ,., z ,...'.,:~, 00 '943 0041 0024 76 .,::) c,,'> ..', 0:'5..1. ''> ,.,., ,.'..".~. 0 .,... 1077 00 '"'" .) 77 c, n ,'~ ,::' o 'x ~-:.,.., ° 1 3, ''~ "' .... '.. ,:., 0 · 0z. 1 7 ~ '"" '"'' ''''~ ' ~:'" ' "'" '"' "'" o '~ ..z ~:::, 0 ,.., 1,::)"" .1. 0 1 ,:::, o 0 ,.-;. ,c:~, 79 '"""'" '" '" l ' (:: ')' .,.:./° 0 ~.:.. 06 .,,'. ~ 06 :L 80 ~ ~''''' "' .... o .;.. ~.:. o ~ ,:~ 100 009 / 81. 8" © ,, .:.-. ,~ -, .., 7 ~. '~' , ('5 0, ,., ~.:. 0 ° 24 00 ,:~ 82 8""0 I 0,9'::' :~' ,:~ . 0 '" ,.~ 0°-40 O° 2.4 o,.~ (::. 9,1~ 1,4 4 · 89 0 ° 41 000.,~ '~ ~ P "' '::'"" 0 ~ © '" o -, ":. ? 3~..'. ° ':)..,.. I , ,... ,, 0 .,~ ,:, ~.:. ',5 . o ,~ o 93 S ~o" 00 .1. 5 0 ~ 0 ',5 0 P~ "~ "' 'I '" ()~ 0 S 0,0'" .;, ~:3 (:) (? + x.'. . .. · :).. 000 ,.'::' ...:'. 87 89S'::' o 0 ,... 0,17 ()~. 09 ()~ 0 88 89 :?; 6° 0 1 · 1 '" .~,: 0048 0° 14 F:' 0 R .... (:~ I'~' A .[' N .,. 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"' It:' ! 47° 48° 45° 69, 4:2, ,. .7,,...,6 I:," "} 5 8,0 I::° L':;7 · 7 30,7 "y ~ 77 ,:)4 · 1 8,2 9°3 I:.:' !'1 4~ .1. 7° .1. 24 S7'90 26 ~ 0 270.4 s m iY~ e 160 ~.;; ~ n'~ e 80 "" .,..'.~ t.. 1'.'2 .', .,.~ ....k .... ~.~ .3.. , ..~ ~ 1 * f" ¥" m (::, * ~''' ~='.~.;6 . ~:.J(.:.):::~ · 1 s ~ 'f x * s;~a'~e~oo]. .4FI "' .. 1 s ~ 'P x ..... ' · " .... I · ' .... '"'::' 1 s~, 'f.'.. i¥, x 7 s ~ m e * '? Y' ~ c., * 1 ""::' ,..~ ,.~ S ;5 Iii E. ~.:. ,:~t..I ~....' x..~ s;~n'~e 38 "' .... .. . I.. s ;~ n'~ e .1. 24~..~" e ..... ls~v'?x 76 de~,. s ~ n'~ e '56 d e ..) These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories, Inc. (all errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or represeutations, as to the productivity, proper operations, or profitableness of any off, gas or other mineral well or sand in connection with which such report is used or relied upon. CO AL. ASKA, INC'~ U T H B A Y ,"~ T A T E 11.' 1 '' I CORE LABORATORIES, INC. Petroleum t~eservoir Engineering B A 'T' E : F: C] R H A T I 0 N : I... I S B U R N Ii:". .:::0001 < 04, 01 < 04' 01 04,03 04, 27 .... 0 4, 01 61"~ ()~ 4 7 '2 ~ 3;,,.=4,"' 6 7 6,,... o ''~ 8: 3 4 04' .44 4 ·o"' ')^.. 4' 6856 · S 14 · 7 0 · 09 504 ^... 0 67 6.4.4 1 '7 4' .1. I::'A G Ii..". .4 A [ ,:,, :i. :1. u T'e · [" ~ :i. ]. u ¥' e '[" m i ]. u ¥' e '[" i~ :i. 1 u ~r' e These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories, Inc. (all errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations, as to the productivity, proper operations, or profitableness of any oil, gas or other mineral well or ~md in connection with which such report is used or relied upon, CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS F' A (.'., I::. ',::'; A "~ .... I N C CO AL.i'-~,~IxA, . [JTI"I BAY STATE: :11::1. B i..i ¥ I::. .~ F:' 0 R H A'T I 0 N : I... I S B [.J R N E F"]:I...E NO : BF ..... ,'3-885 A N A I... Y S T S : 1' I... S ~ R D B C 0 R I!i: A N A I... Y S :1: S R I!': S LJI... T S I) Iii: A N "" S T A R I'( A N A I.. Y S :1:,:~c' .PRELIMINARY COPY F'L. E B,::"': F'T I"1 H:E:~ ER' FEE'T' ]. 19 "'"" "" o ? o/, .1. .1.2.1. ,~ o ..:. o 0 ..;.,.. o97001 12,3 o,,"', ,., [.., 'Y :' .1. · ,¢:. ,", o".,,'.', ", I,r') I..'"t'"t t'"l ",l "'~' .¢. ~.J C) '2' / C) ~, 7 ,. .1. 26 .1. 2 ? ,~ o -, ,:. C.~ )' i ~..~ · .1. :L28 (:.,"~976 '~ 8977 :1.,.'30 897~'o ,"'~..'. .1. S .1. ~:'~ ' 7 2 ~.,9 9° ... o 0.4 1~S ~9~'' C.' .1.~4 89~''' 2 C) .. .. /4'.{, :1.35 89'"'3,,o 0 .1 36 "" '"' ' (:.-. ? o . 00 .,,,1 .1. 38 '"' ' .1. ;5 9 '" ©''' ''~ 4 140 '"' "'""~" ¢=' ';" ,;:)'4) ,I. ~'~ .1. 41 "'"'""'"' ""' .. o '2 '~' ~0 0 :1.43 ~'~"' "' .1. 4.4 8992°,.: ~:' .1.45 ~., 9 ',' ,:~, .1. 146 " 4 o99 °4 .1. 47 '" ',".:; o99 . ~..,'I. .1. 4 8 '~ 9 ' .4 F:'lii: R M E A B I I... :1: T Y ( M B ) I::' 0 R M A X I M t.J M 90 I. I::. I:~ V E: R'T' I A !... Z 8 .1. 0 ~ 50 . S 0 O04,.~ .1. 1 0,. 95 ' 9.. ,o, 27.7 .1. 8,8 1"4 · 5 ~..~ 1;:' - ' · ...I 0 · ....I ,.. 44 · · ,'1 ."),, "") ,..' .¢.'. ^'.. e x 25°9 ' S 9 4 · .I. 8 · 7 19,6. :1.6,7 8 · '".,.:. .. 8· .1. ,,'""If · ....:. ~, · ,1. I ·,..:."' IJI .... )(.,RIPTION These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories, Inc. (all errors and omissions excepted); but Cor~ Laboratories, Inc. and its officers and employees, assume no responsibility and make no warrauty or representations, as to the productivity, proper operations, or profitableness of any oil, 8as or other mineral well or sand in connection with which such report is used or relied upon. CORE LABORATORIES, INC. Petroleum Reservoir Engineering C), H DALLAS, TEXAS :t.J T I.-I B A Y ~ T A'T' E :11:1 I) A T E ~ I::' 0 R i':I A T I 0 N ~' 1... I S B t.J R N lie H F' I... I:.-'. ~.i E F:' "1" I"1 I i'"l B E R I":" E E'T 14 '9 :" ':: ~'' "' o ';' z ,, 0 1044 O0 '5,:. ,~ 0 ? "' "' .¢.'. .c.: 6 '~:I' 5.1., " :;' 2 -' 10 '::'"' o?9 .,.. 4 0 ?/' .. s.J 4: .1. ~ 2. 9000. ,,') 1 ~53 900.1. 00 00. 61 00 ~...."'"',:~ · .I. ,.., 4$:' 002.. 3 1071 0~. 12 15~: 90 ,.,. 030 '3 0,04 O003 /' I 1 ,'56 ? ~.) (., 400 0009 0 ~, '06 I .ITT'. ! ,,7 ? 00',"); ~ 1 '"' ~...0 ':, '.', I 00~..'."' 158 9006, ,:~ 0 ~ 18 0.16 1 L59 9' 00704 1 ~ 80 O, 30 160 9008 · 2 16 .'1. 9009° 0 16 '~' ~. 9010 .~ 0 163 90110.,... '''~' .1. 64 '" ") 4 ' 0 4";' :;,' ,.. 1.,..:'" ,,0., ',"~; o ,, . 165 90.1. ,3 ... ':"' ,... 0 · 14 · 166 '? 014 .,. 2 003 S 0,, 11 )167 90:1.~500 168 9016 o 0 0 ~ ~.:. 0 0 · 11 :L 69 90 J. 7o '5 11 o 6 ~ .~... ~.:. 1 ? 0 9018 ·~..'. ''~ 171 9. 019 o 2 0 o ~.... ''~ ''~), 0, :I. 6 · "11 · 1. 7..2 90 .,.= '' 001 00 ~.... I 001 / 173 ';:"02.1..,. 0 0 ·.,..'.""1 0 , :1. ';:' .I. 74 90 "" "' .,.:. ,..: ,, 0 0 ~. 1 '3 '...,,:'" '" ... 01 17,'"3 '"' ")"' ~'' "" '., ,....,..: ,::, ,, .,..'. 1 .,..,::'"' '::',.., I ,, 14 176 9 ..... 0 .? 40.,.:.'" S ...o"'-"/ ,::,""' :. o"' .,..:'" 17 ,'7 '"'" "' '-'"' ,,. 0 v 1 '~.' ,,., .,.:.,.~ ,, I '::: 0001 '::i") "' 178 9026 ,. 0 '"', .,..'. 47 ().,.'"'"'.,.:..,.:. pRELiMJ NAi~,Y. COIr'?.~¥ 10 S 1 0093 0 .,. 20 · ::: 0 ,. 01 0 ,, 20 48o 3 · ,:) ,,.,. 0 39°9 '4704 .....' ~ I3 18°:? '64o7 "" :L '"' 8 .;; O ~. ~.'.; ,:;) 'e 47 ° '7 "~'"': 0 48 7 26°7 30 o 9 ?;~S · "' .=J. 4::ii ° ,3 26; 20°4 4.1. o4 79,9 ':I. 2o7' · 't 7.6 '':'':: -' "' "'" ' .O ..:) ~. "' ~ 4 0 · :~o... 1' 4 0 .-) r) I:." ;' I::' .,.'.. ,:. ,0' ,,1''~ 7:~ ¢' ,..l These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories, Inc. (all errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations, as to the productivity, proper operations, or profitableness of any oil, gas or other mineral well or sand in connection with which such report is wed or relied upon. CORE LABORATORIES, INC. Petroleum Reservoir Engineering ~ALLAS, "l" mc X A S A N A L." ~'TM"' S ,o/o ~' TI... ,'RI:zB PRELIMtNAi.~Y COPY i l',l F:' L.. E I:l Iii: I::'"1" I..I F:' E I:;: l'.115 A :8:1: I... :1: 'T' Y ( l'.'i I:i ) IM B E R I.-. [.!: E'I" i'.'l. A" " ,,. :1: M t.J ?'1 '.;." 0 D l!i: 8 ',,,' E: R"[' :1: (., ~,1... .1. 79 9' 027,0 0,, 0 ',5 O00.,..'.'"' 000:1. 5 ,, 8 .,.:. ,. 6 '9 'i .1. 80 90""'"' ,.., ,' O0 0 ,, 09" 0 68 .,.:. c:. 00 0, ':"'"" 29' '..;: .4 "' ? :1. 8 .1. 90 '" .,:.. 9 ,, :1. 00 .1. 0 0 ,, 0c)"' 000.,:..'" 6 ,. 4 ' .,..:"" 0 ? :1. ~ ,'~ " I.":' ., ..,.,~ .1. o ~ 90,30 ,, ,.., 0 .,. :I. 7 O0 :I. ,i'; 0 ,.. 0 S."5,..5 . .,..'. ,. '70 '" 0 08 ") !5 "' .1. 8,3 903:1. ~ ~.:. 0 ~. 007 000 .1. ° :1. ~..:, 74 184 90 "'" "' " ~'.'. '"' "~ ":'"~ ,:~.,..'. 0 ~..: 0, :1. 7 0 ~ :1. "' ,:~ .~.,~ 06 . 0 / .,:.0, ~:. .1. 8 ,'.5 90 ~ "' '" "~ ,:.,,:~ ~ 3 0,05 0003 0,03 "' ,¢,. / .1. 86 903400 2 ...., 97 '":' ~.. 04 0, :1.,.., ''''" t:!; ~ .1. ~.:.'" ° ~.,~-,:, © 187 9 "'"'"' "' " ,'~ " '7~ '":' '" 0 ,:~ ,.~, ,:~ 40,3~....'" 0 ~ ',::'; 4 ,. 027 ,,., ,...: ~ 70 188 90TM' 2 .... ,:~ o0 .1. 00:1. 5 00 .1. 4 0,0'? :I. 0 ~. 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Thc interpretations or opinions expressed represent the best judgment of Core Laboratories, Inc. (all errors and omissions excepted); but Cor~ Laboratories, Inc. snd its officers and employees, assume no responsibility and make no warranty or representations, as to the productivity, proper operatiom, or profitableness of any oil, gas or other mineral well or s~nd in connection with which such report is used or relied upon. CORE LABORATORIES, INC. Petroleum Reservoir Engineering DA L.L. AS, TEXAS F:'A G E '" i.. [... 0 .~( .... A A L.,.., o1', ~.. ~, I N C · 3 U T I"1 B A ¥ ~'T' A T E :11:1 X) A 'l" E ~ F:' 0 R i'"l A 'T' I 0 N ~ I... I S B t.J R N Iii: .... o T,..,RI', ANAL. Y,"3I"' .'OEAN < .... """ PRELIMINARY COPY :~ i"i F' I.. E I:I E F:' T I"1 · J i'"i B E R F:' E IE '1" .....09 , ,,,.,, .~ 'l 210 o r,.:::'.:) 1 ! 211 ? 0'59 ~ 0 2 .1. 2 ? 060° 0 21 ,.'f,. 906.1. ° ,..,':"' 2.1.4 2:1.= ,J 90630 · .:. 16 ? 064 ·~. 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(all errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations, as to the productivity, proper operations, or profitableness of anY oil, gas or other mineral well or sand in connection with which such report is used or relied upon. CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS ~RCO 3 0 tJ T I'.1 AI...A,:.,IxA, INc0 BAY ~ '" ,:~ T A'[ E. :11:1 :(:i A T E F' C1R M A '1" I 0 N ,:> I R lEE t. Jl... T ...... . ..:) C) .::,1, B Iii: A N'"' S T A R I'( ..5. N A 1... Y S I S 3 A M 1::"1... E: ',lUMBER 2:.~9 240 241 244 ,:.4 ,:5 ,..47 ,:.4 2.49 .... ~..I 0 .. ,~..I 1 ."% 253 e.) x~ O 6 2~8 260 261 ,'.. ,..# 263 264 265 ,~66 267 268 BI::.F TH F"' E: [':.' T 9088.9 9089. 9090.0 90.9 .1..~.... 909'~ ,:..0 909S. 0 9094 .o ~... 909~ 0 ....I ¢, 9096 o 6 9097 ·~..'."' 9098 o,... ''~ 9:1. 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'.,I ('}) ,~::i * s ~ r;~ (.:.:, :1,"[" ;". ,:i~ c. · * 9',"5 · .~'"!; d(.:.)s:.~ o S i[.~ IYi C.:' .... ,. s i~ r, e *'f' ¥' ii~ c- · * 60,..,~...:.~.'..~"' ..... ii;ii~li'le :L ''~ ' "~ .,..; ,;'::, ,.., (.:.:. ::....~ .> '" '['" ',". a c.o * 7'::' "' '2~ iS I'fl e /,.. ,..~ ~..i e !.'J · ~i~..E~ ITl e -.'{~ '[" Y' ii~ C' , ,,-{( "'; ~::' .,' ,..~ de::.'.J ~.~; ;~ I'h (.:.:' ~ o o ]. ,:::,"~ 0,..~.::'....~"' ...... '.'!~, .~J~, I¥, e .1. "' '""' d e .':.:.~ i,.,~ ..... · S ~.~ I¥~ (.:.:' ].,:~,""' 6 ..~ ~..-: .:..~, s ~i~ rn e *'[" 'r'. a,:::. · * .1. 4 5 ,"' ...... · ..I ~,'.'.' .'v:f I..I I.%;, :;..-~ · s al: rn,:.:.:, 14 6 .... · u(.:.:'.t:~ · 5~..[i~; ii'~ e 1 ":' '"' ,..~ 1 e .?i, I..I s ~: m e10 0 ,':.'i e :'..:~ · s ~i.)rn e1 ',5 3 "' . . '.J e..:..'.~ · These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories, Inc. (all errors and omission~ excepted); but Core laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or repre~entitlons, II to the productivity, proper operations, or profitableness of any o11~ ~ll et' othe~ mil well o~ Id L't connection with which such report Is used or relied upon. · ?' ' ~ , , ,,,. , ,,' , ,~'-,?', ,., · , , ~ ' , ,,~ ,,. ! ,, ~ ~ , , ~ i~ : , :,, ~ , CO ~LA° · ~KA~ INC. :U T I"1 B A Y ,:~ 'T ,.-, T ['.. :11:1 ii"iF'L. :E li'.l I~ ER 267 271. 277 27t3 ~79 280 28~ 284 2 ~..: · ~...90 29~ 296 297 B E P T I'.1 F; E [.". T 9118,0 9.1..1. 9, ,.;. .,-..0 · 0 ? 1,..:.'" .1., 0 91 """:' ":' 9.1.,:.."':' ?; o 0 9' 1 '" ":' .,;;. 4 o ...:. 9125° ":' .. .1,% 9126 o 1 91 '" TM .c:./ o 4 9' 12 8 o 0 9 :L "'"' .,'.; ';" .~ 4 9:131,0 · . ,.:, 9 ]. 5 ~;., ,.. 91 "TM · ,:) ~;," · 4 9.1. 34. ~... 9136.6 9].S7 ~ ]. 91S8.0 9 .t 59. ~..: 9140.3 9141 o0 914 '~ .,: o 0 9.1.4S.0 914.4 o 0 914 ',".";. 0 9146.0 9147. '5 9148.0 CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, ~'IEXAS B A'T' E ~ F:' 0 R H A'¥ I 0 N S I... I c .... , ,:~ B U K N lie PRELIMINARY COPY F:' E R H lie A B I I... I 'T'Y ( H Ill ) l'.l A" ' " /x I H t.J i't :20 I:l I!i: G V E: R'T' ]: [., A !..." 0 o 56 O. 3~..'.'" 0 · "' '') ~..:.,... 0 · 07 ,.~ 1 o 39 0 o 0 ? 0.07 ()~ 16 0.1 '2 0 o 25 O o ''~`. TM,., 0~.1.0 0.07 ' '77~ 46, 15 ~ 0 7.16 6~ 09 1 .1. ~. 0 ~ o 0 I . 0, S 4 0. ~,.,. 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'.70 9,,. 4 ":' 9,. 0 ":' .,-.. ° 70 1 ":' ":' .,... ,, 7.,... o '2' 1 1 .1.,,7' ":' .,..,70 ~" '::' '" 69 .1. 1 ,, 6 2 o 69 10 · I '.':' .,..o 70 11..4 o 7 ":' .,..,70 11 ,.. 7 '::' '"'":' ..... 0 .." a:. 9 o S "~ .,.. o 77 10 , ,"5 2.. 81 r". A · ~ 01 L.. W"F R · 50 o S 45~9 46 o ''~ ;'3;3 ° 0 56.8 ~':~ l:."; , 6 28,4 4 .1.. 0 60.9 4 Iii o 6 46,S 9.;'?; :Ii 0.0 .'1.' :1. ,.7 :1.4.6 ~, ,1' '"~ 18.4 .1.9,6 2S°6 :1.6.4 :t 5.0 :1.5.5 46.S' I::' ~") I::' ,,:,,... · 8 .1. S.,. ,.., ':::":' 4 ].'::',.., ~. ,.."::' · .,I ...;. , 39°5 14,6 46.4 .1.4.2 44°6 16,7 '1~' ' ,.~ 3 · 1 .1. 3,13 5 S 00 1304 .1.4 ° 7 67°':'-,., :1.0 °6 75° S These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories, Inc. (all errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations, as to the productivity, proper operations, or profitableness of any oil, gas or other mineral well or sand in connection with which such report is used or relied upon. °RCO AL. ASIIA, INI];. 30U'T'H BAY STATE :I1:1 .~AMF I...E i',! LJ H B I::. I'~ 3O0 ./ 30.1. 30 ''~ 303 304 S 05 3O6 ,:~ 0 ,, 308 309 311.0 311. 2 314 31 ,.~ 3.1.6 ..)" 312' 320 321 322 324 ~26 328 I) EI'""'T H F:' .F:: E'l" 9.t 4s' .3 9.150.0 915.1.. 6 9.1.52,1 91',54,2 91 '"" ':'" "> 9156,1 9 :t ',".";7,5 9 :L 58.3 9.159~0 9160.0 9.1.6:1..S ~J. 62 · 0 9' 163.0 9.1.64o0 .9'1 '"" 9166o5 91167,2 9.1.68,.1. 9169o2 ~9170,2 9171,2 9.1.72,1 9.1.73,0 9].74,0 91''~ 0 9'].76.0 9177.7 9.1. 78.6 CORE LABORATORIES, INC. Petroleum Reservoir Engineering D A L. L..A S, TEXAS BA'T'IE:. .' l::' 0 R t"t A '¥ I 0 N : L. I S B U R N Ii.": 0., 31 0,24 0 · .1. ? 0 . 12 0 , .1. 6 0 o :I. '::' 0° 17 0 . .1. 0 . 1 · 7 ~::,. 0.79 7'iSo 1 , ,."::; 4 " 1'.81 1o74 .. 1. :31 0..47 ~..'. 4 o 1 S · ,.' 0 . 15 ri . 0''' 02 '0'45 .... ' 0 ' .1. 8 0,62 2.47 0.6S ( 1't I) ) P 0 R El k ,.., .[ N I) liE: No · - t,; /'"~ I:;' 17 · '5 ~:.. '~' ,.~ 1,9 i;;".., 66 4,3 2°69 .1. ,9 "' '"' ^':, . C) C) 4.7 2,69 "~ ,...o?.1. 4 o ';~ "; '" ,. ,... o /1 5.8 2'. 71 6.9 .,:" o 7.1. :7,5 "' 7"~ ^':. , " 8 . 9 2 o 73 8, ? 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The interpretations or opinions expressed represent tho best judgment of Core Laboratories, lac, (all errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or tepre~ntatlons~ as to the productlvlty~ proper operations, or profitableness of any o11, ps of other mlnerel well of ,and In oonnectlon with which such report ii used or relied upon. ~ I , CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS :CO ALASKA, :I:NC, ILJ T I"1 B A Y S'T' A'1.' E :11:1 : 'T' 1... S ~ R B B PRELIMINARY COPY H F' L. E I) 1F. PT I"1 M ]E'~ E R' F' E: Iii: T S29. 9:1.79,5 '~/ 3S0 9.1. ,:~ 0,0 7, 3: :1. ? .1. 81 · 3 ~ 2 91 Iii ~.:. 1 3,33 9 :Lo'~::~, 0 3 ~ 4 '9' .1. 84 + 0 9 :L '"'::' 0 (D ...J * ' 3S6 9 .1. '" o 600 337 91 "'" 338 9 .1. 8 ,.'339 9.1. 89,0 340 9:1.90o 0 341 9 .1. 91,0 34o 9 .1. 9''~ · ,*. ,~:, 0 0 S43 9 .1. <?,So 0 :.344 9.1. 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'3 ii~ rfl ~:.:.:,~..~ ~...: :...~ 0 o :':~4 "' ...... 0 0 · ""'::' '" "~ ,:~ ,.~ 0 ° 1.,,:"' 0 · ~::'" ",:~ 9 .., 9 .,,. ° '713 ,,. 4 · 0 .1.,.~'::' o ? 9 "." .? 'p ..... 94 ,::.o 3 .67 "":' 6 7° 4 ') ' C' '" "' 00 k. <':> ° 0.4 0 · 0'::' 7 69 41, ...... .:., .,;'. o .1. ,1. g ,.:'::' #'5 '° 0 o 1~...."' 0 · 10 0 o 0 S 5 o 1 ~.... o" 69 4 ::.',. o 4 ~.... ,ii o 0 These analyses, opinions or interpretations are based on observations and materhls supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories, Inc. (all errors and omissions excepted); but Corn Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations, as to the productivity, proper operations, or profitableness of any oil, Bas or other mineral w~ll or sand in connection with which such report is used or relied upon. CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS ~MF'L..E . I)I?PTH J/'"~ B E RI":" E E: 'T 359 9 9 o 2 0 0 "~ 360 5: '')' ~,...L 0,0 ,/36.'1. 9'"' .,.:. 11 0 ~ '"- "~ 9 '" .1. '" ~.: ,'.'., 0 ~..J ~../ 36S '.? o :1. :~, ", ,,,,, ~.,', 3<54 92.:L 4 o ,.~ ,.~ 9,,..1.5o5 366 9'"16, ' ,.,'.; C.1. 367 9.,:;'" .1. 7 o 0 ;;';68 9 '"' 369 72.1.?,0 370 9 © '" ,,...,....0,1 ['~ 71 9 '? ''~ .1. o 0 ~..,, ,,~., 372 9'""' 9 0 ,,=', .~', ,,,,, · 373 9 ,'.: ~'.. ,] o S 74 9 "2 '2 .'.1,0 375 9 '"') ~.:,,.. 5,0 t376 9 "'"' ' ,,,: .,..'. ¢':> ,, 0 .,. ,:~; / 9227 .... ~ .,-.. 378 9' 2 ''~''' "' ,, :4, (:~ ~ ,c,; 379 .,'...,,: ~' . 0 9")'z0.,:.,., o 0 381 c:~ , .,... ,:, 1 , 382 oo.~o ,-, .- ,,,...,.. ~.'.. 0 ...:'. 383 o ,')-.,-, 0 385 o~ / ..:.'. '"'t'.,'.'. · ~'."i ,:~ o 6 c;, .":, ..4. "z -'3 · ' .,.;. 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C'," .. · ~.;) z,,.I f..~ .. ,,:.; o C) 2°69 ~-.. ,7:1. 2.73 "~ .... · 72 ') 7"~ .~.. · .,,,;. · .,' ...'.'. ...:. ~. (.:, (i,I, ^'.'. e C) ~... · 7 0 A N A I.,. Y S T S : 'T'I,.. S, R I) B PRELIMINARY COPY 46 ..,;) / S ,S '...:.'. 6 1 17 S8 46 ,.32 60 * .4,) · 8 °6 · 0 ° C) · 0 ' "" I'"' "'"' % B I.:. ,:., C I',. I F:' T I 0 N de~o These analyses, opinions or interpretations are based on observations and materials supplied by thQ client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories, Inc. (all errors and omissions excepted); but Cora Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations, as to the productivity, proper operations, or profitableness of any oil, gas or other mill~ral w~H Ot s~lld ia ~orutection with which such report is used or relied upon. CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS PAO)E .1. 4A :CO AI-..ASKA, ]:N[;o IU T H B A Y S T A T f.'!: :I1'. 1 ~,MF'[..E ;MBER ) 7390 ~'~92 ~.'74 S95 S96 S97 ,'398 4O0 40.1. 402 40S 404 405 )406 . 407 409 4~0 41 ~ 4~3 41~ 41~ DATE: ~ F' 0 R M A T I 0 N ~ I... I S B U R N E PRELIMINARY B lie F' T 1..I 'F" E IE'T' 9246, .1. 924? ~ 0 9248,0 · ~' ,..'. 49.0 I o .1. 5 I:;' "' "~'""'" :'3 0 o ,.~ ~ , ,. O080 ..... ~ ~..: · ~... < 0 o 01 · :.,.,,3.0 7 o 01 '? ^'.'...J ~"i ~..,. 0 ~. ''y ~''' , , ~' ,'..,.~,.~ ~ :I. .1. o 64 9" 2 · ,..'.56 ~ 0 .., ?5 o, .,..."~ ,.,':': 7,0 7,, 06 , ~,.,., 8° 0 ~.., .. ,., .,..: o 0,0 · ;'..1. ,.I ~.. 61,4 .1.,,..~':~ .,..') .,: c>.,.:. 0 1 1 0 "' .92' ''y "' 9' ''~ .:-/.- 0 0 ~ 67' 9' 26 ?~ 4 7 :[ '""' ,... ,., c,, z. 6,88 · ~' .,'. o 'r ~ ,.., 0,20 9,:"70' · 4 0002 ~' ~..'. ~ .1. ,,; 1 .1.01 o 9272 , ','3 47 o >' .~'. / ,:>, 0 0° .::...: 9~ '"'::: I 0. :'30 P E R H lie A B I I... :1: 'TY ( H B ) I" Ol's ..... {.'~ I'~ ,.., ]. N.. F!' 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(all errors and omissions excepted); but Co~e Laboratories, Inc. and its officers and employees, a~sume no responsibility and make no warranty or representations, as to the productivity, proper operatiom, or profitableneas of any oil, ga.~ or other mineral well or aand in connection with which such report is used or relied upon, CORE LABORATORIES, INC. p ^ t**. ' r.i ~.'J I::. ]. '::' ^ ~J I"1 Pctrol~,~ R~r~otr ~1~i~ DALLAS, TEXAS ~CO Al.. A"' o K A, I N C o ) U TI"I B A Y ,:, l A'T' E: :11: .1. F' I.. E I) E F' T I-'1 l"i B E R F:' E l."i: T 419 9276°5 )' '2. ,-,,;.0 9 77,7 .42.1 927°. ,,,0 4 ..~..,:.. ~.:. ~ ~ 0 .,..80,0 424 9,:'" 81,0 '~T ~'. **.~ .,.:. 42~ 9""'"' .1. ,:;) ~;) · 427 9'" 8.4 o~.:. .1. 428 9285 o 0 429 9"'86,.; o .1. 4 S 0 9 ') "' ,.. o 701 4S 1 928 8° 0 432 "'~':c~9,4 4~S 9290,0 4 S 5 o ,'~ o ,': 4,36 9 ~... 9,:~ 0 4S7 929400 ~ ~: ~-,., , .1. 440 ~ ''~ o. ";, 0 441 · 9299,0 442 9300,0 44,'3 9301 444 ~'"02 445 9303 ·-,'5 446 9304,4 447 93O5° .1. 448 9,306 o 0 90 I)Ii!: G .104.l 0,41 ()~0:3 ' O00:L 0 ~ 09 .::: 0,01 0 o 01 0,10 0021 0 ° 01" 0 ° '75 0 o 31 ()~ 11 .::: 0001 0. 00 ,,:"' < 0 o 01 0 o 05 .::: 0 o 01 10013 O o 10 0,02 0 ° 02 0002 . 0 ~ 0 ;3 000 .1. .::: 0001 O001 0 o 0.1. ~, , O o 02 0° 11 9 ° 72 .,'5 ° S9 *"'~ I::' ,':. ,.~ o ° 0 2 19 o ' ',3 o 49 100 3 16 o 10 0 8 o ,0 o 0 ! (;) o .,.-.: .1. o '::' 7° 6 o 0 .? 4 o 0 e,,, ~,.,, ,~:', o ~.:, · '"~ 0z,':o ''''~ ?°0 .1. 3,1 14 ° 7 .1. 7 ° ~..'. PRELIMINARY coPY, ..,'.. ~."') C.) 1 ,':., 7S ,,: o 70 ") 70 ~, ~ ~.~ ~. ~.,.. 67 _.67 2,7 '5 ,:., 80 ,,:, 71 .1.3.7 1 1 o :3 7°5 · '~ t' 26 ° 0 20 · 4 SO · 9 ~...6 o 0 · ~... :1. 39,7 '27°9 ." S .1. 42 5 .1. 21 .~,;. / 36 These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judsment of Core Laboratories, Inc. (ali errors and omissions exmpt,d); but Cor~ Laborltories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations, as to the productivity, proper operations, or profitableness of any oil, 8as or other minm~l well or sand in connection with which such report is used or relied upon. CORE LABORATORIES, INC. Petroleum .Reservoir Engineering DALLAS, TEXAS F i... C',E .1. &A F',CO ALASKA, Ii',l[.;,, D tJ T I"1 B A Y S'T'A'I" E :11'. :L D A T E : F:' [..1R M A 'f' ;1: CI N ~. I... :r. ,g B U R N F F' I 1... E. N 0 : B F: ..... ,"3'"' 1:385 ANAI...YS' '~'' T ,:~ : 'f'l... S :, R;O B ., AMPLE UMBER ) 450 451 452 453 45.4 4 ,,J ....~ 4'56 4~7 4',58 459 460 46.1. 462 · 463 464 46~ ,) 466 468 469 470 47.1. 472 473 474 476 477 478 I) Iii F:' T I"1 I":' E E: T 9307° 1 9309,0 93:1.0,. 3 93.l :L, 2 9 3.1. ''~ © 93.1. 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(all errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations, as to the productivity, proper operations, or profitableness of any off, las or other mineral well or sand in connection with which such report is used or relied upon. CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS PA G l!~, 17 A ~CO AI......,:~I',A ~, IN[., 0 :)I.JTI"I BAY o ,., ]"A T E 11: .1. I) A 'ir' E ,' F' 0 R H A 'l" :l: 0 N ~ L.. I ,S B U R N I?. C' 0 R Ii:". A N A I... Y,g :[ S R r..~. ~i; I.J I... T S .& ^ ',,! (.,, I) E A N"" S T A R I'( ,.., N,.., L.., ,:~ :1: ,:~ ~HF'[..E :[IEPTH JHBER F'EET 479 o':,, 'z-,. 4 480 933111.0 481 93390 4,"32 9340~ 0 483 .... .,~ .1. 0 ~... 4`'.-]4 934'" 4`'.'.35 93.43. 486 9 487 9 S 4 '"" ~JoO 488 .9346 ° 3 489 9347° 0 490 9,34~'' 0 0 3 49.1. 93.49° 4 492 93'::0,,.~ 0 493 93.'3 ':"' "' ....I 1 ° ...'.'. 494 93 495 ?o5'~ 0 496 9354.4 497 ~'" · ~' o55 ° 0 498 93':: 1 499 93 ':"' 1 ,,.,I 7 500 93',:'.;"'. o 0 0 · , 01 93 '": 502 ?~60 ° 1 503 9361 ° 0 504 o'~ .~, ~. 0 / ~.J'k.t..,',. 0 ~ C) "7...". ",>'. ~.,; 0 5 506 9364 ° 507 o.',, ~' ,:)o,., ° 0 508 '~-" ' F:' E R H Ii!: A B I I... :l: 'l" Y ( H I) ) M A X I H U M' 90 I)Ii!: (.'..l VIE R'I" I C A 1... 000 3 0 ° 0 7 0 ° ~.... 1 (), 0 3 .1. 8. 2083 .1. 006 0° 28 0 o 40 0 · 02 O. 01 I ° ~'''''' / ,.~ I o '"'"' -,., 0 0 '""::' ~:: ," 0045 000 S 0 ° 03 0 o 02 .::: 0001 0.0:3 0 ° 02 .::: 0001 0 o 01 0 ° 0.1. 0.01 0 00.4 0 ° 03 0 ° 87 0,2! 4 0 ° 16 0 ,. 05 0 ° 05 0 · 02 0 o 09 0 °3S 0 · 17 0004 ,.,F:' [::~ R G R A' :[ N- % DEN, .. 4 0 6 ") "~ ~.:. 0 '7 407 ':) ° 7"'- .,,.. 8 o 6 "~ .,... ,76 4° ,.., .,... ,,. '76 ':) "!, ~..o7 .,. ° 6[3 ,.,, ,:.o 70 J. o 2 2... ° 69 · "' '1 .,..: ,. 0,.... · 70 .1. o "') ,... .... ° '? :1. 1 o 5 .,... ° 69 1 ° 1 "~ .,... ° 67 1 · '::' ,.~ ,,. ° 70 1 ° '7 2 ° 69 '~'~ · · . ° 1 7'" .,E. o 0 ° 27 0 °.,.:. ,.'" "" 1 ·29::.. 4 ° 9~ .... 0 [31 0 ', 05 0 ° 04 0 · 06 .,..':~· 1.,.:.'" °' 74 0 · 02 0 ° 01 :::: 0,01 5 ° '? " . ~.:. ° 77 0.17 0 · 0 ::] 0 · 1,.~'::' S00 "~ ,,., 76 0 · 2 :"3 0 · 08 0 ° 02 1 °.,... ©,...°'~ 71 ,.~ ~..."~' '° 8 0 · .48 O° 14 0 ° 02 I ° 6 ,...'~ ° 70 ' o' ° :1. 0.65 0 o 64 1 ° :'~ 1 'So 0 2 ° 69 6.5 0043 < 0° 01 1 ° ..4 .,.:. 0'" o' o"' .'L O° 0 0 ,. 0 .1. 0 ° 01 < 0 ° 01 1 ° 3 .,,."~ 0 o" cI" 2.. 1 ° ,:~"' ,;:, ,:;. ° 1 6 ° '::' 0 .. ,.~ o z. 7 ° z. ,,. ° 77 .1. 2 ° 9 707 "~ "~ ~.074 .1. 9 o ...,. 24 ~ :L 10 14° '" '" '"'": .. o · 5 ~.:. o ~ ,., Iii ° 8 5 · '""' 2 ""'' 7 ,.~ .:. ° "7,:~ .1, ° I"- I 1... E i"40: B F: ..... 3 '"' 8 [:35 ANAl..."'"'"" .... ~ .... "' · o, o ~ T I...,:~, Ix I.I B · F' I... U I D 8 A'T' S ° [) I L .... W T. R 8 37' .,.:. 7 ' 49,° ~,.0 6:1. ;.7 3 89"'0. S 6 86 ° 7 2,:5 66 ° 9 37 5 ''~' .,...1 ? '""' '" ~.1 0 (3 :1.707 550z. 46 ° 7 .. ",i~,~""'07 11 ° 2; o'"S 0 J; ,") ,...707 44 · ,~ 18 ° .4 6 ~ ,.~ · 0 :L '::' ,.~ 00 7 ' .... 2 0.'0 ,, · .1.400 .~8201'~ ~.:.7 ° 7 58,9 24.,5' 7000 .1. 0 ° 0 .';'"7607 PRELIMINARY COPY These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories, Inc. (ali errors and omissions excepted); but Cor~ Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations, as to the productivity, proper operations, or profitablenes~ of any oil, gas or other mineral w~ll or sand In connection with which such report is used or relied upon. ~CO ALASKA~ IN[,'o ' ~ A t"', ...... ] U T I"1 B,.-, Y ~:,l A I E:. .t1:1 B I:Z F:' T H F:' E E T 9367o~3 9S6801 9'3&9,0 '-/:~ 70,0 9~'7:L o 0 9`372°`3 937`3 o 0 9S74,0 9375~0 9S76, .1. 9S77 o 0 9S78o 0 9S79 o 0 9S80,0 9 ~ c}.,;., 0 0 '.'Z t'~ '? 4 C.) -7.. (') .4 c .. , ,;.- 0 :?S86 ~ S · -~, (.~ ~, MI""L. E JHBER 509 510 511 51S 514 515 516 517 5.1.8 519' I.~ ,~21 522 52,3 524 I..'~ ,~25 526 527 528 5G0 CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS F' ~.., b [:: ! 8 A I . ~ PRELIMINARY CopV O o 0;3 0 o 03 0,51 0.01 O o 30 0 o 78 0,14 0 · 02 54° ()o 0"' 0,0,,:."' 0° 02 ,,. 0~ ].1 ':' 0 ~ 02. · :::0 o 0.1. .1. t 2 `3 O * I::' ,' "'~' x'~ "') 0. ~,'. 0 ()~ ,, ,,... `3,5 :I. ~'.,,.., '20.. . 0,20 O o :I.o ~' .1.~o .I. ,76 0 · 05 (), 0`3 0 o ()iI (), 02 0 o 0 .1. (), 01 < 0 ,, 0 .1. 3,, 04 0 ° 20 0,, .1. 9 O° 11 0 o 56 0 °79 0° 47 · ::: O° 01 .::: 0 · 01 1.5O o° o2 0 o 0 2 O o 01 , 0 .,. 0 4 0 o 01 ~... o 70 · ,,'. o 69 , '2. o 71 ^'.. o 6 8 ,:.°76 .,:: o 70 ~..'. °70 ,~'. o7.1. "' 6"2 .,;'. + . .,'.'. ° /'~2 t.) ..'(*~, .~:. ,~ C)C) . "~' 61 ''~' '''~ "~' 7 ° s "~ s m i¥, e .1. ~,. 0 "' ~,. 1 ~ 0 7`3 ° 3 ' ",. ,..~ e .';..'.~ ,.., ,:... ."~.;, ..., .1. ....;..,. ,.., & 4 ,..,~ '?.'i~..i!~ rr, e 13 ,.., ''':' ,..~ e ::..'.~ ,, ~ ( .,I., ;', ,. .... 1 ,$ 49 o 0 `33,5 :.~ ..... s m I;', e 105 "' ......° k.I ~;': ;:.'i . ' .1. 6 7. 2.4 ° ':'" ..... '"~ "' .... .... 45oS =:..",i:~ s~t;',e *i";".mc'o* 1.,;;,: ,..,~;;..?.~° 46 ° 0 "'?' ''~ '::' ' ,., .,;. ,,' ; ,, , ., ',~, .~ ,! '31.5 ' ~,~ 1 S g V f' :X .1. '2. :3 d e.~.:.~ ,. 34.7 35 o S ,,27!";'S , t.'~ 9 .,.:.0. :" 65; 1 .., :3'0° 8, ',:30° 4 16 · ~.:. ,.¢ 6 ~ o . ..... .:: 1,6 4'6,5 "' 2 8.6.~,' ' 4,.~ '=' ~ 25';2 44. S These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories, Inc. (all errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations, as to the productivity, proper operations, or profitableness of any oil, gas or other mineral w~ll or land in connection with which such report is used or relied upon. Su~gesned form to be inserted in each "Active" well folder to d,,eck for tirr~ly cc~liance wit.h our regulations. Operator, Wel 1 Nan~e a~ Number . Reports and Materials to be received by: ~--~ Z-7;~ Date .Required Date Received Remarks · , C cmp le ti o n Report Yes . Well History~ Yes -.. f · Core ~scrip:on ¥ ~ ~--~ V -- ~ ~ ~~- Registered S~ey Plat ~ t ~d~0n T~t Re~rts ~~ ~'~ , Digitiz~ ~ta ~ ~. -~,RCO Alaska, Inc. Post Office r,-.~. 360 Anchorage, .ska 99510 Telephone 907 277 5637 April 13, 1984 Reference: ARCO Open Hole Finals ARCO/EXXON i llll[lll[lllllti: South Bay State #1 11-3-83 CPL/Cyberlook 10-11/11-3/12-16-83 BHCS 11-3-83 DILL/Micro/SFL 10-11/11-3/12-16-83 DIL/SFL 11-3/12-13/12-16-83 FDC 11-3/12-13/12-16-83 FDC/CNL 11-3-83 RFT Run 2 5" Sch Run 1/2/4 2" & 5" Run 2 2" & 5" Run 1/2/4 2" & 5" Run 2/3/4 2" & 5" Run 2/3/4 2" & 5" Run 2 : ~n and return the attached copy as receipt of data. FRIDAY THE 13th is upon us - Have a Nice One! Kelly McFarland ATO-1429F Trans. #140 SPECIAL DISTRIBUTION DISTRIBUTION Chevron D &M Dallas Drilling Ext. Exploration (Alan Dennis) - Exxon Getty Marathon Jake Rathmel 1 _Y- q _. ,- . = - .'_.-:.--..fn :~ - - i -.-'~? Mobil Mobil E & P Phillips Prudhoe Bay Well Files _ ~r ,.,~<.? , , . Carolyn Smi~h~ -~/> APRZ Sohio State of Alaska Alaska 0g &~ncho~ag~Gas Cons. ..... ~-:---"~ 1 ! nc. ~.,~,~u ~. aska, Extension Expl or.~tion TRANSF'kI TTAL ' Bill-Ven Alen- AOGG From' -Lucille John.~f. on - Ext. te' April .11. 1984 :ansmitted herewith a~e the fo]~owing' Bluelines & Sep±~s (F±n~ls) ARCO' SO'UTH BAY ST: #1 12-16-83 BHCS Runs' 1,2,4 2" &. 5"' " NGT " 4 5" 12-17-83 DPMTR " " 5" '12-16-83 CNFD Runs 2,3,4 2" & 5" " FDC " " 2" & 5" 11-3-83 RFT Run 2 12-16-83 LSS " 4 5" 11-3-83 DLL/Msfl " 2 .2" & 5" " CPL/Cylk " 5" 12-16-83 DIL/Sfl Runs 1,2,4 2" & 5" 2-14,3-21-84 2-21,3-27-84 PRESS SVY Run 2 PRE S S~ SVY Job #69022 Job #69060 Receipt Ackn°wl edgment'~ ~.~~RC Return Receipt ~ O Alaska, Inc. Extension Exploration P. O. Box 100360 Anchorage, AK 99510 Attn' · L' - Alaska 0il & Gas Cons. Commission Anchorage Processed by:. Lue~ 1 le Johnston ATO-iO15 x4599 · ARCO Alaska, Inc. Extension Exploration T RAN SM I TTAL Date' ,_~- 14- ~,~z Transmitted herewith Receipt Acknowledgment: Return Receipt t~.'//~RCO A1 aska Inc. Extension E~pl oration P. O. Box 100360 Anchorage, AK 99510 Attn · Date- Processed A.-SCO Alaska, Inc. Extension Exploration -TRANSMI-TTAL From: Bate' ~ '- ' · -Transmitted herewith a~e the following' Receipt Acknowledgment: /' Return Receipt tjx: /~CO Alaska, Inc. L/Extension Exploration P. O. Box 100360 Anchorage, AK 99510 Attn' Processed b ..... i _ ARCO Alaska, In~ Post Office ~*ox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 March 7, 1984 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: South Bay State #1 Dear Mr. Chatterton' Enclosed is a Sundry Notice for the subject well. We propose to pull the 4-1/2" test string and replace it with a 2-7/8", plastic-coated, completion assembly. Since we have already started this work, your earliest approval will be appreciated. Verbal approval has been received from M. Minder, AOGCC. If you have any questions, please call me at 263-4610. Sincerely, ~ T. L. Fithian Area Drilling Engineer TLF/JG:tw GRU6/L22 Enclosures RECEIVED ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASK .)ILAND GAS CONSERVATION ~ MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTH E R I~x 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well . Surface: 400' FNL, 750' FEL, 5ec.22, T11N, R15E, UN 5. Elevation in feet (indicate KB, DF, etc.) 61 ' RKB 12. I 6. Lease Designation and Serial No. ADL 28322 7. Permit No. 83-143 8. APl Number 50-- 029-21019 9. Unit or Lease Name Prudhoe Bay Unit/Lisburne 10. Well Number South Bay State #1 11. Field and Pool Prudhoe Bay Field/Lisburne Lisburne Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing ~ Other J~ Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [] Altering Casing [] [] Abandonment [] [] Other [] 13. Describe Proposed or Completed Operations (Clearly state i]ll pertinent details and give pertinent dates, including estimated date of starting any 'proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc., proposes, to pull the 4-1/2" test string and replace it with a 2-7/8", plastic-coated completion assembly. This completion assembly will contain the necessary provisions for subsurface safety equipment. A 13-5/8", 5000 psi, RSRRA BOP stack will be used on well work performed by the workover rig. The BOP equipment will be pressure tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. Verbal approval received 03/06/84 from M. Minder, AOGCC. Estimated Start: March 5, 1984 RECEIVED AJa~ 011 & Gas Cons. L,~m~mlg.gl0r, 14. I hereby certify that_the fo, r,~oing is true and correct to the best of my knowledge. Signed ~--'~. ~, _~~4~~ Title Area Drilling Engineer The space below for Commission use Conditions of Approval, if any: Approved by COMMISSIONER Approved Copy Returned By Order of the Commission Date / -- Submit "Intentions" in 'f:riplicate Form 10-403 Rev. 7-1-80 GRU6/SN08 and "Subsequent Reports" in Duplicate '~ STATE OF ALASKA /~ _ " ALASK,-"~-"IL AND GAS cONSERVATION C'-'".'1 MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATION · Drilling wellj~ Workover operation [] 2. Name of operator ARCO Alaska, Inc. 7. Permit No. 83-143 4. Location of Well atsurface 400' FNL, 750' FWL, Sec.22, T11N, R15E, UH 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50-.029-21019 9. Unit or Lease Name Prudhoe Bay Unit/Lisburne CONFIDENTIAL 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RKB 61' ADL 28322 10. Well No. South Bay State,#1 11. Field and Pool PrudhoeBa~y Field/Lisburne Lisburne 0il Pool For the Month of. January ,1984 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks ' Spudded well t~ 1030 hfs, 10/04/83. Drld 17-1/2" hole to 3800'. Ran, cmted & tested 13-3/8" csg w/FS @ 3781'. Drld 12-1/2" hole to 8330'. Ran, cmted & tested 11-3/4" lnr. Cored f/8344' - 8713'. Drld 8-1/2" hole f/8713' - 8844'. Ream hole to 12-1/4" f/6480' - 8844'. Ran, cmted & tstd 9-5/8" csg. Cored f/8847' - 9477'. RIH w/8-1/2" bit. Drl f/9477' - 9819'. Cored f/9819' - 9954'. Ran logs. Perform DST #1. Drl f/9954' - 9973'. OH logs. Plug back hole to 9666'. Perform DST #2. Run liner.(continued on attached sheet) 13. Casing or liner run and quantities of cement, results of pressure tests : 20", 91.5#/ft, H-40 weld conductor set ~ 81'. Instd w/1910# poleset. ~13-3/8", 72#/ft, L-80 BTC csg w/FS ~ 3781'. Cmtd w/2400 sxs "Fondu" + 400 sxs PF "C". 11-3/4", 60#/ft, S-95 Hydril csg f/1636' - 6480'. Cmtd w/500 sxs "G" cmt + 50 bbl PF "C". 9-5/8", 47#/ft, S-95 hydril + L-80 BTC csg w/FS ~ 8836'. Cmtd w/550 sxs "G" cmt. 7", 29#/ft, L-80 BTC csg-f/8543' - 9700'. Cmtd w/175 sxs "G" cmt. -14. Coring resume and brief description Core #1 f/8344' - 8371'. Recovered 27'. Core #2 f/8371' - 8379'. Recovered 4'. Core #3 f/8379' - 8391'. Recovered 12'. Core #4 f/8391' - 8416'. Recovered 25'. Core #5 f/8416' - 8447'. Recovered 31'. (continued on attached sheet) 15. Logs run and depth where run Log #1 - Borehole Televiewer f/9954' - 8836'. Log #2 - FDC/CNL/Cal/GR f/9954' - 8836'. DIL/BHCS/GR f/9965' - 8830'. LDT/CNL/NGT/GR/Cal f/9973' - 8830'. (continued on attached sheet) LSS/GR f/9965' - 8830'. 16. DST data, perforating data, shows of H2S, miscellaneous data DST #1 f/9954' - 9750'. DST #2 f/9666' - 9450'. DST #3 f/9652' - 9486'. DST #4 f/9210' - 9440'. DST #5 f/9058' - 9200'. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge· SIGNED , ' .;.~//'~V~¢~ TITLE Area Brilling Engineer DATE 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 Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 D R N / M R 60 Submit in duplicate MONTHLY REPORT (cont'd) South Bay State #1 CONFIDENTIAL 12.) CO cmt to PBTD @ 9652'. Run CBL. Perform DST #3. Sqz perf$ f/9516' - 9566'. CO cmt to 9440' PBTD. Perform DST #4. Sqzd perfs. CO cmt to 9225'. Spot 75 sxs "G" cmt @ 9225'. CO cmt to 9200' (PBTD). Perform DST #5. Wiper trip. Log w/csg caliper. Arctic pack 13-3/8" x 11-3/4" annulus. Run 4-1/2" tbg string. ND BOPE. NU tree. Secured well. RR ~ 1500 hrs, 01/10/84. SEE DRILLING HISTORY 14.) Core #6 f/8447' - 8456'. Pressure core recovery not available. Core #7 f/8456' - 8465'. Pressure core recovery not available. Core #8 f/8465' - 8474'. Pressure core recovery not available. Core #9 f/8474' - 8481'. Pressure core recovery not availble. Core #10 f/8481 - 8538'. Recovered 56'. Core #11 f/8538 - 8576'. Recovered 38'. Core #12 f/8576 - 8585'. Pressure core recovery not available. Core #13 f/8585 - 8594'. Pressure core recovery not available. Core #14 f/8594 - 8618'. Recovered 24'. Core #15 f/8618 - 8626'. Pressure core recovery not available. Core #16 f/8626 - 8635'. Pressure core recovery not available. Core #17 f/8635 - 8644'. Pressure core recovery not available. Core #18 f/8644 - 8653'. Pressure core recovery not available. Core #19 f/8653 - 8713'. Recovered 58'. LISBURNE CORES: Core #1 f/8847' - 8907'. Core #2 f/8907' - 8967'. Core #3 f/8967' - 9015'. Core #4 f/9015' - 9076'. Core #5 f/9076' - 9136'. Core #6 f/9136' - 9196'. Core #7 f/9196' - 9242'. Core #8 f/9242' - 9299'. Core #9 f/9299' - 9359'. Recovery not available. Recovered 60'. Recovered 48-1/2'. Recovered 61 . Recovered 60 . Recovered 45 . Recovered 55 . Recovered 57 . Recovered 60 . Core #10' f/9359' - 9419'. Recovered 60 . Core #11 f/9419' - 9477'. Recovered 58 . Core #12 f/9819' - 9879'. Recovered 60 . Core #13 f/9879' - 9939'. Recovered 60 . Core #14 f/9939' - 9954'. Recovered 15 . 15.) Dipmeter f/9973' - 8830'. RFT f/9559' - 8868'. CBL f/9645' - 8370'. Csg caliper f/8520' - surface. DRN/MR6Oa:tw SOUTH BAY STATE #1 DRILLING HISTORY CONFIDENTIAL NU hydril and diverter system. Spudded well @ 1030 hrs, 10/04/83. Drld 17-1/2" hole to 3800'. Ran 94 jts 13-3/8" 72#/ft, w/FS @ 3781'. Cmtd 13-3/8" csg w/2400 sxs Fondu + 400 sxs PF "C". ND 20" diverter system. Installed 13-3/8" packoffs & tested to 2000 psi - ok. NU BOPE & tested to 5000 psi - ok. Tested csg to 1500 psi - ok. Drld FC + cmt. Drld FS & 10' of new form. Tested form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 8330'. Underream 12-1/4" hole to 13-1/2" f/3781' -8330'. Ran 119 jts of 11-3/4" 60#/ft lnr f/6480' -16~_36].. Crated 11-3/4" lnr w/500 sxs "G" cmt. Sqz lnr lap w/200 sxs PF "C" cmt. Drl cmt f/1630' - 1646'. Drl cmt f/1630' - 1646'. Drl cmt f/6226' - 6480'. TIH to 8330' Drl 10' new hole. Form leak-off test. RIH w/coring assy. Cut core #1 'f/8344' - 8371'. Recovered 27'. Redress core barrel. RIH. Cut core #2 f/8371' - 8379'. Recovered ~._' RIH & cut core #3 f/8379' - 8391' Recovered 12' RIH & cut core #4 i~/~391' - 8416'. Recovered 25' RI~ & cut core #'5 f/8416' - 8447'. Recovered 31' RIH & cut core ~6 f/8447' - 8456'. RIH & cut c ore #7 f/8456' - 846~'. Ream 6-1/2" hole to 8-1/2" f/8447' - 8465'. Cut core #8 f/8465' - 8474'. RIH & cut core #9 f/8474' - 8481'. RIH & ream 6-1/2" hole to 8-1/2" f/8465' - 8481'. POOH. RIH & cut core #10 f/8481' - 8538'. Recovered 56' RIH & cut core #11 f/8538' - 8576'. Recovered 38'. RIH & cut core #12 'f/8576' - 8585' RIH & cut core #13 f/8585' - 8594' RIH & ream 6-1/2" hole to 8-1/2" f/'8576' - 8594'. Circ + cord hole. PO0~. RIH. Wash & ream f/8569' - 8594'. Cut core #14 f/8594' - 8618'. Recovered 24'. RIH & cut core #15 f/8618' - 8626' RIH & cut core #16 f/8626' - 8635' RIH w/8-1/2" bit & ream f/8618' - 8'635'. CBU. POOH. RIH & cut core #1~ f/8635' - 8644'. Cut core #18 f/8644' - 8653'. TIH w/8-1/2" bit & ream 6-1/2" hole to 8-1/2" f/8635' - 8653' Cut core #19 f/8653' - 8713'. Recovered 58'. TIH w/8-1/2" bit & drld ~/8713' -8844'. Circ. POOH. RIH w/9-7/8" bit & ream 8-1/2" hole to 9-7/8" f/8340' - 8428'. CIRC. Ream f/8428' - 8621'. POOH. Underream hole w/12-1/4" underreamer f/6480' - 8844'. POOH. RIH & re-ream f/6480' - 8844'. POOH. RU & run 207 jts of 9-5/8" csg w/FS @ 8836'. Crated csg w/550 sxs "G" cmt. Land csg. Test pack-offs to 3000 psi. RIH w/8-1/2" bit. Tag top of cmt @ 87D4r~'d. Test ,csg to 3000 psi. Drl FC & cmt to FS @ 8836'. CO to 8844'. f/8844 - 8847'. Form leak-off test to 13.1 ppg. Clean mud pits f/chng to oil-faze system. Displ well f/bland mud to oil-faze. TIH w/core bbl #1. Survey. Cut core #1 f/8847' - 8907'. CBU. TOH. Recover core #1. TIH & cut core #2 f/8,907' - 8,967'. POOH. Recovered 60'. TIH,w/core #3. Cut core #3 f/8967 - 9015 . TOH w/core #3. Recovered 48-1/2 . TIH w/core barrel #4. Core f/9015' - 9076'. POOH. Recovered 61'. RIH w/core #5. Core f/9076' - 9136'. POOH. Recovered 60'. RIH w/core #6. Cut core f/9136' - 9196'. POOH. Recovered 45'. RIH w/core #7. Cut core #7 f/9196' - 9242'. POOH w/core #7. Recovered 55', (15' of which was recovered f/core #6). RIH w/core #8. Cut core f/9242' - 9299' CBU. POOH. Recovered 57'. RIH~: w/core #9. Cut core #9 f/9299' - 9359". CBU. POOH. Recovered 60' RIH--'.' w/core #10. Cut core #10 f/9359' - 9419'. CBU. POOH. Recovered 60'. w/core #11 f/9419' - 9477'. CBU. POOH. Recovered 58' f/core #11. RIF~7.! w/8-1/2" bit. Drl f/9477' - 9819'. CBU. POOH. RIH w/Core #12. Cut cor .e~._:. ??~ ~-.--~'z f/9819' - 9879' CBU. POOH. RIH w/core bbl #13. Cut Core #13 f/9879':. 9939' CBU PO~H Recovered 60' RIH w/core bbl //14 Core f/9939' - ..... · . July 18, 1984 Mr. J. L. Fi thian Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Prudhoe Bay Unit Wells South Point State No. 1, South Bay State Ro. 1, Pingut State No. !. Dear Mr. Fithian: The Commission considers the date that triggers the 30 day filing period for the completion report, deviation survey or inclination survey, and other required well data to be-the date the drilling rig is released whether or not preparatoryJto extended testing of the wel!. Our records show that this date for the listed wells is August 8, 1983, January 10, 1984, and October 3, 1983 respectivelY. We have no record of having received all the required data. Please submit the required reports at this time. Yours very truly, Harry W. Kugler Commissioner JAL/be: 1. HICK. F ARCO Alaska, Inc. ARCO Explc~_~..._n - Alaska Operations Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 277 5637 HAND CARRIED SAMPLE TRANSMITTAL- SHIPPED TO: DATE. JULY 17, 1984 ALASKA OIL & GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501 ATTN' MIKE MINDER OPERATOR: ARCO NAME' SOUTH BAY, ;STATE #1 SAMPLE TYPE' CORECHIPS NUMBER OF BOXES: 33 SAMPLES SENT: BOX # 1. 8344-8373 2 . 8374-8402 3. 8403-8426 4 . 1-8427- 8447 S. 8493-8522 6. ~3-8546 7. 7-8577 8. 8594-8618 9. 8653-8686 10. 8687-8710 11. 8848-881~ 12. 8882-8916 13. 8917-8948 14.- 8949-8978 15. 8979-9009 16. 9010-9040 17. 9041-9072 18. BOX # &8481-8492 19. 9106-9139 20. 9141-9173 21. 9174-9209 22. 9210-9235 23. 9253-9279 24. 9280-9314 25. 9315-9349 26. 9350-9384 27. 9385-9418 28. 9419-9455 29. 9456-9477 30. 9830-9863 31. 9864-9894 32. 9895-9924 33. 9925-9954 10 ' SHIPPED BY: PALEO LAB TECH &9242-9252 & 9818-9829 UPON RECEIPT OF THESE SAMPLES, .PLEASE NOTE ANY DISCREPANCIES AND MAlL A SIGNED COPY OF THIS FORM TO' ARCO ALASKA, INC. P.O. BOX 100360 ANCHORAGE, ALASKA 99510 ATTN' R, L. BROOKS ARco Alaska, Inc. is a Subsidiary of AtlanticRichfieldComPany · ARCO ALASKA, INC. Extension Exploration TRANSMITTAL )- C. Vi. Chatterton - AOGC From- Lucille Johnston - Ext. Exploratio~ ire- May'14~ 1984 Transmitted herewith are the following' One Copy Each ARCO- W.S. Pilot #13:'~ 6-17-83 Registered Survey Plat /W. Sak #24 ~ W. Sak #24 S~. Bay St#1 Lis Tape #65031- 4-12-82 Run 1,2 Open Hole " ", #~42~3~0 z4-5-82 Run 2 , HDT ,- ~is TaZpe' #69125 12-16-83 Run 4 LSS/wf Listing D.S. 4-20 ~D.S. i8-i Lis Tape #68524 9-2-83 Runs 1,2 Open Hole Listing Registered Survey Plat 5-9-82 MUDLOG 6-8,23-82 Note' /-'On this well, please contact Teresa Gorup of Paleo Bayview regarding well Sample~ Lab, Receipt icknowledgment' {eturn Receipt RCO Alaska, Inc. Extension Exploration :~,ias~:~.~ Oii& ~:~s Cons. C0mmissi0~ PoO. Box 100360 Processed By'-. Lucille~:Johnston ~ Anchorage, Ak. 99510 ATO-1015 x4599 : ATTN ' -- '"~-~- ARCO ALASKA, INO \_.~,j',E...~x t e n s i on Exploration TRANSMITTAL ~- C. V'. Chatterton - AOGC From- Lucille Johnston - Ext. Exploratioj ~te- . May' 14~ 1984 Transmitted herewith are the following' One Copy Each ARCO· W.S. Pilot #13:'j 6-17-83 Registered Survey Plat JW. Sak #24 ~ W. Sak #24 ~6~ ~${~]-,B, ay St#1 D.S 4-20 Lis Tape #65031- 4-12-82 Run 1,2 Open Hole " ". #423~ 4-5-82 Run 2 HDT.- kL-f-i~ ~a~e" #69125 12-16-83 '~dn 4 LSS/wf) Lis Tape #68524 9-2-83 Runs'l,2 Open Hole Listing ~~L~-Jr-~?e~ Registered Survey Plat 5-9-82 - MUDLOG 6-8,23-82 · /'On this well, please contact Teresa Gorup · Note. . fPaleo Lab, Bayview regarding well Sample~' Receipt ',ckn°wledg.ment: ~eturn Receipt Date: __ t~:/ARCO Alaska, Inc. -' - Extension Exploration PoO. Box 100360 Anchorage, Ak. 99510 .~',,iaska 0;i & E:s Cons. Commission -Processed By'-. Luclll'e';'Johnston - ATO-Z015 x~599 .----- STATE OF ALASKA ~ ALASK/. IL'ANDGAS CONSERVATION C /1MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL[] 2. Name of Operator ARCO ALASKA, INC. 3. Address 700 G STREET, ANCHORAGE, AK 4. Location of Well 400' FNL, 750' FWL SEC 22 - TllN - R15E, 5. Elevation in feet (indicate KB, DF, etc.) 60=5' KB COMPLETED WELL 99510 6. Lease Designation and Serial No. OTHER [] 7. Permit No. 83-143 8. APl Number s0- 0292101900 9. Unit or Lease Name SOUTH BAY STATE 10. Well Number ] 11. Field and Pool LISBURNE 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] 'Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] [] Abandonment [] [] Other 2~ [] 60 Day Well Test (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). Reference is made to an earlier sundry dated March 28,1984, giving the Commission noti- fication that a small percentage of hydrogen sulfide gas had been detected in the production from the subject well. Since this well began producing on March 23,1984, it has-been continually monitored and lab tested for the H?S content. The content has remained constant at 7~ppm:H~S. A 10 ppm H2S threshold limit set by the Occupational Safety and Health AdminiStration (OHSA) is normally accepted by ARCO Alaska, Inc. as an amount necessary to implement the attached "minimum safety and loss prevention provisions". ARCO Alaska, Inc. by this sundry, hereby notifies the Commission that we will cease to operate the subject well under the attached minimum safety and loss prevention provisio~ We will continue to produce subject well for the duration of the 60 day test and will continue to monitor the H2S content. If the H_S content should rise and remain above z an acceptable safe limit, we will Once again i~plement the attached provisions. RECEIVED APR 2 0 14. , hereby certify that the fore,going, is tr~or~,1 ~ ~"'~~~ my knowledge. '''"' ~1,-- o0- ~ ................... ~--~¢ Signed J. S. Dayton /~ ~ ~~ Title_R~¢inn2] ~gi~¢¢r Anc~ge The space below for Commissio~e / Date ~, Co.d,tio.s o. A.prov...,. . /'7 By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1 ~0 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate n~nut~=rw ~ut. r lut t~KUUU~;1 IUN AND DRILLING OPERATIONS MINIMUM SAF~Y A~ LOSS PR~E~IO~ PROVI~O~ . Foll~(ng is a checklist of (terns ~(ch ~st be addressed ~en planning for hydrogen exposure. These it~= should be. cons(dared minimums and should be exceeded ,~hen applicable. Hore detail is addressed in Texas ARC Rule )6, adopted by ARCO 0(1 and Gas C~pany es ~e binding standard c~pany-w(de. A. Radiu~ of Ex=o~ure*-Jdent(fJcetJon 1. ~lculeted fr~ H~S source using'dispersion equations (re: Rule 36) 2. For unkn~n sourc~ levels - 3000 feet red(u~ is mi ~posure area is to be plotted~ ell ingress and egress route= (dent(lied and inhabited facflJtie~ (dentil(ed within the bounder(es q. All ing'ress routes ere to have signs posted, clearly visible, restricting access to only authort zed personnel. 5. Per(meter boundaries will have hydrogen sulfide warn(rig ~(gns mt appropriate well as wind direction markers at strateg(c locations. Wind directional mmrkers w(ll be located such that m person ~s in visual contect at all times ~en leev~n~ ~e lo- cat(on. C. Authorized Personnel Access-Training Requi resents 1. All personnel having regular access to the exposure area will be required to attend training and briefing sessions prior to access. 2. As a minimum, handling will encompass: a. Effects of H?S; symptoms of exposure; identifications of exposure source b. Hands on tralning, and proof of performance, with breathing air equipment c. Briefing on fixed monitoring; personnel r.,onitorin.m equipment to be use~; alarm i nterpretati OhS d. Evacuation procedures; process safety equipment (STV, etc.) e.' lechniques of "buddy system" emergency response/rescue f. A post-test will be given and kept on file · 3. Short term access to unauthorized employees (i.e., short term maintenance, etc.) will be allowed only in the accompaniment of an authorized person. Vehicul ar Access-Procedures All vehicles will be parked at the facility such that they may be used for immediate emeroency e_mress (i.e., headed out configuration; keys left in ignition} Fres~ air e~quipment being carried in each vehicle will be placed in the front seat for immediate access during emergency situations All personnel entering the location must be "authorized" and have had documented train- ' ing as specified in B above. E. Conti n.oenc¥ P1 anning 1. An emergency contingency plan will be charted before any operations take place; as a minimum, this plan will include: a. Evacuation exposur.e levels, alarm interpretation, shut-in procedures, personnel response Definition of personnel briefing area during evacuation (headcount purposes) -c. Radio, telephone call list with emergency response units; local authorities Evacuations of adjacent facilities within exposure are~. e. Intracompany location management contacts f. ~ress routes Moni torino Eouipment and Breathino Air Eoui~ment 1. Fixed monitors ~11 be maintained and tested d~ily; calibration frequency based on manufacturer's specification 2. Personnel monitors ~ill be worn by authorized personnel ~uch ~at ~in~ul~r personnel will wear one at all times; group~ will have one ~orn by one member Fixed'monitor~ ~ill have both visual and audible al~rm~ with the high level alarm set no higher than 50 ppm 4. Personnel monitors will be ~et ~t no greater ~an 20 ppm for low level =;=re, mhd no greater than 50 ppm high level al=re (for dual ~la~ models) 5. All monitoring equipment ~11 be selected from preapproved purchasin~ ~uidelines and will be selected based on constraints to temperature extremes Breathing air equipment (NIOSH approved) will be available such that all exposed per- sonnel will h~ve readily accessible units Documentati on 1. A central file will be maintained at the production location central safety group; v~ith a duplicate copy at Anchorage Safety. Documentation will include: a.- Contingency pl an b. l~a'inino lo.~s; including names of attendees and copies of post tests c. Monitoring equipment calibration schedule and tests log d. Emergency drill reports · e. Any other documentation regardin.o formalized safety activities STATE OF ALASKA ALASK .)ILAND GAS CONSERVATION ~. MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRIL.LING WELL [] 2. Name of Operator ARCO ALASKA, INC, 3. Address 700 G STREET, ANCHORAGE, AK COMPLETED WELL [] r. llN[lfll:alTl f t 99510 4. Location of Well 400' FNL, 750' FNL SEC 22 - TllN - R15E, UM 5. Elevation in feet {indicate KB, DF, etc.) 60.5' KB 6. Lease Designation and Serial No. 12. 7. Permit No. OTHER [] 83-143 8. APl Number 50- 0292101900 9, Unit or Lease Name SOUTH BAY STATE 10. Well Number 11. Field and Pool L ISBURNE Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing SUBSEQUENT REPORT OF: ~:~ (Submit in Duplicate) ~'- [] Altering Casing [] [] Abandonment [] [] Other [] [] 60 DAY WELL TEST (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). Please consider this Sundry as formal notification that a very small percentage (less than 10 ppm) of Hydrogen Sulfide gas has been detected in the production from the subject well. Although initial DST's indicated no H?S gas, the wellbore equipment and surface facilities were designed to withstand H_S. ARCO-Alaska, Inc. also implemented the attached "MinimumI Safety and Loss Prevention rrov~slons prior to initiating an approved 60 day well test. After receiving the necessary approval and implementin'g the safety provisions, the subjsct well was started up for a 60 day flow test at 1815 hrs on 3-23-84 with an initial rate of , 2400 BOPD and 750 GOR and no H~S. After several days of testing a very small concentration of H2S (0-3 ppm) was detected,z The well test will continue for 60 days under the attached, provisions, i The attached company policy conforms to the Railroad Commission of Texas Oil and Gas Division 05~.02.02.036 Rule 36. Oil, Gas or Geothermal Resource Operation in Hydrogen Sulfide Areas and the American Petroleum Institute RP55, Recommended Practices for Conducting Oil and Gas Production Operations Involving HydrOgen Sulfide, also attached. These safety provisions were closely adhered to and proved to be very effective during the Pingut State #1 60 day well test which was recently terminated. 14. I hereby certify that the~. ,~ ~~f°reg°ing is true and correct to the best of my knowledge. Signed J. S. Dayton --.-- -_ , __ Title R~.g i ~n~ I Fng i n~.~.r The space below for Commiss~ use Conditions of Approval, if an~,;,,I Approved by Date 'By Order of COMMISSIONER the Commission Date __ Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ~DROCEN SULF I DE PRODUCT I ON A~ DR ! LL ! NC* OPERAT IONS ' ~NIMUH SAFETy AND LOSS PR~EN~ION PRO~ONS (Ref: ARCO Oil and Gas C~pany Poli~ .- Foll~ing is a checklist of (terns ~ich must be addressed ~en planning for hydrogen sulfide exposure. These items should be. cons(dared m~n(mums and should be exceeded when applicable, Hore detail is addressed in Texas RRC Rule )6~ adopted by ARCO 0(1 and Gas C~pany es the binding standard company-wi de. A. Radius of Exposure~-ident(f(cation , 1. ~lculated from H.S source using dispersion equations (re: Rule 2, For unknown sourc~ levels - )000 feet radius is minimum 3. ~posure area is to be plotted~ all ingress and egress routes identified and inhab(t~ facilities identified within the boundaries q.AI) ingress routes are to have signs posted~ clearly v(sible~ restricting access only author(zed personnel, 5, Per(meter boundaries will have hydrogen sulfide warning signs at appropriate points well as wind direction markers at strategic locations. Wind directional markers will be located such that a person (s(n visual contact at all t(mes ~en leaving the lo- ca t( on. Authorized Personnel Access-Trai ning Requi rements 1. All personnel having regular access to the exposure area will be required to attend training and briefing sessions prior to access. 2. As a minimum, handling will encompass: a. Effects of H_S; symptoms of exposure; identifications of exposure source b. Hands on training, and proof of performance, with breathing air equipment c. Briefing on fixed monitoring; personnel monitoring equipment to be used; alarm interpretations d. Evacuation procedures; process safety equipment (STV, etc.) e; Techniques of "buddy system" emergency response/rescue f. A post-test will be given and kept on file . 3. Short term access to unauthorized employees (i.e., short term maintenance, etc.) will be allowed only in the accompaniment of an authorized person. Vehicular Access-Procedures 1. All vehicles will be parked at the facility such that they may be used for immediate emergency egress {i.e., headed out configuration; keys left in ignition} 2. Fresh air Equipment being carried in each vehicle will be placed in the front seat for immediate access during emergency situations 3. All personnel entering the location must be "authorized" and have had documented train- ing aS specified in B above. Contin?ency Plannin9 1. An emergency contingency plan will be charted before any operations take place; as a minimum, this plan will include: a. Evacuation exposure levels, alarm interpretation, shut-in procedures, personnel b. response Definition of personnel briefing area during evacuation (headcount purposes) Radio, telephone call list with emergency response units; local authorities Evacuations of adjacent facilities within exposure area. Intracompany 1 ocation management contacts Egress routes E, F. Honitorino Equipment and Breathino Air Eauipment Fixed monitors will be maintained and tested daily; calibration frequency based on manufacturer's specification 2. Personnel monitors will be worn by authorized personnel such that singular personnel will wear one at all times; groups will have one worn by one member Fixed monitors will have both visual and audible alarms with the high level alarm set no higher than $0 ppm Personnel monitors will be set at no greater ~%an 20 ppm for low level alarm, and no greater than 50 ppm high level alarm (for dual alarm models) $. All monitoring equipment will be selected from preapproved purchasing guidelines and will be selected based on constraints to temperature extremes G. Breathing air equipment {NIOSH approved) will be available such that all exposed per- sonnel will have readily accessible units Documentation 1. A central file will be maintained at the production location central safety group; with a duplicate copy at Anchorage Safety. Documentation ~ill include: a. Contingency pl an b. Tra'ining logs; including names of attendees and copies of post tests c. Honitoring equipment calibration schedule and tests log d. Emergency drill reports · e. Any other documentation regarding formalized safety activities ~ ? ~ .. ~. STATE OF ALASKA ; ALASKA~ ",LANDGAS CONSERVATION C 'IMISSlON MONTHLY R :RORT OF I RILLINO ANI WORKOVER 1. Drilling well [~X Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 83-143 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21019 9. Unit or Lease Name Prudhoe Bay Un.it/Lisburne 4. Location of Well atsurface 4007 FNL, 750' FWL, Sec.22, T11N, R15E, UN CONFIDENTIAL 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RKB 61' ADL 28322 10. Well No. South Bay State #1 11. Field and Pool PrudhoeBay Fiel d/Lisburne Lisburne Oil Pool For the Month of. February ,19 84 ;12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks -' ~ Spudded well ~ 1030 hfs, 10/04/83. Drld 17-1/2" hole to 3800'. Ran, cmted & tested 13-3/8" csg w/FS ~ 3781'. Drld 12-1/2" hole to 8330'. Ran, cmted & tested 11-3/4" lnr. Cored f/8344' - 8713'. Drld 8-1/2" hole f/8713' - 8844'. Ream hole to 12-1/4" f/6480' - 8844'. Ran, crated & tstd 9-5/8" csg. Cored f/8847' - 9477'. RIH w/8-1/2" bit. Drl f/9477' - 9819'. Cored f/9819' - 9954'. Ran logs. Perform DST #1. Drl f/9954' - 9973'. OH logs. Plug back hole to 9666'. Perform DST #2. Run liner. (continued on attached sheet) 13. Casing or liner run and quantities of cement, results of pressure tests 20", 91.5#/ft, H-40 weld conductor set ~ 81'. Instd w/1910# poleset. 13-3/8", 72#/ft, L-80 BTC csg w/FS @ 3781'. Cmtd w/2400 sxs "Fondu" + 400 sxs PF "C". 11-3/4", 60#/ft, S-95 Hydril csg f/1636' - 6480'. Cmtd w/500 sxs "G" cmt +-50 bbl PF "C". 9-5/8", 47#/ft, S-95 hydril + L-80 BTC csg w/FS @ 8836'. Cmtd w/550 sxs "G" cmt. 7", 29#/ft, L-80 BTC csg f/8543' - 9700'. Cmtd w/175 sxs "G" cmt. 14. Coring resume and brief description Core #1 f/8344' - 8371'. Recovered 27'. Core #2 f/8371' - 8379'. Recovered 4'. Core #3 f/8379' - 8391'. Recovered 12'. Core #4 f/8391' - 8416'. Recovered 25'. Core #5 f/8416' - 8447'. Recovered 31'. (continued on attached sheet) 15. Logs run and depth where run Log #1 - Borehole Televiewer f/9954' - 8836'. Log #2 - FDC/CNL/Cal/GR f/9954' - 8836'. DIL/BHCS/GR f/9965' - 8830'. LDT/CNL/NGT/GR/Cal f/9973' - 8830'. LSS/GR f/9965' - 8830'. (continued on attached sheet) 1 o. DST data, perforating data, shows of H2S, miscellaneous data DST #1 f/9954' - 9750', open hole test. DST #2 f/9666' - 9450', open hole test. DST #3 f/9652' - 9486', perf w/4 spf f/9566' - 9516'. DST #4 f/9210' - 9440', perf w/4 spf f/9241' - 9270'. DST #5 f/9058' - 9200', perf w/4 spf f/9086' - 9150'. (continued on attached sheet) 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. .~~_.~_~ ~..~~ ~c Area Drill~'ng Eng,'neet .... NOT~--R~ort on/~ this f~ is required for each calendar month, regardless of the status of operations, and must I~ flied in duplicate with the Alaska ~ifand ~as Conserv~n Commission by the 15th of the succeeding month, unless otherwise directed. Form 10~04 DRN/MR71 Submit in duplicate MONTHLY REPORT (cont'd) South Bay State #1 12.) CO cmt to PBTD @ 9652'. Run CBL. Perform DST #3. Sqz perfs f/9516' - 9566'. CO cmt to 9440' PBTD. Perform DST #4. Sqzd perfs. CO cmt to 9225'. Spot 75 sxs "G" cmt @ 9225'. CO cmt to 9200' (PBTD). Perform DST #5. Wiper trip. Log w/csg caliper. Arctic pack 13-3/8" x 11-3/4" annulus. Run 4-1/2" tbg string. ND BOPE. NU tree. Secured well. RR ~ 1500 hfs, 01/10/84. SEE DRILLING HISTORY 14.) Core #6 f/8447' - 8456'. Pressure core recovery not available. Core #7 f/8456' - 8465'. Pressure core recovery not available. Core #8 f/8465' - 8474'. Pressure core recovery not available. Core #9 f/8474' - 8481'. Pressure core recovery not availble. Core #10 f/8481' - 8538'. Recovered 56'. Core #11 f/8538' - 8576'. Recovered 38'. Core #12 f/8576' - 8585'. Pressure core recovery not available. Core #13 f/8585' - 8594'. Pressure core recovery not available. Core #14 f/8594' - 8618'. Recovered 24'. Core #15 f/8618' - 8626'. Pressure core recovery not available. Core #16 f/8626' - 8635'. Pressure core recovery not available. Core #17 f/8635' - 8644'. Pressure core recovery not available. Core #18 f/8644' - 8653'. Pressure core recovery not available. Core #19 f/8653' - 8713'. Recovered 58'. LISBURNE CORES: Core #1 f/8847' - 8907'. Core #2 f/8907' - 8967 . Core #3 f/8967' - 9015 . Core #4 f/9015 - 9076 . Core #5 f/9076 - 9136 . Core #6 f/9136 - 9196 . Core #7 f/9196 - 9242 . Core #8 f/9242 - 9299 . Core #9 f/9299 - 9359 . Recovery not available. Recovered 60'. Recovered 48-1/2'. Recovered 61 . Recovered 60 . Recovered 45 . Recovered 55 . Recovered 57 . Recovered 60 . Core #10 f/9359' - 9419'. Recovered 60 . Core #11 f/9419' - 9477'. Recovered 58 . Core #12 f/9819' - 9879'. Recovered 60 . Core #13 f/9879' - 9939'. Recovered 60 . Core #14 f/9939' - 9954'. Recovered 15 . 15.) Dipmeter f/9973' - 8830'. · RFT f/9559' - 8868'. CBL f/9645' - 8370'. Csg caliper f/8520' - surface. CCL/GR f/9200' - 8700'. HP/Temp/Spinner/Gradio/GR/CCL f/9200' - surface. GR/CCL f/9078 - 8990'. HP/Temp/GR/CCL f/9145' - surface. GR/CCL f/8969' - surface. GR/Temp f/8969 - surface. HP/Temp/ f/9033' - surface. Spinner/Temp/HP/Gradio/GR/CCL f/9023' - surface. GR/CCL/Sinker Bars f/9051' - surface. GR/CCL/Sinker Bars f/9126' - surface. MONTHLY REPORT (cont'd) South Bay State #1 16.) Perf f/9026' - 9062' w/4 spf. Perf w/8936' - 8918' w/4 spf. Perf f/8900' - 8918' w/4 spf. Perf f/8900' - 8882' w/4 spf. Perf w/8858' - 8872' w/4 spf. DRN/MR71a:tw SOUTH BAY STATE #1 DRILLING HISTORY CONFIDENTIAL. NU hydril and diverter system. Spudded well @ 1030 hrs, 10/04/83. Drld 17-1/2" hole to 3800'.. Ran 94 jts 13-3/8" 72#/ft, w/FS @ 3781'. Cmtd 13-3/8" csg w/2400 sxs Fondu + 400 sxs PF "C". ND 20" diverter system. Installed 13-3/8" packoffs & tested to 2000 psi - ok. NU BOPE & tested to 5000 psi - ok. Tested csg to 1500 psi - ok. Drld FC + cmt. Drld FS & 10' of new form Tested form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 8330'. Underream 1~-1/4" hole to 13-1/2" f/3781' - 8330'. Ran 119 jts of 11-3/4" 60#/ft lnr f/6480' - 1636'. Cmted 11-3/4" lnr w/500 sxs "G" cmt. Sqz lnr lap w/200 sxs PF "C" cmt. Drl cmt f/1630' - 1646'. Drl cmt f/1630' - 1646' Drl cmt f/6226' - 6480'. TIH to 8330' Drl 10' new hole. Form leak-~ff test. RIH w/coring assy. Cut core #1Y/8344' - 8371'. Recovered 27'. Redress core barrel. RIH. Cut core #2 f/8371' - 8379'. Recovered 4'. RIH & cut core #3 f/8379' - 8391'. Recovered 12'. RIH & cut core #4 f/8391' - 8416'. Recovered 25' RIH & cut core #5 f/8416' - ~7~ Recovered 31' RIH & cut core $6 f/8447' - 8456'. RIH & cut c UI-~ ~/ f/8456' - 846~'. Ream 6-1/2" hole to 8-1/2" f/8447' - 8465'. Cut core #8 f/8465' - 8474' RIH & cut core #9 f/8474' - 8481'. RIH & ream 6-1/2" hole to 8-1/2" f/84~5' - 8481'. POOH. RIH & cut core #10 f/8481' - 8538'. Recovered 56'. RIH & cut core #11 f/8538' - 8576'. Recovered 38'. RIH & cut core #12 f/8576' - 8585'. RIH & cut core #13 f/8585' - 8594'. RIH & ream 6-1/2" hole to 8-1/2" f/8576' - 8594'. Circ + cond hole. POOH. RIH. Wash & ream f/8569' - 8594'. Cut core #14 f/8594' - 8618'. Recovered 24'. RIH & cut core #15 f/8618' - 8626'. RIH & cut core #16 f/8626' - 8635'. RIH w/8-1/2" bit & ream f/8618' - 8635'. CBU. POOH. RIH & cut core #17 f/8635' - 8644'. Cut core #18 f/8644' - 8653'. TIH w/8-1/2" bit & ream 6-1/2" hole to 8-1/2" f/8635' - 8653'. Cut core #19 f/8653' - 8713'. Recovered 58'. TIH w/8-1/2" bit & drld f/8713' - 8844' Circ. POOH. RIH w/9-7/8" bit & ream 8-1/2" hole to 9-7/8" f/8340' - ~428'. CIRC. Ream f/8428' - 8621' POOH. Underream hole w/12-1/4" underreamer f/6480' - 8844'. POOH. R~H & re-ream f/6480' - 8844'. POOH. RU & run 207 jts of 9-5/8" csg w/FS @ 8836'. Cmted csg w/550 sxs "G" cmt. Land csg. Test pack-offs to 3000 psi. RIH w/8,1/2" bit. Tag top of cmt @ 8742'. Test csg to 3000 psi. Drl FC & cmt to FS @ 8836'. CO to 8844'. Drld f/8844' - 8847'. Form leak-off test to 13.1 ppg. Clean mud pits f/chng to oil-faze system. Displ well f/bland mud to oil-faze. TIH w/core bbl #1. Survey. Cut core #1 f/8847' - 8907'. CBU. TOH. Recover core #1. TIH & cut core #2 f/8907' - 8967' POOH. Recovered 60' TIH w/core #3. Cut core #3 f/8967' - 9015' T~H w/core #3. Recovered' 48-1/2'. TIH w/core barrel #4. Core f/9015' - ~076' POOH. Recovered 61' RIH w/core #5. Core f/9076' - 9136 POOH. Recoiered 60'. RIH w/core' '. #6. Cut core f/9136' - 9196'. POOH. Recovered 45 . RIH w/core #7. Cut core #7 f/9196' - 9242'. POOH w/core #7. Recovered 55', (15' of which was recovered f/core #6). RIH --w/core #8. Cut core f/9242' - 9299' CBU. POOH. Recovered 57'. RIH w/core #9. Cut core #9 f/9299' - 9359". CBU. POOH. Recovered 60'. RIH w/core #10. Cut core #10 f/9359' - 9419'. CBU. POOH. Recovered 60' RIH w/core #11 f/9419' - 9477'. CBU. POOH. Recovered 58' f/core #11. RIH w/8-1/2" bit. Drl f/9477' - 9819'. CBU. POOH. RIH w/Core #12. Cut core f/9819' - 9879' CBU. POOH. ~IH w/core bbl #13. Cut Core #13 f/987~.~. 9939'. CBU. PO~H. Recovered 60 . RIH w/core bbl #14. Core f/9939' -!~'~i South Bay State #1 Drilling History (cont'd) 9954' BBL jammed. POOH w/Core #14. Recover core. TIH w/8-1/2" bit. Circ ~ cond. POOH. Ran log #1, "Borehole Televiewer" f/9954' - 8836'. Ran log #2, FDC/CNL/Cal/GR f/9954' - 8836' RD loggers. TIH w/8-1/2" bit. Circ & cond. mud @ TD. POOH. PU DST tools. TIH. Perform DST #1 f/9954' - 9750'. POOH w/DST tools. RIH w/8-1/2" bit. Drl f/9954' - 9973'. CBU. POOH. Log w/DIL/BHCS/GR. Chng tools. Log w/LDT/CNL/NGT/GR/Cal. Chng tools. Log w/LSS/GR. Chng tools. Log w/Dipmeter. Chng tools. Log w/RFT. Conditioning trip. RIH w/3-1/2" DP. Plug back hole w/125 sxs Class "G" cmt. RIH w/8-1/2" bit & CO to 9666'. CBU. POOH. PU DST #2 tools + RIH. Test BOPE. Perform DST #2. POOH. PU 8-1/2" bit + RIH. Drl cmt f/9666' - 9700' PBTD. Circ & cond. POOH. RIH w/liner. Liner set f/8543' - 9700'. Cmtd inr w/175 sxs "G" cmt. Co cmt to top of lnr @ 8543'. CO cmt to PBTD @ 9652' Test csg. TOH. Run CBL f/9645' - 8370'. RIH w/DST #3 tools. Perform DST #3 f/9652' - 9486'. TOH w/DST #3 tools. RIH w/cmt ret + set @ 9450' Sqzd 30 bbl Class "G" cmt into perfs f/9516' - 9566'. POOH. TIH w/6" ~it & CO cmt to 9440' PBTD. Test csg to 3000 psi. POOH. RIH w/DST #4 tools. Perform DST #4 f/9210' - 9440'. POOH w/DST #4 tools. RIH w/cmt ret + set @ 9225'. Sqzd perfs f/9241' - 9270', w/10.2 bbl Class"G" cmt. CO cmt to cmt ret @ 9225'. Test csg. CBU. POOH. RIH w/OEDP to 9225'. Spot 75 sxs "G" cmt. CO cmt to 9200' PBTD. CBU. Test csg. POOH. PU__ DST #5 tools + RIH. Perform DST #5, f/9058' - 9200'. POOH w/DST #5 tools. TIH w/6" bit & 7" csg scpr. CBU. POOH. LDDP. Run csg caliper log f/8520' - surface. Perform Arctic pack downsqueeze in 13-3/8" x 11-3/4" annulus w/50 bbl Permafrost "C" + 103 bbl A.P. Ran 4-1/2" tbg string w/tail @ 8806', pkr @ 8753' ND BOPE. NU tree. Test same. Secure well. RR @ 15~O.._O~_h.r~_s_, . 0~1/10_/~4', Move rig off location. Move in + rig up NOWSCO.-Test coil tbg + BOPE to 4000 psi. TIH w/1-1/4" coil tbg to PBTD. Displ well w/180 bbl diesel @ I bbl/min. TOH w/coiled tbg. MIRU SOS. Test BOPE + lubricator to 3500 psi. Run GR/CCL f/9200' - 8700' Perf f/9026' - 9062' w/4 spf. TOH. RD SOS. MIRU coiled tbg unit + HOWCO'. RIH w/coil tbg to 9200' Spot acid f/9200' - 9026'. PU + bullhead acid into perfs f/9150' - 9086" + 9062' - 9026'. Pumped total of 100 bbl 15% HCL. SI well. Flow well. RU SOS. Test WL BOP to 4500 psi, lubricator to 4000 psi. RIH w/HP/Temp/Spinner/Gradio/GR/CCL. Monitor BHFP. SI well. Monitor pressure build-up. TOH w/PLT tools. RD SOS. MIRU HOWCO frac equipment. Pressure test all lines to 5000 'psi. Pump 150 bbl gelled diesel followed by 200 - 7/8" RCN balls, 1.25 SP GR. Continue pumping + pump 240 bbl gelled diesel. SI well. Flow well f/lO min. SI well. Test lines to 5000 psi. Open well. Put 1000 psi on annulus. Frac well w/20,O00# 100 mesh sand, 112,000# 20/40 mesh sand, 1496 bbl gelled diesel + 94 bbl diesel flush. Average pump in rate of _+32-1/2 bbl/min, @ 2400 - 2800 psi. Observe pressure. SI + secure well. RD HOWCO frac equipment. Test lines to 4000 psi. MIRU SOS. Test BOPE to 3500 psi. Ran GR/CCL log f/9078' - 8990' POH. RD SOS. Flowing well. MIRU SOS. Test BOPE. RIH w/HP/Temp/GR/CCI' log to 9145' SI well. Record pressure build-up. POOH w/logs stopping @ various inter~als. Chng out tools. RIH w/perf gun + perf f/8936' - 8918', w/4 spf. POH. Chng out tools. RIH w/perf gun #2 + perf f/8900' - 8918' w/4 spf. POH. RIH w/perf gun #3 + perf f/8900' - 8882' w/4 spf. POH. Flow well. RIH w/perf gu~ #4 South Bay State #1 Drilling History (cont'd) + perf f/8858' -8872' w/4 spf. POH. Flow well. SI well. Began pumping 136 bbl total of diesel w/35 sxs 12-20 mesh sand. Followed by 2 sxs of 100 mesh sand as cap. RU SOS. RIH w/GR/CCL. Tag top of sand @ ~8969'. POH. RU HOWCO. Test lines to 4500 psi. Begin pumping @ 1.0 BPM. Shut down. RD HOWCO. RU coil tbg unit. Test lines. RIH w/coil tbg to 8940' Pump 70 bbl 15% HCL followed by 15 bbl diesel @ .84 bbl/min @ 3800 psi. ~OH w/coil tbg. RU HOWCO. Pump 140 bbl diesel @ 6.6 bbl/min @ 2000 psi. SI well. RIH w/GR/Temp log to 8969'. POH. SI well. F1 ow well. SI well. RIH w/HP/Temp log to 9033'. PU to 8838'. Monitor pressure build-up. POOH w/HP/Temp logs stopping @ various intervals. RD SOS. Flow well. RU SOS. RIH w/Spinner/Temp/HP/Gradio/GR/CCL log to 9023' Flow well. PU to 8848' w/survey tools. Shut in well. POOH w/survey toois. RD SOS. Well shut in. MIRU coil tbg. Test BOPs to 3900 psi. RIH w/coil tbg. Open well to flow. Begin pumping N+2 @ 350 SCFM, increase to 600 SCFM. Increased nitrogen rate to 1200 SCFM 2000 SCFM. Continue flowing well. POOH w/coil tbg. Shut in well. MIRU Camco. Test BOPE to 2500 psi. RIH w/GR/CCL/Sinker Bars. Tag BTM @ 9051' POOH. Flow well. RIH w/Sinker Bars/CCL. Tag BTM @ 9126' Flow wel'l. Shut in well. RD Camco "F" line unit. MIRU Camco "Slic~" line unit. Test BOPs to 3000 psi. RIH. Set Camco 2.5 CA.blanking plug in "D" nipple @ 8796'. Test plug. Secure well, as of 02/29/84. DRN/DH63'tw ' · . ~.. STATE OF ALASKA ~ ALASK~ "ILAND GAS CONSERVATION C ~MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIO 1. Drilling welex~ REV IS ION Workover operation [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well atsurface 400t FNL, 750' FWL, Sec.22, T11N, ELSE, UH CONFIDENTIAL 5. Elevation in feet (indicate KB, DF, etc.)' I 6. Lease Designation and Serial No. RKB 61' J ADL 28322 For the Month of. January ,1984 7. Permit No. 83-143 8. APl Number 50-- 029-21019 9. Unit or Lease Name Prudhoe Bay Unit/Lisburne 10. Well No. South Bay State #1 11. Field and Pool PrudhoeBay Fi eld/Lisburne Lisburne 0il Pool ,! 2. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks , Spudded well ~ 1030 hrs, 10/04/83. Drld 17-1/2" hole to 3800'. Ran, cmted & tested 13-3/8"-csg w/FS ~ 3781'. Drld 12-1/2" hole to 8330'. Ran, cmted & tested 11-3/4" lnr. Cored f/8344' - 8713'. Drld 8-1/2" hole f/8713' - 8844'. Ream hole to 12-1/4" f/6480' - 8844'. Ran, cmted & tstd 9-5/8" csg. Cored f/8847' - 9477'. RIH w/8-1/2" bit. Drl f/9477' - 9819'. Cored f/9819' - 9954'. Ran logs. Perform DST #1. Drl f/9954' - 9973'. OH logs. Plug back hole to 9666'. Pjrform DST #2. Run liner.(continued on attached sheet) 13. Casing or liner run and quantities of cement, results of pressure tests 20" 91 5#/ft, H-40 weld conductor set ~ 81' Instd w/1910# poleset. i13-3/8" 72#/ft L-80 BTC csg w/FS @ 3781' Cmtd w/2400 sxs "Fondu" + 400 sxs PF "C". 11-3/4" 60#/ft S-95 Hydril csg f/1636' - 6480'. Cmtd w/500 sxs "G" cmt + 50 bbl PF "C',. 9-5/8", 47#/ft, S-95 hydril + L-80 BTC csg w/FS ~ 8836'. Cmtd w/550 sxs "G" cmt. 7" 29#/ft L-80 BTC csg f/8543' - 9700'. Cmtd w/175 sxs "G" cmt. 14. Coring resume and brief description Core #1 f/8344' - 8371'. Recovered 27'. Core #2 f/8371' - 8379'. Recovered 4'. Core #3 f/8379' - 8391'. Recovered 12'. Core #4 f/8391' - 8416'. Recovered 25'. Core #5 f/8416' - 8447'. Recovered 31'. (continued on attached sheet) 15. Logs run and depth where run Log #1 - Borehole Televiewer f/9954' - 8836'. Log #2 - FDC/CNL/Cal/GR f/9954' - 8836'. DIL/BHCS/GR f/9965' - 8830'. LDT/CNL/NGT/GR/Cal f/9973' - 8830'. (continued on attached sheet) LSS/GR f/9965' - 8830'. 16. DST data, perforating data, shows of H2S, miscellaneous data DST #1 f/9954' - 9750', open hole test. ' DST #2 f/9666' - 9450', open hole test. DST #3 f/9652' - 9486', perf w/4 spf f/9566' - 9516'. DST #4 f/9210' - 9440', perf w/4 spf f~9241' - 9270'. DST #5 f/9058' - 9200', perf w/~ spf'f/9086' - 9150'. Perf f/9026' - 9062'. Oil ~ G~s Oor, s. o0mmissi0n 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. c~ Ar-ea Dril ling Engineer SIGNED ITLE DATE - ~ N~--R~o, this form/is~quired for each calendar month, regardless of the status of operations, and must/be fileotin duplicate with the Alaska Oil and ~as Conservatio~mmission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 DRN/HR7 0 Submit in duplicate MONTHLY REPORT (cont'd) South Bay State #1 12.) CO cmt to PBTD ~ 9652'. Run CBL. Perform DST #3. Sqz perfs f/9516' - 9566'. CO cmt to 9440' PBTD. Perform DST #4. Sqzd perfs. CO cmt to 9225'. Spot 75 sxs "G" cmt ~ 9225'. CO cmt to 9200' (PBTD). Perform DST #5. Wiper trip. Log w/csg caliper. Arctic pack 13-3/8" x 11-3/4" annulus. Run 4-1/2" tbg string. ND BOPE. NU tree. Secured well. RR ~ 1500 hrs, 01/10/84. SEE DRILLING HISTORY 14.) Core #6 f/8447' - 8456'. Pressure core recovery not available. Core #7 f/8456' - 8465'. Pressure core recovery not available. Core #8 f/8465' - 8474'. Pressure core recovery not available. Core #9 f/8474' - 8481'. Pressure core recovery not availble. Core #10 f/8481' - 8538'. Recovered 56'. Core #11 f/8538' - 8576'. Recovered 38'. Core #12 f/8576' - 8585'. Pressure core recovery not available. Core #13 f/8585' - 8594'. Pressure core recovery not available. Core #14 f/8594' - 8618'. Recovered 24'. Core #15 f/8618' - 8626'. Pressure core recovery not available. Core #16 f/8626' - 8635'. Pressure core recovery not available. Core #17 f/8635' - 8644'. Pressure core recovery not available. Core #18 f/8644' - 8653', Pressure core recovery not available. Core #19 f/8653' - 8713'. Recovered 58'. LISBURNE CORES: Core #1 f/8847' - 8907'. Core #2 f/8907' - 8967'. Core #3 f/8967' - 9015'. Core #4 f/9015' - 9076'. Core #5 f/9076' - 9136'. Core #6 f/9136' - 9196'. Core #7 f/9196' - 9242'. Core #8 f/9242' - 9299'. Core #9 f/9299' - 9359'. Recovery not available. Recovered 60'. Recovered 48-1/2'. Recovered 61 . Recovered 60 . Recovered 45 . Recovered 55 . Recovered 57 . Recovered 60 . Core #10 f/9359' - 9419'. Recovered 60 . Core #11 f/9419' - 9477'. Recovered 58 . Core #12 f/9819' - 9879'. Recovered 60 . Core #13 f/9879' - 9939'. Recovered 60 . Core #14 f/9939' - 9954'. Recovered 15 . 15.) Dipmeter f/9973' - 8830'. , RFT f/9559' - 8868'. CBL f/9645' - 8370'. Csg caliper f/8520' - surface. CCL/GR f/9200' - 8700'. HP/Temp/Spinner/Gradio/GR/CCL f/9200' - surface. DRN/MR7Oa:tw SOUTH BAY STATE #1 DRILLING HISTORY CONFIDENTIAL NU hydril and diverter system. Spudded well @ 1030 hrs, 10/04/83. Drld 17-1/2" hole to 3800'. Ran 94 jts 13-3/8" 72#/ft, w/FS @ 3781'. Cmtd 13-3/8" csg w/2400 sxs Fondu + 400 sxs PF "C". ND 20" diverter system. Installed 13-3/8" packoffs & tested to 2000 psi - ok. NU BOPE & tested to 5000 psi - ok. Tested csg to 1500 psi - ok. Drld FC + cmt. Drld FS & 10' of new form. Tested form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 8330'. Underream 12-1/4" hole to 13-1/2" f/3781' -8330'Ran 119 jts of 11-3/4" 60#/ft lnr f/6480' - 1636'. Cmted 11-3/4" lnr w/~O0 sxs "G" cmt. Sqz lnr lap w/200 sxs PF "C" cmt. Drl cmt f/1630' - 1646'. Drl cmt f/1630' - 1646'. Drl cmt f/6226' - 6480'. TIH to 8330' Drl 10' new hole. Form leak-off test. RIH w/coring assy. Cut core #1 'f/8344' -8371'. Recovered 27'. Redress core barrel. RIH. Cut core #2 f/8371' - 8379'. Recovered 4'. RIH & cut core #3 f/8379' - 8391'. Recovered 12' RIH & cut core #4 f/8391' - 8416'. Recovered 25'. RIH & cut core #'5 f/8416' - 8447' Recovered 31'. RIH & cut core #6 f/8447' - 8456'. RIH & cut core f/8456' - 8465'. Ream 6-1/2" hole to 8-1/2" f/8447' - 8465'. Cut core #8 f/8465' - 8474' RIH & cut core #9 f/8474' - 8481'. RIH & ream 6-1/2" hole to 8-1/2" f/84~5' - 8481'. POOH. RIH & cut core #10 f/8481' - 8538'. Recovered 56'. RIH & cut core #11 f/8538' - 8576'. Recovered 38'. RIH & cut core #12 f/8576' - 8585'. RIH & cut core #13 f/8585' - 8594'. RIH & ream .6-1/2" hole to 8-1/2" f/8576' - 8594'. Circ + cond hole. POOH. RIH. Wash ~ ream f/8569' - 8594'. Cut core #14 f/8594' - 8618'. Recovered 24'. RIH & cut core #15 f/8618' - 8,626'. R, IH & cut core #16 f/8626' - 8635'. RIH w/8-1/2" bit & ream f/8618 - 8635 . CBU. POOH. RIH & cut core #17 f/8635' - 8644'. Cut core #18 f/8644' - 8653'. TIH w/8-1/2" bit & ream 6-1/2" hole to 8-1/2" f/8635' - 8653'. Cut core #19 f/8653' - 8713'. Recovered 58' TIH w/8-1/2" bit & drld f/8713' - 8844'. Circ. POOH. RIH w/9-7/8" bit '& ream 8-1/2" hole to 9-7/8" f/8340' - 8428'. CIRC. Ream f/8428' - 8621'. POOH. Underream hole w/12-1/4" underreamer f/6480' - 8844' POOH. RIH & re-ream f/6480' - 8844'. POOH. RU & run 207 jts of 9-5/8'~ csg w/FS @ 8836'. Cmted csg w/550 sxs "G" cmt. Land csg. Test pack-offs to 3000 psi. RIH w/8-1/2" bit. Tag top of cmt,@ 8S4r~'d. Test ,csg to 3000 psi. Drl FC & cmt to FS @ 8836'. CO to 8844 . f/8844 - 8847'. Form leak-off test to 13.1 ppg. Clean mud pits f/chng to oil-faze system. Displ well f/bland mud to oil-faze. TIH w/core bbl #1. Survey. Cut core #1 f/8847' - 8907'. CBU. TOH. Recover core #1. TIH & cut core #2 f/8907' - 8967' POOH. Recovered 60' TIH w/core #3. Cut core #3 f/8967' - 9015' T~H w/core #3. Recovered' 48-1/2'. TIH w/core barrel #4. Core f/9015' - ~076' POOH. Recovered 61'. RIH w/core #5. Core f/9076' - 9136'. POOH. RecoVered 60'. RIH w/core #6. Cut core f/9136' - 9196'. POOH. Recovered 45'. ~R~I,H w/core #7 Cut core #7 f/9196' - 9242'. POOH w/core #7. Recoveredbb- (15' of ~hich was recovered f/core #6). RIH w/core #8. Cut core f/92~2' - 9299' CBU. POOH. Recovered 57'. RIH w/core #9. Cut core #9 f/9299' - 9359". CBU. POOH. Recovered 60'. RIH w/core #10. Cut core #10 f/9359' - 9419'. CBU. POOH. Recovered 60'. RIH w/core #11 f/9419' - 9477'. CBU. POOH. Recovered 58' f/core #11. RIH w/8-1/2" bit. Drl f/9477' - 9819'. CBU. POOH. RIH w/Core #12. f/9819' - 9879' CBU. POOH. RIH w/core bbl #13. Cut Core #13 f/98;~ 9939'. CBU. PO~H. Recovered 60'. RIH w/core bbl #14. Core f/9939' - t AR 1984 Nask~ 0il & Gas Cons. Commissior South Bay State #1 Drilling Hi story (continued) 9954'. BBL jammed. POOH w/Core #14. Recover core. TIH w/8-1/2" bit. Circ & cond. POOH. Ran log #1, "Borehole Televiewer" f/9954' - 8836' Ran log #2, FDC/CNL/Cal/GR f/9954' - 8836' RD loggers. TIH w/8-1/2'" bit. Circ & cond. mud @ TD. POOH. PU DST too'ls. TIH. Perform DST #1 f/9954' - 9750'. POOH w/DST tools. RIH w/8-1/2" bit. Drl f/9954' - 9973'. CBU. POOH. Log w/DIL/BHCS/GR. Chng tools. Log w/LDT/CNL/NGT/GR/Cal. Chng tools. Log w/LSS/GR. Chng tools. Log w/Dipmeter. Chng tools. Log w/RFT. Conditioning trip. RIH w/3-1/2" DP. Plug back hole w/125 sxs Class "G" cmt. RIH w/8-1/2" bit & CO to 9666'. CBU. POOH. PU DST #2 tools + RIH. Test BOPE. Perform DST #2. POOH. PU 8-1/2" bit + RIH. Drl cmt f/9666' - 9700' PBTD Circ & cond. POOH. RIH w/liner. Liner ,set f/8543' - 9700' Cmtd inr w/1~5 sxs"G" cmt. Co cmt to top of lnr @ 8543. CO cmt to PBTD ~ 9652'. Test csg. TOH. Run CBL f/9645' - 8370' Perf w/4 spf f/9566' - 9516'. RIH w/DST #3 tools. Perform DST #3 f/96~2' - 9486'. TOH w/DST #3 tools. RIH w/cmt ret + set @ 9450'. Sqzd 30 bbl Class "G" cmt into perfs f/9516' - 9566'. POOH. TIH w/6" bit & CO cmt to 9440' PBTD. Test csg to 3000 psi. POOH. Perf w/4 spf f/9241' - 9270'. RIH w/DST #4 tools. Perform DST #4 f/9210' - 9440'. POOH w/DST #4 tools. RIH w/cmt ret + set @ 9225'. Sqzd perfs f/9241' - 9270', w/10.2 bbl Class "G" cmt. CO cmt to cmt ret @ 9225'. Test csg. CBU. POOH. RIH w/OEDP to 9225'. Spot 75 sxs "G" cmt. CO cmt to 9200' PBTD. CBU. Test csg. POOH. Perf w/4 spf w/9086' - 9150'. PU DST #5 tools + RIH. Perform DST #5, f/9058' - 9200'. POOH w/DST #5 tools. TIH w/6" bit & 7" csg scpr. CBU. POOH. LDDP. Run csg caliper log f/8520' - surface. Perform Arctic pack downsqueeze in 13-3/8" x 11-3/4" annulus w/50 bbl Permafrost "C" + 103 bbl A.P.- Ran 4-1/2" tbg string w/tail @ 8806', pkr @ 8753'. ND BOPE. NU tree. Test same. Secure well. RR @ 1500 hrs, 01/10/84. Move rig off location. Move in + rig up NOWSCO. Test coil tbg + BOPE to 4000 psi. TIH w/1-1/4" coil tbg to PBTD. Displ well w/180 bbl, diesel @ i bbl/min. TOH w/coiled tbg. MIRU SOS. Test BOPE + lubricator to 3500 psi. Run GR/CCL f/9200' - 8700'. Perf f/9026' - 9062' w/4 spf. TOH. RD SOS. MIRU coiled tbg unit + HOWCO. RIH w/coil tbg to 9200'. Spot acid f/9200' - 9026'. PU + bullhead acid into perfs f/9150' - 9086' + 9062' - 9026'. Pumped total of 100 bbl 15% HCL. SI well. Flow well. RU SOS. Test WL BOP to 4500 psi, lubricator to 4000 psi. RIH w/HP/Temp/Spinner/Gradio/GR/CCL. Monitor BHFP. SI well. Monitor pressure build-up, as of 01/31/84. DRN/DH62'tw , qAR i ¢; 1984 Ajask~ Oil & Gas Oons. Oommissior~ Anshorage South Bay State #1 Drilling History (continued) 9954' BBL jammed. POOH w/Core #14. Recover core. TIH w/8-1/2" bit. Circ ~ cond. POOH. Ran log #1, "Borehole Televiewer" f/9954' - 8836'. Ran log #2, FDC/CNL/Cal/GR f/9954' - 8836' RD loggers. TIH w/8-1/2" bit. Circ & cond. mud @ TD. POOH. PU DST tools. TIH. Perform DST #1 f/9954' - 9750'. POOH w/DST tools. RIH w/8-1/2" bit. Drl f/9954' - 9973'. CBU. POOH. Log w/DIL/BHCS/GR. Chng tools. Log w/LDT/CNL/NGT/GR/Cal. Chng tools. Log w/LSS/GR. Chng tools. Log w/Dipmeter. Chng tools. Log w/RFT. Conditioning trip. RIH w/3-1/2" DP. Plug back hole w/125 sxs Class "G" cmt. RIH w/8-1/2" bit & CO to 9666'. CBU. POOH. PU DST #2 tools + RIH. Test BOPE. Perform DST #2. POOH. PU 8-1/2" bit + RIH. Drl cmt f/9666' - 9700' PBTD. Circ & cond. POOH. RIH w/liner. Liner set f/8543' - 9700' Cmtd inr w/175 sxs "G" cmt Co cmt to top of lnr @ 8543'. CO cmt to PBTD ~ 9652'. Test csg. TOH. Run CBL f/9645' - 8370'. RIH w/DST #3 tools. Perform DST #3 f/9652' - 9486'. TOH w/DST #3 tools. RIH w/cmt ret + set @ 9450' Sqzd 30 bbl Class "G" cmt into perfs f/9516' - 9566'. POOH. TIH w/6" ~it & CO cmt to 9440' PBTD. Test csg to 3000 psi. POOH. RIH w/DST #4 tools. Perform DST #4 f/9210' - 9440'. POOH w/DST #4 tools. RIH w/cmt ret + set @ 9225'. Sqzd perfs f/9241' - 9270', w/10.2 bbl Class "G" cmt. CO cmt to cmt ret @ 9225'. Test csg. CBU. POOH. RIH w/OEDP to 9225'. Spot 75 sxs "G" cmt. CO cmt to 9200' PBTD. CBU. Test csg. POOH. PU DST #5 tools + RIH. Perform DST #5, f/9058' - 9200'. POOH w/DST #5 tools. TIH w/6" bit & 7" csg scpr. CBU. POOH. LDDP. Run csg caliper log f/8520' - surface. Perform Arctic pack downsqueeze in 13-3/8" x 11-3/4" annulus w/50 bbl Permafrost "C" + 103 bbl A.P. Ran 4-1/2" tbg string w/tail @ 8806', pkr @ 8753'. ND BOPE. NU tree. Test same. Secure well. RR @ 1500 hrs, 01/10/84. DRN/DH52- tw THE DIA-LOG COMPANY RO. BOX 1410:3, HOUSTON, TEXAS 77221 -410,3 TELEPHONE (7ID) 747-2100 RECEIVED, ARCO ALASKA, INCORPORATED SOUTH BAY STATE #1 PRUDHOE BAY FIELD NORI~{ SLOPE, ALASKA JANUARY 8, 1984 LOG #41697 FED 81984 Alaska Oil & Gas Cor~s, Commission Anchorage SUMMARY GENERAL CONDITION OF CASING The enclosed Dia-Log Casing Profile Caliper Log covers 8520' or 200 joints of 9 5/8" O.D. 47.0 #/ft. casing. The purpose of the Caliper Log is to determine the existance and extent of drill pipe wear damage to the casing. It was reported that approximately 1500' of open hole have been drilled through the casing. Inspection of the log trace finds no significant loss in wall thickness by drill pipe wear. There are 6 different joints, of the 200 logged, recorded with remaining wall thicknesses less than the allowable A.P.I. tolerances. The log trace for these joints indicates slight irregularities in the casing rather than a wall loss by wear. For example, the pit-like log deflection recorded in Joint ~68 is interpreted to be a mill slug. The deflection recorded near the upper end of Joint 999 is typical of tong or slip mash. The minimum remaining wall thickness recorded is li/32" (72.8% of the nominal wall) for Joints 91, #7, ~38, #40, ~68 and #99. The remaining 194 joints logged are recorded with 12/32" (79.4%) or more remaining wall thickness and still within the allowable A.P.I. tolerances for new casing. DBW/db DIA-LOG t CASING PROFILE CALIPER LOG NOM.O.D. REMAINING WALL THICKNESS 0 1 1 3 1 10 18 ARCO Alaska, Inc. Extension Exploration TRANSMITTAL Date- ~ - 7- f~/~ ' Transmitted herewith are the following- Receipt - Acknowl edgmenl~: Return Receipyto~ ARCO Alasl~a InC. .~ Extension E~pl oration P. O. Box 100360 Anchorage, AK 99510 Attn- A,~-k~ Oi! & ,:Sas Cons. C0mmi~i0~. Da re- Ancho[a~ Processed bY: ARCO Alaska, Inc. Extension Exploration To: Bill Van Alen- AOGC. TRANSMITTAL From: Doug Hastings - Ext. Exploration ,. Date' Jan. 25, 1984 Transmitted herewith are the following' One Copy Each, Blueline & Sepia ARCO- So. Bay St. #1 12-13-83 FDC Run 3 2" & 5" " CNFD " '" 12-16-83 DIL/Sfl Run 4 " " BHC ~ " " " CORIBAND 5" 1-4-84 CMPLN RCD Run 1 5" 12-16-83 FDC Run 4 2" & 5" " CNFD " 2" ~ 5" " NGT " 5" 12-17-83 !2-16-83 12-17-83 12-14-83 12-17-83 10-4-83 LIS TAPE (12-17-83) LIS TAPE _~C PL/C y lk " -.5~" 4/ ~, HR DPMTR " 5" -' RF~/Qklk " RFT " ~ 5" LITH .LG , MUDLOG ~ 2" · PRSS-EVL/Prf 5000-9950 (3 logs) OPEN HOLE Run $ CORBAN Run ~ ARCO: PTNGUT ST 7-26-83 FRAC ID Run 3 7-26-83 FRAC ID Run 3 Receipt Acknowledgment: Return Receipt to/'~~OAlaska Inc. L~ Extension E~ploration P. O. Box 100360 Anchorage, AK 99510 Attn' 8791.0-9998.5 879'1.0-9998.5 #68859 · #68857z~'~ \ "A" Btn "B" Button 9200-10100 "A" Btn "B" Button lg200-11400 o Anohora~e Processed by: Lucille Johnston ATO-1015 x4599 s;TATE -'. ~ .:: /-~-~._.~ OF ALASKA ,,--'~ - ALASKA{ .... JAND GAS"CONSERVATION CC .... )IlSSION ~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATION · Drilling well,~ Workover operation [~] ~,~ 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 83-143 3. Address 8. APINumber P. O. Box 100.360, Anchorage, AK 99510 50- 029-21019 4. Location of Well atsurface 400' FNL, 750' FWL, Sec.22, T11N, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. RKB 61' I ^DL 28322 9. Unit or Lease Name Prudhoe Bay Unit/Lisburne 10. Well No. South Bay State #1 11. Field and Pool PrudhoeBa¥ Field/Lisburne Lisburne 0il Pool For the Month of December , 19 83 2. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 1030 hfs, 10/04/83. Drld 17-1/2" hole to 3800'. Ran, cmted & tested 13-3/8" csg w/FS ~ 3781.'. Drld 12-1/2" hole to 8330'. Ran, crated & tested '11-3/4" lnr. Cored f/8344' - 8713'. Drld 8-1/2" hole f/8713' - 8844'. Ream hole to 12-1/4" f/6480' - 8844'. Ran, crated & tstd 9-5/8" csg. Cored f/8847' - 9477'. RIH w/8-1/2" bit. Drl f/9477' - 9819'. Cored f/9819' - 9954'. Ran logs. Perform DST #1. Drl f/9954' - 9973'. OH logs. Plug back hole to 9666'. Perform DST #2. Run liner.(continued on attached sheet) 13. Casing or liner run and quantities of cement, results of pressure tests 20" 91 5#/ft, H-40 weld conductor set ~ 81' Instd w/191Q# poleset 13-3/8", 72#/ft, L-80 BTC csg w/F5 ~ 3781'. Cmtd w/2400 sxs "Fondu" + 400 sxs PF "C". 11-3/4", 60#/ft, S-95 Hydril csg f/1636' - 6480'. Cmtd w/500 sxs "G" cmt. 9-5/8", 47#/ft, S-95 hydril + L-80 BTC csg w/FS ~ 8836' Cmtd w/550 sxs "G" cmt. 7" 29#/ft L-80 BTC csg f/8543' - 9700' Cmtd w/175 sxs "G" cmt 14. Coring resume and brief description Core #1 f/8344' - 8371'. Recovered 27'. Core #2 f/8371' - 8379'. Recovered 4'. Core #3 f/8379' - 8391'. Recovered 12'. Core #4 f/8391' - 8416'. Recovered 25'. Core #5 f/8416' - 8447'. Recovered 31'. (continued on attached sheet) 15. Logs run and depth where run Log #1 - Borehole Televiewer f/9954' - 8836'. Log #2 - FDC/CNL/Cal/GR f/9954' - 8836'. DIL/BHCS/GR f/9965' - 8830'. LDT/CNL/NGT/GR/Cal f/9973' - 8830'. (continued on attached sheet) LSS/GR f/9965' - 8830'. 6. DST data, perforating data, shows of H2S, miscellaneous data RECEiVFD DST #1 f/9954' - 9750'. DST #2 f/9666' - 9450'. DST #3 f/9652' - 9486'. DST #4 f/9210' - 9440'. -H2S 0ppm 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in dupl{cate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10404 DRN/MR53 Submit in duplicate MONTHLY REPORT (cont'd) South Bay State #1 CONFIDENTIAL 12.) CO cmt to PBTD @ 9652'. Run CBL. Perform DST #3. Sqz perfs f/9516' - 9566'. CO cmt to 9440' PBTD. Perform DST #4 as of 12/31/83. SEE DRILLING HISTORY 14.) Core #6 f/8447' - 8456'. Pressure core recovery not available. Core #7 f/8456' - 8465'. Pressure core recovery not available. Core #8 f/8465' - 8474'. Pressure core recovery not available. Core #9 f/8474' - 8481'. Pressure core recovery not availble. Core #10 f/8481' - 8538'. Recovered 56'. Core #11 f/8538' - 8576'. Recovered 38'. Core #12 f/8576' - 8585'. Pressure core recovery not available. Core #13 f/8585' - 8594'. Pressure core recovery not available. Core #14 f/8594' - 8618'. Recovered 24' Core #15 f/8618' - 8626' Pressure core recovery not available. Core #16 f/8626' - 8635'. Pressure core recovery not available. Core #17 f/8635' - 8644'. Pressure core recovery not available. Core #18 f/8644' - 8653'. Pressure core recovery not available. Core #19 f/8653' - 8713'. Recovered 58'. LISBURNE CORES: Core #1 f/8847' - 8907'. Core #2 f/8907' - 8967'. Core #3 f/8967' - 9015'. Core #4 f/9015' - 9076'. Core #5 f/9076' - 9136'. Core #6 f/9136' - 9196'. Core #7 f/9196' - 9242'. Core #8 f/9242' - 9299'. Core #9 f/9299' - 9359'. Recovery not available. Recovered 60'. Recovered 48-1/2'. Recovered 61 . Recovered 60 Recovered 45 Recovered 55 . Recovered 57 . Recovered 60 . Core #10 f/9359' - 9419'. Recovered 60 Core #11 f/9419' - 9477'. Recovered 58 . Core #12 f/9819' - 9879'. Recovered 60 Core #13 f/9879' - 9939'. Recovered 60 . . Core #14 f/9939' - 9954'. Recovered 15 . 15.) Dipmeter f/9973' - 8830'. RFT f/9559' - 8868'. CBL f/9645' - 8370'° DRN/MR53a:tw RECEIVED SOUTH BAY STATE #1 DRILLING HISTORY CONFIBEIVTIt L NU hydril and diverter system. Spudded well @ 1030 hrs, 10/04/83. Drld 17-1/2" hole to 3800'. Ran 94 jts 13-3/8" 72#/ft, w/FS @ 3781'. Cmtd 13-3/8" csg w/2400 sxs Fondu + 400 sxs PF "C". ND 20" diverter system. Installed 13-3/8" packoffs & tested to 2000 psi - ok. NU BOPE & tested to 5000 psi - ok. Tested csg to 1500 psi - ok. Drld FC + cmt. Drld FS & 10' of new form. Tested form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 8330' Underream 12-1/4" hole to 13-1/2" f/3781' -8330' Ran 119 jts of 11-3/4'~ 60#/ft lnr f/64__87._.~ ,!~636.'. Crated 11-3/4" lnr w/~O0 sxs "G" cmt. Sqz lnr lap w/200 sxs PF "C" cmt. Drl cmt f/1630' - 1646' Drl cmt f/1630' - 1646'. Drl cmt f/6226' - 6480'. TIH to 8330' Drl' 10' new hole. Form leak-off test. RIH w/coring assy. Cut core #1 'f/8344' - 8371'. Recovered 27'. Redress core barrel. RIH. Cut core #2 f/8371' - 8379' Recovered 4' RIH & cut core #3 f/8379' - 8391'. Recovered 12' RIH &'cut core #4 f/~391' - 8416'. Recovered 25' RIH & cut core #'5 f/8416' - 8447' Recovered 31'. RIH & cut core ~6 f/8447' - 8456'. RIH & cut core #~ f/8456' - 8465'. Ream 6-1/2" hole to 8-1/2" f/8447' - 8465'. Cut core #8 f/8465' - 8474' RIH & cut core #9 f/8474' - 8481'. RIH & ream 6-1/2" hole to 8-1/2" f/84~5' - 8481'. POOH. RIH & cut core #10 f/8481' - 8538'. Recovered 56'. RIH & cut core #11 f/8538' - 8576'. Recovered 38'. RIH & cut core #12 f/8576' - 8585'. RIH & cut core #13 f/8585' - 8594'. RIH & ream 6-1/2" hole to 8-1/2" f/8576' - 8594'. Circ + cord hole. POOH. RIH. Wash & ream f/8569' - 8594'. Cut core #14 f/8594' - 8618' Recovered 24'. RIH & cut core #15 f/8618' - 8626'. RIH & cut core #16'f/8626' - 8635'. RIH w/8-1/2" bit & ream f/8618' - 8635'. CBU. POOH. RIH & cut core #17 f/8635' - 8644'. Cut core #18 f/8644' - 8653'. TIH w/8-1/2" bit & ream 6-1/2" hole to 8-1/2" f/8635' - 8653' Cut core #19 f/8653' - 8713'. Recovered 58' TIH w/8-1/2" bit & drld ~/8713' - 8844' Circ. POOH. RIH w/9-7/8" bit '& ream 8-1/2" hole to 9-7/8" f/8340' - ~428'. CIRC. Ream f/8428' - 8621' POOH. Underream hole w/12-1/4" underreamer f/6480' - 8844'. POOH. R~H & re-ream f/6480' - 8844'. POOH. RU & run 207 jts of 9-5/8" csg w/FS @ 8836'. Crated csg w/550 sxs "G" cmt. Land cs§. Test pack-offs to 3000 psi. RIH w/8-1/2" bit. Tag top of-Xcmt @ 8742' Test csg to 3000 psi. Drl FC & cmt to FS @ 8836' CO to 8844' Drld' f/8844' - 8847'. Form leak-off test to 13.1 ppg. Cl'ean mud pits f'/chng to oil-faze system. Displ well f/bland mud to oil-faze. TIH w/core bbl #1. Survey. Cut core #1 f/8847' - 8907'. CBU. TOH. Recover core #1. TIH & cut core #2 f/8907' - 8967' POOH. Recovered 60'. TIH w/core #3. Cut core #3 f/8967' - 9015' T~H w/core #3. Recovered 48-1/2' TIH w/core barrel #4. Core f/9015' - ~076'. POOH. Recovered 61'. RIH w/'core #5. Core f/9076' - 9136'. POOH. Recovered 60'. RIH w/core #6. Cut core f/9136' - 9196' POOH. Recovered 45' RIH w/core #7. Cut core #7 f/9196' - 9242' PO0~ w/core #7. Recovere~ 55', (15' of which was recovered f/core #6i. RIH w/core #8. Cut core f/9242' - 9299' CBU. POOH. Recovered 57'. RIH w/core #9. Cut core #9 f/9299' - 9359". CBU. POOH~ Recovered 60'. RIH w/core #10. Cut core #10 f/9359' - 9419' CBU. POOH. Recovered 60'. RIH w/core #11 f/9419' - 9477'. CBU. POOH] Recovered 58' f/core #11. RIH w/8-1/2" bit. Drl f/9477' - 9819'. CBU. POOH. RIH w/Core #12. Cut core f/9819' - 9879' CBU. POOH. RIH w/core bbl #13. Cut Core #13 f/9879' - 9939'. CBU. PO~H. Recovered 60'. RIHw/core bbl #14. Core f/~i,.9~~tV~[ JAN 1 9954'. BBL jammed. POOH w/Core #14. Recover core. TIH w/8-1/2" bit. Circ & cond. POOH. ;.Ran log #1, "Borehole Televiewer'!-:~;f/9954'~.-~ 8826'. Ran log #2, FDC/CNL/Cal/GR f/9954' - 8836'. RD loggers. TIH w/8-1/2" bit. Circ & cond. mud @ TD. POOH. PU DST tools. TIH. Perform DST #1 f/9954' - 9750'. POOH w/DST tools. RIH w/8-1/2" bit. Dri f/9954' - 9973'. CBU. POOH. Log w/DIL/BHCS/GR. Chng tools. Log w/LDT/CNL/NGT/GR/Cal. Chng tools. Log w/LSS/GR. Chng tools. Log w/Dipmeter. Chng tools. Log w/RFT. Conditioning trip. RIH w/3-1/2" DP. Plug back hole w/125 sxs Class "G" cmt. RIH w/8-1/2" bit & CO to 9666'. CBU. POOH. PU DST #2 tools + RIH. Test BOPE. Perform DST #2. POOH. PU 8-1/2" bit + RIH. Drl cmt f/9666' - 9700'. PBTD. Circ & cond. POOH. RIH w/liner. Liner set f/8543' - 9700'. Cmtd lnr w/175 sxs "G" cmt. Co cmt to top of lnr @ 8543'. CO cmt to PBTD @ 9652'. Test csg. TOH. Run CBL f/9645' - 8370'. RIH w/DST #3 tools. Perform-DST #3 f/9652' - 9486'. TOH w/DST #3 tools. RIH w/cmt ret + set @ 9450'. Sqzd 30 bbl Class "G" cmt into perfs f/9516' - 9566'. POOH. TIH w/6" bit & CO cmt to 9440' PBTD. Test csg to 3000 psi. POOH. RIH w/DST #4 tools. Perform DST #4 f/9210' - 9440', as of 12/31/83. DRN/DH47- tw RECEIVED ARCO Alaska, Inc. * Post Office B,...,'100360 Anchorage, Alaska 99510 Telephone 907 276 1215 December 30, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: South Bay State #1 - Safety Procedures Dear Mr. Chatterton: Although we have not encountered H^Sz in the subject well, nor do we expect to, we have implemented additional H S safety procedures. The attached letter, dated December ~9, 1983, outlines the various safety procedures that have been included in our H2S monitoring program on the South Bay State #1 well. If you have any questions, please call me at 263-4610. Sinc~ere~y,~ T. L. Fithian Area Drilling Engineer T.LF/03:rb Attachment cc: South Bay State #1 Well File J. Gruber, ATO 1478 J. R. Rall, ATO 1458 R. A. Ruedrich, ATO 1926 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc, Date: Subject: From/Location: To/Location: Internal Correspond December 29, 1983 Safety Procedures Impletemented on South Bay State #1 R. L. Hines - ATO 1470 Scott Walker - ATO 1378 As of this date, the following safety procedures have been included in our H2S monitoring program on the South Bay State well: . Four (4) automatic hydrogen sulfide monitoring devices with audio/visual alarms have been installed. These are located at the shale shaker, bell nipple, rig floor, and on the stairway leading to the mud pits. Currently, these monitors are tested and watched by the mud loggers during drilling operations. . Two (2) hand-held Draeger detection meters are on location; one in the doghouse and one located in the pit area. Use of the meters was discussed during a safety meeting. Be e Zn CO3, a hydrogen sulfide scavenger, is on location. Fourteen (14) Scott Air Packs (Scott Pressur-Pak II/Back-Pac Style) are on location. Twelve (12) are located on the rig and two (2) are in the camp. A demonstration on how to use the air packs was given during safety meetings. e A H~S Contingency Plan has been prepared showing possible escape routes from the rig and location. . ARCO Alaska, Inc.'s Fire and Safety personnel have presented a safety meeting to each of the crews on the rig. A film, "H2S Can Kill" was shown. A discussion on the properties of H2S, how to detect its presence, use of the "buddy system" for rescue, safe breathing areas, and how to use the Scott Air Pack followed. e ge The wellhead currently being used is H2S rated. The Magcobar mud engineer performs a chemical check of the mud for H2S twice daily during drilling operations. e Sensor badges that change color when H2S is present are being worn by each member of the drilling crew. 10. Sign posted at the drillsite access indicate potential H2S. 11. Audio alarm and flashing light has been installed at the test facility. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany H2S Safety Procedures - South Bay State #1 December 29, 1983 Page 2 12. There are two (2) wind socks; one at the drillsite access and one on location. 13. Station bills have been posted. 14. H2S monitoring panel installed on the rig in the doghouse for use during testing and completion operations. R. L. Hines Sr. Drilling Supervisor RLH:sw M01 12/29/83 xc: R. A. Ruedrich W. S. Congdon South Bay State #1 Well File T. L. Fithian M. J. Hebert/E, Kirk 'White ARCO Alaska, Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 December 16, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: South Bay State #1 Dear Mr. Chatterton- Enclosed is a Sundry Notice for the subject well. We propose to plug back to 9700' TVD. Since we expect to start this work on December 17, 1983, your earliest approval will be appreciated. If you have any questions, please call me at 263-4965. S i n ce re~: 1. L. FithSan ^rea Dr~ll~n~ [n§ineer TLF/JG-tw GRU5/L73 Enclosures ARCO Alaska, inc. is a Subsidiary of AtlanticRichfieldCornpany STATE OFALASKA ~-'. ALASrkA ~iL AND GAS CONSERVATIO,...;L,,.,IMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL I-X]X COMPLETED WELL [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 83-143 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21019 4. Location of Well Surface: 400' FNL, 750' FEL, Sec.22, TllN, ELSE, UN 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 12. 61' RKB ADL 28322 OTHER [] 9. Unit or Lease Name Prudhoe Bay Uni t/Lisburne 10. Well Number South Bay State #1 11. Field and Pool Prudhoe Bay Fie1 d/Lisburne Lisburne 0il Pool 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 j~ 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 Abandonmehtsee20 AAC 25.105-170). ARCO Alaska, Inc., proposes to plug back the South Bay State #1 well to 9700' TVD. A cement plug will be set from the current TD ~ 9964' to 9700' with approximately 100 sx Class G cement. The open hole above plug back TD to the 9-5/8" casing will be cased off and cemented with a 7" liner as proposed in the original permit. Estimated Start: December 17, 1983 Verbal approval rec'd 12/16/83 from M. Minder, AOGCC. 14. I hereby certify that the fgC,~going is true and correct to the best of my knowledge. Signed ~"~, -~- ~~ Title Area Dril 1 ing Engi near The space below for Commission use Conditions of APproval, if any: BY LOH~IE C. SMI111 Approved by. COMMISSIONER Approved Copy Returned By Order of the Commission Form 10403 Rev. 7-1-80 GRUS/SN38 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ...... , STATE OF ALASKA ALA~KA-£~-~"AND GAS coNSERVATION CO', IlSSlON MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS'Y ~ Drillin~wel----~-~ Wor~ove---r ~ 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 83-143 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21019 9. Unit or Lease Name Prudhoe Bay Unit/Lisburne 4. Location of Well atsurface 400~ FNL, 750' FWL, Sec.22, T11N, R15E, UM CONFIDENTIAL .. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RKB 61' ADL 28322 - 10. Well No. South Bay State #1 11. Field and Pool PrudhoeBa¥ Field/Lisburne Lisburne Oil Pool For the Month of. November ,19 83. 2. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 1030 hfs, 10/04/83. Drld 17-1/2" hole to 3800'. Ran, cmted & test-ed 13-3/8" csg w/FS @ 3781'. Drld 12-1/2" hole to 8330'. Ran, cmted & tested 11-3/4" lnr. Cored f/8344' - 8713'. Drld 8-1/2" hole f/8713' - 8844'. Ream hole to 12-1/4" f/6480' - 8844'. Ran, cmted & tstd 9-5/8" csg. Cored f/8847' - 9477'. RIH w/8-1/2" bit. Drl f/9477' - 9525' as of 11/30/83. SEE DRILLING HISTORY 13. Casing or liner run and quantities of cement, results of pressure tests 20", 91.5#/ft, H-40 weld conductor set @ 81'. Instd w/1910# poleset. 13-3/8", 72#/ft, L-80 BTC csg w/FS @ 3781'. Cmtd w/2400 sxs "Fondu" + 400 sxs PF "C". 11-3/4", 60#/ft, S-95 Hydril csg f/1636' - 6480'. Cmtd w/500 sxs "G" cmt. 9-5/8", 47#/ft, S-95 hydril + L-80 BTC csg w/FS ~ 8836'. Cmtd w/550 sxs "G" cmt. SEE DRILLING HISTORY 4. Coring resume and brief description Core #1 f/8344' - 8371'. Recovered 27'. Core #2 f/8371' - 8379'. Recovered 4'. Core #3 f/8379' - 8391'. Recovered 12'. Core #4 f/8391' - 8416'. Recovered 25'. Core #5 f/8416' - 8447'. Recovered 31'. (continued on attached sheet) 15. Logs run and depth where run N/A .16. DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. . SIGNED //_///,~-/ .... lllL NOTE--~5~rt on tl~s form is required for each calendar month, regardless of the status of operations, and must be/~iled in duplicate with the Alaska Oil ar~ Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 DRN/MR51 Submit in duplicate MONTHLY REPORT (cont'd) South Bay State #1 CONFIDENTIAL 14.) Core #6 f/8447' - 8456'. Pressure core recovery not available. Core #7 f/8456' - 8465'. Pressure core recovery not available. Core #8 f/8465' - 8474'. Pressure core recovery not available. Core #9 f/8474' - 8481'. Pressure core recovery not availble. Core #10 f/8481' - 8538'. Recovered 56'. Core #11 f/8538' - 8576'. Recovered 38'. Core #12 f/8576' - 8585'. Pressure core recovery not available. Core #13 f/8585' - 8594'. Pressure core recovery not available. Core #14 f/8594' - 8618'. Recovered 24'. Core #15 f/8618' - 8626'. Pressure core recovery not available. Core #16 f/8626' - 8635'. Pressure core recovery not available. Core #17 f/8635' - 8644'. Pressure core recovery not available. Core #18 f/8644' - 8653'. Pressure core recovery not available. Core #19 f/8653' - 8713'. Recovered 58'. LISBURNE CORES: Core #1 f/8847' - 8907'. Core #2 f/8907' - 8967'. Core #3 f/8967' - 9015'. Core #4 f/9015' - 9076'. Core #5 f/9076' - 9136'. Core #6 f/9136' - 9196'. Core #7 f/9196' - 9242'. Core #8 f/9242' - 9299'. Core #9 f/9299' - 9359'. Recovery not available. Recovered 60'. Recovered 48-1/2'. Recovered 61'. Recovered 60'. Recovered 45'. Recovered 55'. Recovered 57'. Recovered 60'. Core #10 f/9359' - 9419'. Recovered 60'. Core #11 f/9419' - 9477'. Recovered 58'. DRN/MR51a:tw SOUTH BAY STATE #1 DRILLING HISTORY NU hydril and diverter system. Spudded well @ 1030 hrs, 10/04/83. Drld 17-1/2" hole to 3800'. Ran 94 jts 13-3/8" 72#/ft, w/FS @ 3781'. Cmtd 13-3/8" csg w/2400 sxs Fondu + 400 sxs PF "C". ND 20" diverter system. Installed 13-3/8" packoffs & tested to 2000 psi - ok. NU BOPE & tested to 5000 psi - ok. Tested csg to 1500 psi - ok. Drld FC + cmt. Drld FS & 10' of new form. Tested form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 8330'. Underream 12-1/4" hole to 13-1/2" f/3781' -8330'. Ran 119 jts of 11-3/4" 60#/ft lnr f/6480' - 1636'. Cmted 11-3/4" lnr w/500 sxs "G" cmt. Sqz lnr lap w/200 sxs PF "C" cmt. Drl cmt f/1630' - 1646'. Drl cmt f/1630' - 1646'. Drl cmt f/6226' - 6480'. TIH to 8330'. Drl 10' new hole. Form leak-off test. RIH w/coring assy. Cut core #1 f/8344' - 8371'. Recovered 27'. Redress core barrel. RIH. Cut core #2 f/8371' - 8379'. Recovered 4'. R~H & cut ,core #3 f/8379' - 8391' Recovered 12' RIH & cut core #4 f/8391 - 8416 . Recovered 25' RI~ & cut core #~ f/8416' - 8447' Recovered 31'. RIH & cut core ~6 f/8447' - 8456'. RIH & cut core #~ f/8456' - 8465'. Ream 6-1/2" hole to 8-1/2" f/8447' - 8465'. Cut core #8 f/8465' - 8474' RIH & cut core #9 f/8474' - 8481'. RIH & ream 6-1/2" hole to 8-1/2" f/84~5' - 8481'. POOH. RIH & cut core #10 f/8481' - 8538'. Recovered 56'. RIH & cut core #11 f/8538' - 8576'. Recovered 38'. RIH & cut core #12 f/8576' - 8585'. RIH & cut core #13 f/8585' - 8594'. RIH & ream 6-1/2" hole to 8-1/2" f/8576' - 8594'. Circ + cond hole. POOH. RIH. Wash & ream f/8569' - 8594' Cut core #14 f/8594' - 8618' Recovered 24' RIH & cut core #15 f/8618' - 8626' RIH & cut core #16 f/8626' - 8635' RIH w/8-1/2" bit & ream f/8618' - 8~35'. CBU. POOH. RIH & cut core #1~ f/8635' - 8644'. Cut core #18 f/8644' - 8653'. TIH w/8-1/2" bit & ream 6-1/2" hole to 8-1/2" f/8635' - 8653' Cut core #19 f/8653' - 8713' Recovered 58'. TIH w/8-1/2" bit & drld ~/8713' - 8844' Circ. POOH. RI~ w/9-7/8" bit & ream 8-1/2" hole to 9-7/8" f/8340' - ~428' CIRC. Ream f/8428' - 8621'. POOH. Underream hole w/12-1/4" underre~mer f/6480' - 8844'. POOH. RIH & re-ream f/6480' - 8844'. POOH. RU & run 207 jts of 9-5/8" csg w/FS @ 8836'. Cmted csg w/550 sxs "G" cmt. Land csg. Test pack-offs to 3000 psi. RIH w/8-1/2" bit. Tag top of cmt @ 8742' Test csg to 3000 psi. Drl FC & cmt to FS @ 8836' CO to 8844' Drld' f/8844' - 8847'. Form leak-off test to 13.1 ppg· Cl'ean mud pits f~chng to oil-faze system. Displ well f/bland mud to oil-faze. TIH w/core bbl #1. Survey. Cut core #1 f/8847' - 8907'. CBU. TOH. Recover core #1. TIH & cut core #2 f/8907' - 8967' POOH. Recovered 60' TIH w/core #3. Cut core #3 f/8967' - 9015'. T~H w/core #3. Recovered' 48-1/2'. TIH w/core barrel #4. Core f/9015' - 9076' POOH. Recovered 61'. RIH w/core #5. Core f/9076' - 9136'. POOH. RecoVered 60' RIH w/core #6. Cut core f/9136' - 9196' POOH. Recovered 45' RIH w}core #7. Cut core #7 f/9196' - 9242' PO0~ ' i w/core #7. Recovered 55', (15' of which was recovered f/core #6 . RIH w/core #8. Cut core f/9242' - 9299' CBU. POOH. Recovered 57'. RIH w/core #9. Cut core #9 f/9299' - 9359". CBU. POOH. Recovered 60'. RIH w/core #10. Cut core #10 f/9359' - 9419'. CBU. POOH. Recovered 60' RIH w/core #11 f/9419' - 9477'. CBU. POOH. Recovered 58' f/core #11. RIH w/8-1/2" bit. Drl f/9477' - 9525' as of 11/30/83. DRN/DH45' tw ' - " ~__~ STATE OF ALASKA ~.-..~ -ALASKA' ' AN D GAS CONSERVATION C£ MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [] ,Wo'i'kove'r operation [] 2. Name of operator ~ ,~ Ill~iI*li ll'-I~ ~ ~/~_~ 17. PermitNo. ARCO Alaska, Inc. Vwlll II.~I=.lll ~nl~ I 83-143 3. Address P. 0. Box 100360, Anchorage, AK 4. Location of Well at surface 400 ' F N L, 750 ' 5. Elevation in feet (indicate KB, DF, etc.) RKB 61 ~ 99510 FWL, Sec.22, T11N, R15E, UM 6. Lease Designation and Serial No. ADL 28322 8. APl Number 029-21019 50-- 9. Unit or Lease Name Prudhoe Bay Unit/Lisburne 10. Well No. South Bay State #1 11. Field and Pool PrudhoeBa¥ Fi eld/Lisburne Lisburne 0i1 Pool For the Month of. 0 c t o b e r ,19 83 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 1030 hfs, 10/04/83. Drld 17-1/2" hole to 3800'. Ran, 13-3/8" csg w/F5 @ 3781'. Drld 12-1/2" hole to 8330'. Ran, cmted & tested Cored f/8344' - 8644' as of 10/31/83. SEE DRILLING HISTORY cmted & tested 11-3/4" lnr. !13. Casing or liner run and quantities of cement, results of pressure tests 20" 91 5#/ft, H-40 weld conductor set ~ 81' Instd w/1910# poleset 13-3/8", 72#/ft, L-80 BTC csg w/FS ~ 3781'. Cmtd w/2400 sxs "Fondu" + 400 sxs PF "C". 11-3/4" 60#/ft S-95 Hydril csg f/1636' - 6480' Cmtd w/500 sxs "G" cmt SEE DRILLING HISTORY 14. Coring resume and brief description - 8371'. - 8379'. - 8391'. - 8416'. - 8447'. Core #1 f/8344' Core #2 f/8371' Core #3 f/8379' Core #4 f/8391' Core #5 f/8416' Recovered 27'. Recovered 4'. Recovered 12'. Recovered 25'. Recovered 31'. (continued on attached sheet) 15. Logs run and depth where run N/A DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Area Drilling Engineer /(_~-~ SIGNED ~t'. /~' ~----- ~ ~ TITLE ............... DATE _ -- NOTE--Report on this form is required for/~ach calendar month, regardless of the status of operations, and must be flied in duplicate with the Alaska Oil and Gas Conservation Commission by die 15th of the succeeding month, unless otherwise directed. Form 10q04 D R N / M R45 Submit in duplicate MONTHLY REPORT (cont'd) South Bay State #1 CONFIDENTIAL 14.) Core #6 f/8447' - 8456'. Pressure core recovery not available. Core #7 f/8456' - 8465'. Pressure core recovery not available. Core #8 f/8465' - 8474'. Pressure core recovery not available. Core #9 f/8474' - 8481'. Pressure core recovery not availble. Core #10 f/8481' - 8538'. Recovered 56'. Core #11 f/8538 - 8576'. Recovered 38'. Core #12 f/8576 - 8585'. Pressure core recovery not available. Core #13 f/8585 - 8594'. Pressure core recovery not available. Core #14 f/8594 - 8618'. Recovered 24'. Core #15 f/8618 - 8626'. Pressure core recovery not available. Core #16 f/8626 - 8635'. Pressure core recovery not available. Core #17 f/8635 - 8644'. Pressure core recovery not available. DRN/MR4$a:tw SOUTH BAY STATE #1 DRILLING HISTORY . , CONFIDENTIAL NU hydril and diverter system. Spudded well @ 1030 hrs, 10/04/83. Drld 17-1/2" hole to 3800'. Ran 94 jts 13-3/8" 72#/ft, w/FS @ 3781'. Cmtd 13-3/8" csg w/2400 sxs Fondu + 400 sxs PF "C". ND 20" diverter system. Installed 13-3/8" packoffs & tested to 2000 psi - ok. NU BOPE & tested to 5000 psi - ok. Tested csg to 1500 psi - ok. Drld FC + cmt. Drld FS & 10' of new form. Tested form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 8330'.. Underream 12-1/4" hole to 13-1/2" f/3781' -8330' Ran 119 jts of 11-3/4'~ 60#/ft lnr f/6480' - 1636'. Crated 11-3/4" lnr w/~O0 sxs "G" cmt. Sqz lnr lap w/200 sxs PF "C" cmt. Drl cmt f/1630' - 1646'. Drl cmt f/1630' - 1646'. Drl cmt f/6226' - 6480'. TIH to 8330'. Drl 10' new hole. Form leak-off test. RIH w/coring assy. ' Cut core #1 f/8344' - 8371'. Recovered 27'. Redress core barrel. RIH. Cut core #2 f/8371' - 8379'. Recovered 4' RIH & cut core #3 f/8379' - 8391' Recovered 12' RIH & cut core #4 f/~391' - 8416'. Recovered 25' RI~ & cut core #~ f/8416' - 8447' Recovered 31' RIH & cut core ~6 f/8447' - 8456'. RIH & cut core #~ f/8456' - 846~'. Ream 6-1/2" hole to 8-1/2" f/8447' - 8465'. Cut core #8 f/8465' - 8474' RIH & cut core #9 f/8474' - 8481'. RIH & ream 6-1/2" hole to 8-1/2" f/84~5' - 8481'. POOH. RIH & cut core #10 f/8481' - 8538'. Recovered 56' RIH & cut core #11 f/8538' - 8576'. Recovered 38'. RIH & cut core #12 'f/8576' - 8585' RIH & cut core #13 f/8585' - 8594'. RIH & ream 6-1/2" hole to 8-1/2" f/'8576' - 8594'. Circ + cond hole. POOH. RIH. Wash & ream f/8569' - 8594'. Cut core #14 f/8594' - 8618'. Recovered 24'. RIH & cut core #15 f/8618' - 8626' RIH & cut core #16 f/8626' - 8635' RIH w/8-1/2" bit & ream f/8618' - 8~35'. CBU. POOH. RIH & cut core #1~ f/8635' - 8644'. DRN/DH39-tw MEMORA.NOUM TO: Thru: Lonnie C. Smith Commissioner ~ ~ State of Alaska TELEPHONE NO: SU BJ ECT: 1983 Witness. BOPS Test on ARCO's South Ba~ State So. I, Sec. 22, Tll~,R15L,U.M., Permit No. 83-143. T__hurs~a.y, Oc_tober 6, 1983: Mile testing safety valves at A~CO's P.B.U., I was contaCted by Don ~4icke~-, ARCO drilling foreman, requesting I come to Rowan Rig No. 41 and witness the upcon~n9 BOPE test. After completing safety valve testing for the day, I went to Rig ~o. 41 and began testing the BOPE's at 6:30 pm and completed at 8:30 pm. As the attached BOPS test report shows there were no failures. In summary, I witnessed the BOPE test on ARCO's South Bay State NO. 1. Attachment - 02-00IA(Rev. 10/79) STATE OF ALASKA ALASKA OII?~.-CAS CONSERVATION CQMMISSION B.C._ .E. Inspection Report . ........... f~ ~ "~ , , ~ ~ ~ ~~ .... ~' ~rator. /7~~ ~ ~ ,,, Repres~tativ~ ~_3 ~~~ ~ ~i~ling ~n~a~or ~~~~j .Rig ~/. ~g~[~mntative~3~ ~~~ ~tion, ~neral -[ 3f~ . AC~U~R SYS~M .. .' ' Well Si~ --~CC'' ~1 ~arge ~es~e~~ psig Ceneral Ho~e~~. ~~ , ~essure ~ter Clo~re ,~P ~ psig Rm~e pit ~/ . BOPE Stack Annular Preventer: , Blind Rams Choke Line Valves .. H.C.R. Valve Kill Line Valves Check Valve q / Test Pressure Pump incr. clos. pres - 200 psig. ~" m.i~/,D sec. Full Charge Pressure Attained: ~ min.~CDsec. ., Controls: Master .C~? ~ Remote ~{~Blinds_ switch cover Kelly and Floo~ Safety Valves - Upper. Kelly / Test Pressure ~_~ ~ · LOWer Kelly.. /. Test Pres sure / Ball Type. _ J Test Pressure Inside BOP. / Test Presslre Choke Manifold ~~ Test Pressure No. flanges ~ ~ ~justable Choke~q / ~ / '- Hydrauically operated choke / Test Results: Failures, .. [~ .. Test Time.' ~ Repair or. Replacement of failed equipment to be made within. Inspector/Ccmmission office notified, Remarks: ~-~" days and Distribution orig. - AC&GCC cc - Operator cc - Supervisor ARCO Alaska, In,?-~ Post Office ..,ox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 6, 1983 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - South Bay State #1 Dear Elaine- Enclosed is an as-built location plat for the subject well. Since this information is of a confidential nature, we would appreciate it if you could store it in a secure area. If you haVe any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer GRU4/L90' sm Enclosure RECEIVED Alaska Oii & G~s (;OHS, b~th~f~Js$io~ Anch:~rafle ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany I - ~~ .~,-. ,-.,..~,. '~ .~...'~REN M. SEiBER~ . '~-=C,,',i~: i"= ~C:~' ~ CO-ORDINATES I HEREBY CERTIFY THAT ! AM ~-~ PROPERLY REGISTERED AND X ' 708,001.47- LICENSED .TO PRACTICE L~ND ~' SURVEYING iN THE STATE OF LAT= 70°17'57.$84'' <-'~ ALASKA AND THAT THIS PLAT REPRESENTS AN AS-BUILT SURVEY LONG = 148° 18'55.069" MADE BY ME, AND THAT ALL ~' DIMENSIONS AND OTHER DETAILS NW CORNER CELLAR BO~' ARE CORRECT, AS OF: 10'01-8;~ ELEV. = 18,3' NOTE' I. COORDS ARE BASED ON AI.J~KA STAT~ P~IE, ZONE 4 :>. 8~$15 OF' EL£¥. I$ ~OA~ BEnCHMaRK N I6? ~. DISTANC£$ AR[ SHRF~CF . W'W - ~sao~t.-r of SOUT~ ~'¢ STa-r[ CO~OucTo~ " ARCO Oil and Ga~ Company Division o! Atlantic RichlY®Id Comp~n~ NORTH ALASKA DISTRICT' PRUDHOE BAY DWG No~ · II I September Mr. D. S. Smiiey Area /)ri 11 ing Engineer ARO~- Alaska, Inc. P. O. Pox 100360 Anchorage, Alaska 99510 Re~ Prudhoe Bay UnittLiSburne South Bay State No. 1 AROD Alaska, Inc. Per. it No, ~$-I43 Sur. Loc.. 400'~_~L, 750'F~L. Sec. 22, TllN, R15E, t~. Btmhole Lee. S A ~ B Dear ~r. Smi Iey: Enclosed is the approved application for permit to drill the above referenced wel i. If coring is conducted, a one cubic inch chip fror~ each foot of recovered core is required. Samples of well'cuttings and a mud log are required. An inclination survey is required as per 20 AAC 25,050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental log_s, velocity surveys and dipmeter - ~{any rivers in Alaska and their drainage systems have been classified as important for the spav,~ing or migration of anadrorr~ous fish. Operations in these areas are subject to AS 16.05.870 and the regulatio~ :profited thereunder (Title 5, Alaska A~inistrative Code). Prior to e~eneing operation~ you-m~y be contacted by the Habitat Coordinator's Office, ~partment of Fish and G~e. Pollution of any waters'of the State is prohibited by AS 46, Chapter 3, Article 7 and ~he regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to cou~nencing operations you may be contacted by a representative of the Department of Enviro~ental Conservation. To aid us in scheduling field work, please notify this office 24 hours prior to e~menei~C installation of the blowout ,~.~r, D, S, Sn~i 1 ey ~ 2-.: . Pm~dhoe BaY UnltlLisburne South Bay State No. 1 September 30. 1983 prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casin~ shoe~ ts drilled. Where a diverter system is required, please also notify this office 24 hours prior to c~ncing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give-this office adequate advance notification so that we may have a wi tness present. Very ~,ru ly ?ou~r~, / ~ ~ ~ ~ / I C. V. ~atterton:' -' Alaska Oil and Gas Conservation C~ission be:6~H/A Enclosure Department of Fish ~ ~ame, l~abitat Section .w/o encl. Department of ~nvironmental Conservation w/o encl, ARCO Alaska, Inc. ~ Post Office BL~ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 September 29, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' South Bay State #1, Permit to Drill Dear Mr. Chatterton' Please find attached a letter from the geologists working on the South Bay State #1 well stating that no hydrocarbon deposits are expected to or have been encountered above 4000' SS in wells adjacent to the South Bay State #1 location. ARCO Alaska, Inc. does plan to use a diverter while drilling the 17-1/2" surface hole. Since we plan to spud this well on October 5, 1983, your earliest approval will be appreciated. Also, since this well is confidential in nature, could you please keep this information in a secure area. If you have any questions, please call me at 263-4610. Sincerely, D. S. Smiley Area Drilling Engineer DSS/JRR:tw JRR/49 Attachment Alaska 0it & Gas Gons~ Anch0rag0 ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. /,-,;-,~. Internal Correspond~ .~ Date: Subject: September 27, 1983 Hydrocarbon Potential in Shallow Portion of So. Bay St. No. 1 Well Based on East Bay St. #1 and Sag River St. #1 logs. From/Location: B.A. Durfee & D. S. Hastings To/Location: John Rall- ATO 1458 All of the Shallow Sands markers are well below 4000' subsea in Townships ION and llN, R15E based on picks from Sag River St. #1 and East Bay St. #1 logs. The Shallow Sands appear to be wet and there are no apparent hydrocarbon bearing sands above them in these wells. We therefore ascribe no hydrocarbon potential to the interval above -4000 feet in the South Bay well area. East Bay St. #1 - Formation Markers Subsea T3 -4437 K-15 -4940 Upper Ugnu -5950 Lower Ugnu -6235 K-13 -6496 West Sak Sands -6575 Sag River St. #1 - Formation Markers Subsea T3 -4233 K-15 -4766 Upper Ugnu -5796 Lower Ugnu -6980 K-13 -6357 West Sak Sands -6433 B. A. Durfee Geologist Senior Geologist cc: J. D. Fortier M. R. Werner - ATO 1092 File: GO 12 SS 4.2 ARCO Alaska, Inc. is a Subsidiary of AflanflcRichfleldCompany ARCO Alaska, Inc. "% Post Office By_. 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 19, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- South Bay State #1, Permit to Drill Dear Mr. Chatterton' Enclosed is our application for Permit to Drill South Bay State #1 and the required $100 filing fee. Attachments to the application include a plat detailing the proposed South Bay State pad and access road; a sketch and description of the BOP equipment; and a sketch and description of the surface hole diverter system. Since we expect to spud this well on October 1, 1983, your earliest approval will be appreciated. Also, since this well is of a confidential nature, could you please keep this information in a secure area. If you have any questions, please call me at 263-4610. D. S. Smiley~ Area Drilling Engineer DSS/JG'tw GRU4/L53 Enclosures Gas Oons, f.;',ommissio~ ~mhorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany la. Type of work. DRILL REDRILL DEEPEN PERMIT TO DRILL 20 AAC 25.005 SERVICE [] STRATIGRA~)~J-I. J,{; [] ] MULTIPLE ZONE [] ~'~ ~- qtaaka ~Jil & Gas C°.~, .~_J ,,o. bO ,..~ nchor~gc ~m~t lb. Type of well EXPLORATORY [] DEVELOPMENT OIL I~x DEVELOPMENT GAS [] 2. Name of operator ARCO Alaska, Inc. 3. Address P.0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 400' FNL, 750' FWL, Sec. At top of proposed producing interval 400' FNL, 750' FWL, Sec. At total depth 400' FNL, 750' FWL, Sec. 22, TllN, R15E, UM 22, T11N, R15E, UM 22, T11N, R15E, UM 5. Elevation in feet (indicate KB, DF et~:.) Pad 21 ', RKB 61 ' I 6. Lease designation and serial no. ADL 28322 12. Bond information (see 20 AAC 25.025) Type Statewi de Surety and/or number 9. Unit or lease name Prudhoe Bay Unit/Lisburne 13. Distance and direction from nearest town I 14. Distance to nearest property or lease line 8 mi. NE of Deadhorse miles I 4530' feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 11061 ' ( MD=TVD ) feet 2560 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICKOFF POINT N/A feet. MAXIMUM HOLE ANGLE +2°°I (see 20 AAC 25.035 (c) (2) 10. Well number South Bay State #1 21 SIZE Hole l Casing 30" 20" 17½' 13-3/8 ~... 11. Field and pool Prudhoe Bay Field/Lisburne Lisburne 0fl Pool Proposed Casing, Liner and Cementing Program CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Weight Grade Coupling/ Length MD TOP TVD MD BOTTOM TVD (include stage data) 94# H-40 Wel deq 85 ' 35 ' I 35 ' I 20 ' Ii I ?~ ' I qnn~ p,~ es~ I 72# L-80 Butt /'3966' 34' 34' 4000' .40r).~× on ,, 12:~'[11-3/4 59¢ S-95 SFJP/j 4686' 3700'' 3700'1 8386' I 8386' SO0sx c~no,_ ~ sx pr~_/ 10~'r 9 5/8' 47¢ L-80 SFJP / 8743' 33' ~ 33' 8776' I 8776 500sx O & 300 sx PF1 8~" / 7" 29¢ L-80 Butt I 2585' 8476' I I ~ 8476' 11061' I 11061' 550sx Class G gmt 22. Describe proposed program: ARCO A]aska~ Inc., proposes to dri]l this vertical hole to 11~061~ (ND=TVD) to core the Sadlerochit zone and to core and test the Lisburne zone. Logs will be run from the 13-3/8" casing shoe to TD. A 13-5/8" 5000. psi RSR~A BOP stack wi1] be installed and tested. The annular preventer will be tested ~o 3000 psi and rams tested ~o 5000 ps~. The BOP equipment will be pressure tested each week and operationa]]y tested each trip. This we]l will be completed with a packer above the producing interval and produced through tubing for a long-term Lisburre ~est. A]] intervals perforated while the rig is on the ho]e wi]] be reported as app]icab]e. A separate Sundry Notice w~]] be submitted for perforating work done after rig release. No close wellbore crossings w~]l e encountered downhole. A non-freezing f]uid wi]l be left in a]] uncemented annu]i within the permafro interva]. This we1] will be used for injection of reserve pit fluids down the 13-3/8" x 9-5/8" annulus prior o Arctic pack operations. T~l-3/M~._qa~_eg will be a co~ingency~tring to be run only if hole conditions warrant. The 13-3/8" casing s~ring will be set deep for extra kick contro] while coring in the Sadlerochit. 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED ~ ~ ~ TITLE The space below for Commission use ~ Area Dri l I i ng Fngl near CONDITIONS OF APPROVAL Samples required Mud Icg required Directional Survey required ~ APl number ~*ES ~NO ~ES ~NO ~YES ~0 I Permit number ~ , Approval date Y~~, ~~~~3 / . SEE COVER LETTER FOR OTHER REQUIREMENTS ~ '' ~~/~~ by order of the Commission Form 10401 / / Submit in triplicate FORHSl/PO9 ~ sm b.. 2 00 psig@ Surface 5600 psig@ I 1 951 ft. TD (TVD) Federal Insurance Co. 8088-26-27 Amount $500,000 15. Distance to nearest drilling or completed 4-20well 4435' ~ target feet 18. Approximate spud date 10/01/83 2~ //©C~ / PRUDHOE B~ Y ERST DOCK 25 PROPOSED SCYJTH BAY ST PAD 14 Alaska Oil & Gas Cons. Commis}ion 7SED SOUTN BAY ATE PAD AND SCE-B~"" ROAD- JDHO,! BAY UN] T 'H SLOPE BI::~DUGN TATE ~ ALASKA ~, APR. 2006030101 LAT: 70*17'58' LONG: 148' 18'55' ACRE AGE: PAD: 6.' 67 ' ACRES - RO.~D:-' 2; 4 ?-~CRES-:'~:~'::~:cs~r'"~---"'~ V~_UPE: PAD: 57° 600 ¢.Y. ROAD: 19, i00 C.Y~ L~AT]~: 4~' f~, 750' f~_. SEC. 22. TII~RI5E PUrPlE: OIL FIELD ~VEL~N~ BEAUFORT SEA 375 ADJACE~ LAt~ O~R: STATE ~- ~ASKA DATUM: ~.5' AT PAD SURFACE · PAD OR I E NT A T I ON Z150' TO EAST DOCK ROAD--,X, ~ oo' oo' 1,60 '.- · i 460'" ,-[ · Alaska 0il & Gas Cons. ," ' · ~OITIiTIISSIOD SCALE: !" - 150' PROPOSED SOUTH BAY STATE PAD AND Anchorage ACREAGE: PAD: 6. 67 ACRES ROAD: 2. 47 ACRES YOLUI~: PAD: 57,. 600 C. Y, ROAD: 19, I00 C, Y. LOCAT!ON: 400' FNL.. 750' FWt.,. SEC. 22, TI IN-RISE PURPOSE: OIL F !ELD DEVELOPIvENT ADJACENT LAt,~ OWNER: STATE OF ALASKA DATUM: 20. 5' AT PAD SURFACE ACCESS ROAD PRUDHOE BAY UN~' T NORTH SLOPE BOROuGH STATE OF ALASKA 2OO6O30102 . , _ ~4o' . I ,.... zoo' I zo' I UNDERLYING TUNDRA . , __SECTI ON A-A I ,, ROADt 2.4'7' ACRE9 ROAD: 19,, IOO C.Y. :--2= I- -, ,~--_~~-~~~~--: '~~////////~ s._.__ UNDERLY ! NG TUNDRA , SECTION B-B A~:REAC, E, PAD, 6.67 ACRES ¥OLUIVE: PAD= 57,600 C.Y. LOCATION:: 400' FNL, 750.'.FWL, SEC. 22o TIIN---RI5E PURPOSEt OIL FIELD DEVELOPIVENT ADJACENT LAND OWNERs STATE OF ALASKA DATUM: 20, 5' AT PAD SURFACE . . UNDERLYING TUNDRA SEC.T I ON C~C · i · SCALE' 'APPROX. I" - 20' STATE PAD AND, ~" "~' ACCESS ROAD PRUDI'IoE BAY UNIT NORTH SLOPE BOROUGIt .~. STATE OF ALASKA, .~. 2O06030103 ANNULAR PREVENTER BLIND RA~S PIPE RA~S DRILLIN6 SPOOL PIPE RAHS Ala~ka Oil & Gas Con~. Commission Anchoraga 13-5/8" BOP STACK 0IAG~! A~.cumul'ator Caoacity Test ].. C~eck and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure ts 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultane- ously and record the time and pressure re~aining after all units are closed with charging pump Off° Record on IAOC report. (The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. BOP Stack Test Fill BOP stack and manifold with a non-freezing 1 tqutd. Check that all hold down screws are fully retracted. Mark running Joint with predeter- mined plug seating depth. Run test plug on drill pipe and seat in wellhead. Run in lock · dote screws. 3. Close annular preventbr and chokes and bypass valves on manifold. In each of the following tests, first hold a. 250 psi low pressure test for a minimum of '3, minutes, then test at the high pressure. Increase presure to ~~{~and hold for a mtnimm~ o(_ 3 minutes. Bleed p~essure to zero. . _ Open annular 'preventer and close top~set._~f~_ pipe rams. Increase pressure ~ hold f~ at le~t 3 minutes. s~e to zero. Close valves directly upstream of chokes and open chokes. Increase pressure to 5000 psi & hold for at least 3 minutes. Bleed pressure to zero. · Open top set of pipe rams then close bottom set of pipe rams° Increase pressure to 5000 psi below the bottom set of pipe rams and hold for at least 3 minutes. 9. Test remaining untested manifold valves (if any) with 5000 psi upstream of valve and zero pressure downstream. I0. Bleed pressure to zero. Open bottom set of pipe Back off running joint and pull out of hole. Close blind rams and test to 5000 psi for at least 3 minutes. 12. Bleed pressure off all equipment. Open blind rams. Make sure manifold and lines are full of non-freezing liquid and all valves are set in drilling position. 13. Test standpipe valves to 5000 psi. 14. Test Kelly cocks and inside BOP to 5000 psi with Koomey pump. 15. C~eck operation of Oegasser. 10. Record test information on blowout preventer test form° Sign and send to Drilling Super- v i sot. 17. Perform complete BOPE test once a week and functionally operate 8OPE daily. Rev. 5/13/81 SURFACE HOLE D ZVERTER ARCO ,ALASKA SYSTEM INC. SCHEMATTC ~ I0" HYD. OPR. BALL VALVE .,.,/.,..----- V~LL BORE (SEE DETAIL) /" ,,/' ~ I0" HYD. OPR. BALL VALVE / ,//' I ALL 90° TURNS ARE "TEE" ~ I CUSHZON I b ~60' RESERVE PIT AREA NOTE · FLOWL INE DR ILL ING R I SER F 20" 20O0 PSI WP ANNULAR PREVENTOR Valves on diverter lines open automati- 20" cally when the annular ¢C~DUCTC~ preventer is closed. PIPE 1/ I 0" HYDRAULIC OPERATED BALL VALVES "DETAIL" 202601020 CHECK LIST FOR NEW WELL PERMITS Comp any Lease & Well No. ITEM APPROVE DATE (1) Fee (2) Loc thru 8) (3) Admin (9 thru 11) (4) Casg 4~a~~. ~ -,~.~ - ~ (12 thru 20) "(21' thru 24) YES NO , , 1. Is the permit fee attached ....................... ...........,..... .. ~--.~ 2. Is well to be located in a defined pool .......... 3. .Is well located proper distance from property .... 4. Is well located proper distance from other wells ....... 5. Is sufficient undedicated acreage available in this pool . 6. Iswelltobedeviatedandiswellboreplat~?l~?~[[[.iiiiiiii[. 7. Is operator the only affected party ....... ' ..... 8. Can permit be approved before ten-day wait .................. ~.~ . 9 Does operator have bond in force ~'t_-- · a .................................. 10. Is a conservation order needed ...................................... w ~ 11. Is administrative approval needed ................................... 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25· Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ..... Will all casing give adequate safety in collapse, ;g~;i;~'~ ;g~;[l Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............. Is adequate, well bore separation proposed ........................... Is a diVerter system required . ....... Are necessary diagrams of diverter Does BOPE have sufficient pressure rating- Test to Does the choke manifold comply w/API RP-53 (Feb.78) .................. Additional requirements REMARKS · ~ 0 ~Z ~-~0 I INITIAL ' GEO. UN'IT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX~ .. No 'special'effort has been made to chronologically organize this category of information. ~9 ~1['-"1~ r J 1 ! liil ! I:-ti[.~ [~1 ~T il ~'~: i1.1 2 I- ~T 17 i 9 0 0 pi_ 0 0 § ~T t~ . ~_~LL a. _ _ l .__ I I 1,2 I I ia, · - ! t ~? .59 0 ¢i~. ' 0 0 I 1 - . . ~LL ,¢ 2..' 6 ¢ ¥. 1 II . ~ . . 2.77 5' t ! I _ -% ~ ~ ~ ~ .. . - ~'t ii..I ~'-* ~'~ ~'- ~ ~ i . .--._ ~_ -'-- ~T - ~P ~T Cz. _~,, RTL A~,~. ? :'~ ~Z ~? T ? 7 ? --Il' l I l - ~ . ~. I I ~ ~ ~ ~ ~ .._ ~__.~ ._~ . . -j - _ I . ~'~ 16~1 ~*~ I!-~ !ag ~.'~ .~- II.~. ~.~ ~ ~ ~ a 11-*I~ !~.8~- - _ ' 0 i~ - '- ..... ~ ' ~ ~ -:~ _ - ~. ~ ' , _. ~ I~ l~--' ~.~- ~., .~a ~?~ ------ . - . . . !~ ~-- I a ¢i-- -' ..... '-" - ~ ----- '- --~ I ! - ! ~? ~U © >~.' I,I.~ 1,17 1,!7 U~UL !. i 'T 1.1T !.I~ 1,27 , ~T I*! ? 1.i~ 1.17 1.16 1.I~, . ,~- !.i6 1.t. 6 6~ ~T L II,."~ ~ II 1 i il iI~ ti I ;-11 -_ TAPE VERIFICATIF)N ,' , [,VP 010,H02 VERIFICATION LT,qTING SERV]'CE NA~E {EDIT DATE :84/02/24 ORIGIN TAPE NANF, {89,50 CONTI~ATION ~ :01 COMMENTS :TAPE COMNENTS FILE NAI~ :~D[T ,001 n~T~ : MAXIM[]~ LENGTH { 1024 FILE TYP~ PREVIOUS ~* INFORmaTION RECORDS MN~M CONTENTS CN RANG: TOWN{ CTRY: aRCO A~,ASKA INC sr)uTH ~AY STATE PRU~DH()F BAY 15~ 11. N N , SLOPE UNIT TYPE C&TE SIZE CODE 000 000 016 065 000 000 018 065 000 000 0i2 065 000 000 004 065 00o 000 004 ,065 000 000 002 065 000 000 008 065 000 000 006 065 000 000 004 065 LVP OlO.g02 VERIF,IC~TI~N LTSTING P A C;,F, 2 C~MPANY = ATLAflT]C RICHF~EI~D COHPA~Y WgLI,, : SO~ITH BAY STATE ~1 FT~LD = PRUDH[I~ BAY COI,I~TY = N~RTH SI~OPP~ BOROIJGH STAT~ = ALASKA ~UN ~.4 DfiTP~ [.,DGGE, r.I 17 I,.~,C 83 L~P~ J, Krlf"IRT~IG CA,ST~G = 9 6~5" [a ~816' - BIT STZE = 8,5" TO 9970' TYPE WI,HID = o~I,, BASE MIID DENSITY = 9,7 I.,B/O R~ = NA V~SC[1SITY = 70 S R~F = HA P},t = N~ ~MC = NR FLUID LOSS = 4.4 C] R~ ~T BHT = NA LVP OIO,HO? VPCRIFIC~TIF]N LISTING SCHblINBERGER TOOI,$ LOGGED ON RI.iN FOIIR: DI,IAb ]NDUCTII}H ~PHERICAI, LY FOCUSE~D LOG (DI[,) Y, ITHO DENSITY COMPENSATED LOG NATURAl, ~A~MA TOOL (NGT) , , , , , , , , , , , , , , , , , , , , , , , , , , , , $ ************************************************************************************ NUMBER AT ACC~ 6~950 bOP: TYPE FLIITD DENSITY 9 625" 8 88t0' - BIT SIZE = 8,5" TO 9954' {)iL BASE 9,7 LR/G 25,0 $ ~TRIX I, IM~$Tr)HE ******************************************************************************* , , , , , , , , , , , , , , , , , , ~ , ~ , ~ , , , , ~ ~ ~ , ~ JOB N~M~?R AT ACC{ ,';8931 RUN. #?, .DATE I,f~GGEI:.)?, 3 NFIV lg93 TYPE FLUID : D~]NSITY = 10.7 I.,~/G R~ = ].24 e 6B.0 DF v~scos~v = ~o.o s R~ = DH = 7e8 R~C = 3044 ~ 68'0 DF FLUID bOSS = * DUA6 INDUC?IDN SPHERICAI,I,Y FOCUSEr) [rOG fDIL) $ [,VP O10,H02 VE~.[FIC~TIOa [.,IST[NG PAGE 5 BOR.F.,HC)[,D~ CO~PENSAT.F..D [,O¢; ([~HC) * I.,ITH~ DFNSITY CnNP~ISATED I~OG ([,[)T) ,,lOB ~JI,/~B~':R AT ACC% 689]0 CASING = 13.375" a 3781' - HIT SIZE = 12.25" TO 8320~ TYP~] F[,l.llD = [,~]GhlOS[II.,FONATE ORN~9'Y = 9,8 LB/~ R~ = 1.93 0 68.0 DF V!SCO,SITY = 37.0 S R~F = 1.96 ~ 68.0 OF H = 11 0 R~C = 1.70 a 6B,O OF , ** **,,,,, **,, *****__ ********************************************************** ****************************** * DUAh INDUCTIOh 8PHERICAI,,I~Y ~OC[.I~3[3 brig BOREHOI~E COMPENSATED LOG (BHC) T, VP ~IQ.HO~ VF. RIFICATION I,I'$TING P~ESENTED M~RGED ON THZ~ LIS TAPE. ENTRY BLOCKS TYPE SIZE R~P~ COI')E ENTRY 4 I 66 1 ~ 4 73 6O 9 4 65 ,lin 0 1 66 0 DATI,.I~ SPECIFICATION BLOCKS ~N~ SE~VZC~ $~RVICN UNIT API AP1 AP1 APl FILE SIZE PROCESS SAMPI, E REPR [~ ORDER # ~ LOG TYPE CLASS Mnn NO, bEVE[~ CODE FT 0 0 0 0 0 4 r)HM~ 7 0 0 0 0 4 OH~ 7 0 0 0 0 4 OH~4~ 7 12 46 0 0 4 ~V 7 1. 0 0 0 4 Ua. PT 7 3.1, 32 0 0 4 I.)$/F 60 52 )2 0 o 4 ~API 60 31 32 0 o 4 PH 0 6 $ 2 0 0 4 (;/C3 0 44 0 0 0 4 0/0.3 0 35 1 0 0 4 CP~ 0 34 9~ 0 0 4 CPS o 34 03 0 0 4 IN O 2g 3 0 0 4 0 4~ { 0 0 4 o 0 0 0 0 4 0 o 0 0 o 4 GAP! 0 0 0 0 0 4 GAP! 0 )1 32 0 O 4 OHMM 0 0 0 0 0 4 o~m~ 0 0 0 0 o 4 0 H m .v 0 0 0 0 0 4 T :4 0 2~ ] 0 0 4 (;,,APl 0 31 32 0 0 4 Pt.{ 4? 60 2 0 0 4 69 68 68 66 6~ 68 68 68 68 68 68 68 68 6~ 6.8 68 68 68 68 68 68 68 68 LVP 01. V~PIFICAT'[ON I,ISTING G/C3 4~ 44 0 0 CPS 42 34 92 0 CPS 42 34 93 0 IN 42 2~ 3 0 42 42 I 0 42 (' 0 0 GAPI 42 ~ 3~ 0 PP~ 0 0 0 P~ 0 0 0 0 p(I 0 0 0 0 GAP! 0 0 0 0 GAPI 0 0 0 0 US/F 0 52 32 0 US/F 0 0 0 0 GAPI 0 31 32 0 F)~PT SP NPH][ FCNI~ P~,TF LbS NDHI FCNI., 9098 -qqo 0 3275~ -999' -999 10~ -09o 5000 7500 73~4 0000 6758 2500 2500 2500 ~500 0625 7500 9900 0000 -999:2500 0 ~990 8351~7500 6.882~ -999,7500 0 '?~4 8n4g:oooo 1,9 9511 19,5908 9800 noo0 -099i7500 15 ~?0 20R2,0000 5,q102 -099 ~500 1,6:0156 2088 0000 23i~417 24 ~91 SFLU ~R DRHD DRHO CALI THOR SGR SFLU (;,R ORHn I,LD DRHO CAt,][ THOR SFI,IJ DRHO CALl. L L D THOR -999 2500 -999 2500 3 4238 8 5000 373 000o -999 2500 -990 2500 -999 ~500 tn 6719 373 0000 1848,0000 14,9,453 0,0206 8,5491 21.4375 -999 2~00 0 0034 8 4219 0 2734 21 4]75 I DT NRAT GR CALl RHOB NRI~T UR~N PT ILM DT RHOB NRAT CAI, I RHOB NRAT URAN DT 1848 0000 20!7188 DT 0 0483 RHOR ~.6328 NRAT 26,9687 -999,7500 CaLl 0 0549 RHOP ?°45?O ~6,96~7 DT 0 4 0 0 4 0 0 4 0 0 4 0 0 4 0 0 4 0 0 4 0 0 4 0 0 4 0 0 4 0 0 4 0 0 4 0 0 4 0 0 4 0 0 4 0 0 4 0 :~99 2500 II.,D 9912500 GR 4,6563 NON6 0,9482 RNRA -999,7500 -999,2500 -999,2500 NCNb -99q,2500 RNRA 31,406] POTA -999,2500 OTb 742,5000 IhD 50,0625 GR 2,6985 NCNb 0,8981 RNRA -999,2500 ~SF[., -999,2500 GR 2,6759 NCNL 0,944] RNRA 2,3784 POTA 51.,0752 D'rL 1,6 8750 ILD 62!6250 GR ~ 6191 NCNL 2,0488 RNRA -999,2500 ~SFL -999.~500 GR P,6055 NCNb 2.0957 RNRA 0.2539 DOTA 63,1750 nT[, PAGE I 68 I 68 I 68 1 68 I 68 1 68 1 68 ! 68 t 68 1 68 1 68 1 68 I 68 -999 2500 -9992500 32752 0000 1 0000 -999 1500 -999 500 -999 2500 -999 2500 3 8086 -999 2500 863 0000 14 9453 7880 6875 0 9434 =999 2500 -999 2500 7748 0000 0 9624 -0 0084. 51,4492 6953 7188 4600 0000 2 2090 -999 2500 -O99,2500 4400 0000 ?:1055 0,8]01 6],8750 VERIFICATION L,T,$T lNG O~PT ~700 909 SP NPHI 1 FC~I, 6076 LI, S -999 NPHI 2 15 ~0000 .0019 1973 nRHO 0000 511t THOR ~146 SGR ,R~40 1,739.0000 I[,~ 0.6172 DT 8,6797 N~AT 16 2813 -99qi2500 -0 01,51 8 6710 NRmT 16.281] DT DEPT 9600 SP -999 NDHI 0 FCNIi, 672~ pfF 6 L[,$ -qgg NPItI 0 ~R 10 CGR 5 GR 10 0000 SFLI! 7500 G, 5t71 DRHO 0000 CALI 25t9 SGR 8789 DRHO 0000 Cal, I 6641 THOR 8359 SGR ~172 17t9 9 11 -990 9 0000 1875 0117 11594 NRAT 2344 GR 2500 009] 3047 N~AT 2010 2344 DT D~PT 9500 Sp -999 rCNI, ]664 bll,~ -999 NPHI 7 FCNI~ ]432 GR 17 CG~ 5 GE 15 0000 $ F L U q570 DRHD 0000 CAI, I 9297 2500 I.LD 4707 DRHO 00OO CA[,I q062 THOR 5781, ~4R78 184~ -0 9 17 -990 -0 9 0 17 0000 7578 DT 0122 7422 NRAT ]7,,81 GU 2500 ¢tLI 0029 ~}.tflB 1719 NRRT 6016 IIR~N 3281 DEPT SP NPHI rCNL P~r N P H I m'CNI, C. GR q400.O000 SFLU -099.7500 GR 2.9297 DRHO 5~0508 SGR -gqg.~500 t, bn 4,o0~9 DRHO 4936.0000 CILI 1.7.9~44 THOR 11,7714 SGR 15.0]13 1848,0000 Yl,~ 1q.8750 DT -0.0269 EHOB 8.6797 NRRT 16.~125 CR -9~9.2500 CALl o.0015 RHOB 8.7266 NRAT 2.~797 [J~A~3 16,8125 DT n~PT SP NPHI FCNL 9100.O000 SFI, U -099 2500 GR .115~.no00 CIl, I 1.739.oo0o IT,~ ]4.0000 DT 8.6182 NR4T 123.a125 54,8125 GR 2.6680 NCNb 1.061.5 RNR~ -999.2500 -999 2500 GR 2~6426 NCNI,, 1,1562 RNR~ 1,8H18 55,4661 DTb 335,0000 ILD 51,0625 GR 2,6777 NCN[, 0,q863 RNRA -999,2500 ~SFh -99g,2500 GR 2,671q NCNb 1.0410 RNRA 0.6401 POTA 51.8594 DTL 21.3125 IIi, D 60.0000 GR 1 4697 ~NRA -99022500 ~aFL -999,2500 G~ 2.6191 NCNb 1,56]5 RNRA 1,tgi6 POTA ~60,]555 DT5 174,0000 lbo 54.9]75 2,6543 NCNB '1.2178 -999,2500 MSFL -99q.2500 GR ~,6660 NCNB 1,2949 RNRA 0.6572 POTA 55.0000 OTB 10.7500 63.1750 GR 2.62~] NCNB 1.5494 65 8125 9 6172 6820 0000 I 1221 -999 2500 .999 2500 ~368 ~0000 t 5 0 146 953 55 9321 159 8750 it 1875 7000 0000 I 0400 -999 2500 -999 2500 6508 0000 I 0078 0 0000 52 0718 17 3438 12 7578 740 0000 5664 994 2500 -999 2500 5320 0000 I 5498 0 ~441 59 0742 147 0000 19 8750 6]04 o000 I 2529 -999 2500 -999 2500 6404 0000 I 2969 0 0977 54 5000 18,9219 34.0000 4938,5000 11.5750 t, VP 010,H02 VERIFICATION NPHI GR 4 5002 -qgg 2?86 0000 31 ]594 22.0469 35.59]8 SC, R LbO THOR DEPT SP NPHI NDHI ~¢NI., GR 3166 4 -gq9 10 2414 25 24 nooo ~500 0.$14 5000 1147 ~500 ~051 O000 8750 1'758 q375 SFLU DRHO C~!,I SGR I, LD DRH[~ C~L I THOR SP NPHI FeNL GR 9100 0000 '9991~500 ~ 5552 3]~6 0000 4 ~500 ' 9 1'309 280?°0000 26,?187 7.3398 ~6,1~50 $~'I,U GR D R H 0 SGR DRHO CAi,! THOR DEPT SP NDHI rCNL PEP NPH I FCNL CGR GR o00OOoO 999:~500 a.l]90 35'16 5000 4in327 -qqq 2500 ~5,~641 0,7969 11,~437 SFI, U fir DRHO DRHO C.~LI T H OR SC, R DEPT $P NpHT FCNI, NPH! FCNL -gq9 ~500 3817.0000 5,9297 -999,7500 R.4~73 269n.nO00 3~,4375 -0.]o47 GR DRHO CALl SGR LLD DRHO CAI,I THOR I~ISTING 35.3848 CR -qqq.2500 CALI -0.0015 RHO~ fl 632~ NR~T 2i0840 ll~hN 35 ]848 DT 184R 0000 22 0625 -0 0016 8 7813 26 5283 -9gq 2500 0 0171 8 7109 0 0859 26.528] 1730,0000 25.4375 -n 0052 8 770] 3o 3340 -999 2500 -0 0010 8 6797 0 5732 30 3340 1072 0000 12i5625 -0 0167 8 648] 14 5400 -909 2500 -0 0005 ~ 6~50 0 14 5400 ILM DT RHO8 NRAT GR CALl RHOP NRAT [IRAN DT DT RHOB GR C~LI HOB NR~T DT 1072.0000 ~1.,4688 DT 0.0220 8,7~1] NRAT 2~,~125 GR -9g9,2500 0,0015 ~,7500 NRAT 24.~125 -999 2500 MSF[, -999:2500 GR 2.6191 NCN[., ..7510 RNRA .5195 DOTA 62.8750 DTL 24. 125o IbD 6.4:1250 GR 6398 NCNh :5697 RNRA -999,~500 ~SFL -999,~500 GR 2,5996 NCNb ~.7090 RNRA 2,76~! PDTA 64,0O00 DT~ 51 5625 I[.,D 63:8750 GR 2,5793 NCNb 1,4705 RNRA -999,2500 ~$Fb -999,~500 GR 2,5664 NCNb 1.6357 RN~A 2.7275 POTA 6].2500 OTb 106.6875 ILD 63.5000 GR 2,5208 NCNb 1.5655 RNRA '999,2500 ~FL -999,2500 GR 2,5332 NCNb, ~.6~52 RNRA ~.6299 POT~ 6],6250 Drb 106.6~75 ILD 60.9375 GR 2.6113 NCNb t.3154 RNRA -999,~50~ MSFL -999,2500 GR 2.5488 NCNI, ~.9766 POTA 60.8047 DTL PAGE -999 ~500 .999 493~ 0000 i 7695 0 8316 62 ]750 17 5000 22 0625 5073 0000 1 6010 -999 2500 -999 2500 3904 0000 1.6172 0,1786 63.6250 51,0625 25.4375 4876 8750 4841 -99 2500 -999 2500 4556 0000 i 6260 0 2791 62 8750 76 2500 12 5625 5783 0000 I 6169 -999 2500 -999 2500 5548 0000 1,6309 0,059~ 63,0000 104.~250 50 0000 1.3281 i999,2500 -099.2500 4o28.0000 1.4922 -0 0488 61:2266 [~VP 010,H02 ¥I<RIFICATT,,ON [,!STING GR ~t,77~4 DEPT NPHI ~CNL 3R8 ~ 45 CGR -gq9 nOOO :75d0 GE OO2O 6094 ~759 LLD 3340 DR~O ?~00 ~tR7 THOR 2500 9297 D~PT 8Zooinooo SF[,.,U SP 28 5000 NPHI 29 0039 sc. 1 !. 9001 LLD GR -999,2500 THOR GR -999.2500 DEPT NPHI FCNI., PEF h Ir, $ NPH I F'C, NL DEPT SP NPHI t, L S NPH! I~CN L CdR GR 8600,O000 SFLU -~4,2500 22,6563 11,~1.0000 6.0098 80,97R0 -909,7500 DEMO -gOq ?500 THnR -900:2500 SGR '999.2500 8500,n000 SF[..U -35,5000 qR 21.0449 ~RHO 1320,0000 CAI. I 5.5117 SGR 22,2914 LLD -99q.7500 DRHO i qqq.2500 CA[,I 999.~500 THOR gqg,~500 SGR -099,~500 8400 no00 -101 0000 16:2598 ORHO 1695,0G00 CAI,! SP NPH! 3 0625 79:8125 PT 0,0557 8,9375 -g99.2500 UR 3.6012 -0,620{ RHOB -990.2500 -ggg.2500 PT 1,1 8437 60 2187 -0 0229 8 1797 -999 2500 11. 1,844 -999°2500 -qqq ~500 -990i2500 -qgg ~500 II,,M DT [~HOR NRAT RHOR NR~T IJRAN 9375 1~1250 PT 0298 8:5313 NRAT -909.~500 (;R' ~6,1779 -999.7500 RHAB -999,~500 NR~T -999.2500 DT 0,1250 ~4,8125 -0.0459 8.6406 -999,2500 28 4584 -qqg ~500 -999 2500 -gq9 2500 -999 2500 44q,OO00 16,8594 -0.0444 8.4531 RHOB N~AT CAL! NR~T (1RAN DT DT NR~T 3,2207 TLD 82,3750 GR 2,6055 NCNh 2.5781 RNRA 1,0625 MSF[, 87.7070 GR 3,8438 RNRA -990,2500 POTA 85,{66] DTb 10,6053 ILO 85,2500 2.4766 NCN[. 2.6484 RNRA 71.,0625 7,0391 GR -gq9 2500 ~CN[, -999~2500 RNRA 990.2500 P(1TA :999.2500 DTL 4~.5625 94,0000 GR' 2 NCN 9 RNR~ 40,R750 ~SFL 7,3086 OR -999 2500 NCNb -999~2500 RNRA -999.2500 POTA -909,2500 DTL 29,8593 ILD 79,9375 GR 2,3984 NCNb 2 1562 RNRA 29:7656 MSF[., 7.578t GR '990,2500 NCNb '099.2500 RNRA '999,2500 POT~ -990.2500 DTL 255.0000 IhO 83,1875 CR ?.2~13 qCNh 1.8103 ~'~P~ 3.0703 79,8125 2476 0000 2 8770 3 2~1) 74 7500 1472 0000 3 7852 -999 2500 86,0469 9 9766 60 2187 251~ 0000 8203 16 4219 86 3750 -999 °o .999 2500 -999 2500 56 9687 41 1250 285~ 0000 4805 57 9375 37 0038 -999 00 -999 2500 -999 2500 2~ 2656 4 0125 2906 0000 2 2012 49 2760 46 3125 -999 2500 -999 2500 -999 2500 -999 2500 427,2500 16,~594 3284, 000 1.9365 [,vp O.lo,HO2 VE.I~Ip'ICATTON LI$?I~OG -099.2500 -999 ~500 -909i2500 Ti{OR -999 2500 SGR -999 2500 -999,2500 GR 717.7867 C~L! -999 2500 rHO~ -999,~500 PRAT -999,2500 DT D~,:PT SP PF..F N ? }..I T 8300 nO00 SFI, U =2] 9844 50 3418 ORHO 355 2500 ~ 4.453 6 4126 LLD -999 2500 D~HO -099 2500 ~,LI i909[ ?500THO~ 999'2500 ggg 2500 5,4648 166,3750 DT 0,0034 15,6016 NRAT 5,9158, C~[,! -q99,~500 RHOR -999,~500 NRRT 'qgg,~500 IJRAN '999,2500 DT DF',PT SP FCN[, PEr LbS NPHI FCNL R~OO nO00 8FI.,I,! 2417813 - 99~2500 CAL! -999.2500 SGR :gggi~500 gq9 2500 DRHO -OOg 2500 THO~ -~99~2500 SGR -g99,2500 7 4375 212 6250 PT -g99 2500 RHnB -999 2500 NR~T -999 ~500 GR -9992500 -909 2500 ~HOB -999 2500 -~99 ?500 - 99~2500 DT OF, PT ~P FC~I., LL$ NOI,.IT FCML Gr CGr 81oo oooo srL , -27:5000 -999,2500 DRHO -990,2500 -999.7500 SGR -009 7500 ~Ln -909i7500 DRFtO -090 2500 CAI, I -q99.2500 T}{OR -gqg,~500 SG~ 8,J. 328 TI,~ 115,1250 DT -999,2500 ~HOB :999,2500 ~RRT 99g,2500 '999,2500 Cal.,! '909~500 ~AT '99~,~500 t!RAH '099,~500 gEPT SP NPHI FCNI. PF.F bLS NPHY G~ CUr nnO,nOOO -24 0t56 GR 99o]2500 2qgq,2500 CAt, I 99q,2500 SGR '099.?500 'q99.~500 DR}lQ -999.250{) CA[.] -000,?500 THnR -qqg,~500 5,6641 TL~ 156,7500 DT -99q.2500 PHOB -gq9,?500 ,RAT -ggg,~500 ~R -999,7500 C~[.I -009,~500 RHOB -ggq.?500 {IRAN -ggg,?500 ~T i6.1406 7,3711 GR -990 2500 ~{CNI~ -ggg'~O0 RNRA ~ , -999,2500 POTA -~99,2500 DTL 4 7695 ILD 2,2{87 ~CNb 4,1992 RNRA -ggg,2HO0 ~CNI~ -999,2500 RNRA -99q 2500 PO?A -99922500 DTb 5 222] TLD 114,0000 ~r -gga,2500 NCNb '999,2500 RNRA -999,2500 MSF[, -999,2500 GR '999,~500 ~CN[,, -999,2500 RNR~ -999,~500 PilTA -999.2500 DTh 4,~914 10~, 375 GR "099'~500 NCNb -q99,2500 RNRA -999,2500 GR -999.2500 NCNb -999,2500 ~N~A -999,~500 POTA -999.2500 DTL 3.59]8 ILD 102.5000 GR -99q,2500 NCNb -999,2500 RNRA -999,2500 -999.2500 -999.2500 RNRA -999.2500 PF!TA PAGE 11 8 109 -999 2500 -999 2500 -999 2500 -999 2500 4 52]4 ~64 0000 1561 0000 4 3906 6 ,55 ~7050 -999 2500 -999 2500 -999 2500 -999 2500 5 1250 212 6250 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 4,20]i -9 ,2500 -999 2500 -999 2500 -9992500 -9992500 -9992500 -9992500 .99925O0 3,35t6 t56,7500 -999.2500 -099 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 x bVP 01,0,HO2 VEr:~'[FTCATInN NPHI bLS NPI,t I ~R 7200 -999 2500 4.8320 129.8750 DT -990.2500 -qo9.7500 -999.2500 -999 ;500 -999 2500 -Q99 ?500 [;RAN -gg9 ;500 DT OEPT .PHI FCNL PEK NPNI GR GR 7~00.0000 SFI,,i} -25,5000 'OOO,~500 DRHO !099.~500 CALI 999.~500 999.~500 'ggg ~500 '99917500 CAT.,T -090 7500 TH~P '099 ~500 -999.2500 2 6348 ll,,M 1.59:7500 DT '999.~500 NRAT '99g.2500 CR -999.~500 CAIn! -999 2500 ~HOB -9991;500 N~T -999 ;500 URA[~ -ggg 2500 DT ~PT NPHI WCNL NPHT rCM[, Cna 7700 0000 SFLU -24 ~000 -999 2500 f)RHO -999 ~500 -999 2500 SGR -qg9 ;500 ?500 THO~ '9~9,2500 2 3535 I[,M 151 5000 DT -g9g -999 -999 -oqq .qqg -9qq -999 25OO ~500 9500 CAb! 2500 NRAT ~500 U~AN 2500 DT D~PT SD NPH! FCNI, tLS NPHI rCNI., 7600.0000 SF[,U -24.7656 -999.7500 ORHO -909.2500 CAI.,! -099.7500 $~R -09q.2500 I. LD -099.~500 DRHi:) -9g9.2500 -~g~.2500 THom -q99.~500 -o99.7500 2,2:)24 II, M ~6.4375 PT '999.;500 999.2500 NR~T 999.~500 GR 099.;500 CALl 999.2500 N.AT 90.2~00 DT F)EPT NPH I 1 6064 66:4375 DT -9qq ~500 -999:2500 2 4.629 80:81;5 GR -999.2500 NCNb -999.9500 RNRA -999.2500 ~SF£, -909.2500 GR -999.~500 NCNb -999. ~00 RNRA .990 2500 -~9912500 DTL 1,4746 101.]i25 Gm -999.2500 NCNh -999.2500 -999.2500 -999.2500 GR -999.2500 NCnb -999.~500 mNRA -999.;500 POTA -999.2500 1 48]4 ILD -999.2500 NCNb -999.2500 RNR~ -999 2500 ~SFL -99q!~500 GR -999 500 NCNG -999.2500 RNRA -999.2500 POT~ -999.9500 DTL 2.0957 ILD 95 4375 GR -999:2500 NCNb -999,~500 RNR~ -099.2500 ~$F[, 299~,2500 G~ 999,2500 NCN~ -999.~500 RNRA -999.2500 POTA -999.2500 DTL 1.4980 I[,,D 97.8750 Gm -q99.~500 NCNh -999.2500 ~N~A PAGE 12 2 4473 129 8750 -999 2500 -999 2500 -999 ~500 -999 500 -999 2500 -999 2500 -999 1500 -999 500 1 2949 -9 0 -999 ~500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 I 3584 151 -999 500 -999 500 -999 500 -999 ~500 .099 500 -999 2500 -~99 ~500 ~999 2500 2 0176 86 4375 -999 2500 -999 250O -999 2500 -999 2500 .999 2500 -999 2500 -999 2500 -999.2500 1,4404 66.4375 -q99.2500 -999.~500 [,VP OlO,H02 YERIFICATION [,ISTINC, PEF -9q9.9.500 SGP [,[,$ -qgq. 2500 I, LD FCN[., -999. ~500 CAI,I ~ -~9~ 2500 ,HO~ -999~7500 -999 2500 -999 2500 CAI,! -999 ?500 RHOB -999 2500 -999 ~500 DT D~PT 7400 0000 SFLU Sp -24.~7031 NPHI -999,2500 DRHO FCNI,, -999 2500 P~F -999:~500 bbs '999,9.500 NPH! -999,~500 ~RHO '999,7500 -q99,~500 2 5801 ILM -999 -9Q9 -999 -999 -999 -999 -999 -999 ]750 PT ?50O RHOB 2500 NR~T 2500 GR 2500 Cmb! 2500 RHRB 25O0 NR~T ~500 URAN ~500 DT r)EPT sp Npx! FCNI~ PEF NPH! FCNL CC, R , 7]00 OOnO SFI.,.I -9.5.0000 -9~9.7500 DRHO 'gq9 ~500 CALl -999 ~500 'q99 2500 bbD -999 ~500 DRHO -999 ~500 999:~500 -90~.2500 2 1152 76 0000 DT -999 ;500 -999 ~500 NRAT -999 2500 -999 2500 -999 2500 -999,~500 NR~T -999,2500 I..IRAN -999.~500 DT DEPT NPH! FCNL LbS NPHI FCNL 7~00 0000 SFI,U 09:~500 CALl -999.'~500 SGR -999 ~500 -00~,2500 C[[,I -999,2500 THOR -099.~500 SGR -999,~500 2 4512 IbM 1,08 6250 DT -9gq 2500 -999 2500 -999 ~500 -909 2500 CAI,! -999 ~5()0 -999.~500 -990,~500 [{RAN -999,2500 DT DEPT SP NOH! FCNi., bLS ~CNL C~m 7100.0000 -38.7188 -099,~500 DRHO -gqq,2500 CAI,! -999,?500 -999.2500 -990,7500 DRHQ -999,7500 CA[,[ -o99.~500 -099.7500 99 0000 DT -900:2500 RHOM -909,2500 WRAT -o09,2500 GR :q99,2500 NRAT 999,~500 {;RAN -999,~500 DT -999,2500 NSFb -999.2500 ~R -gqg,~500 NCNb -999.2500 RNRA -999.~500 POTA -999,2500 DTL 2.g871 It, P 100, 6~5 GR' -999,2500 NCNb -999 2500 RNRA -999:2500 -999,~500 GR -999,~500 NCNb -999.2500 ~NRA -999,2500 POTA -999,~500 DTb 0000 GR -999.9500 NCNb -999.2500 RNRA :999 ~500 MSFb 999:2500 GR 999 2500 N,CNb 299022500 R~RA -999 2500 -999:2500 2 4453 TLD 99:6250 GR -990,2500 NCNb '099.2500 RNRA -999,2500 ~SFL -999,2500 GR -999,2500 -999,2500 RNRA -999,~500 POTA -999,2500 DTL 3,3926 ILO 98,0000 GR -999,2500 NCNb -999,~500 RNRA -990.~500 MSF[, -999,~500 GR -999,~500 -999,2500 RNRA -999.2500 -9g9,2500 DTL -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 2 2246 8~ 3750 -99 2500 -999 2500 -999 ~500 -999 2500 -999 2500 -999 ~500 -999 1500 -999 500 I 8477 76 0000 -ggg 2500 -999 2500 -999 2500 .999 ]500 -099 500 -999 2500 -999 2500 -999 2500 2 4805 -99 O0 -999 2500 -999 2500 -999 2500 -999 ~500 .999 2500 -999 2500 -999 2500 3 3125 99 0000 -999 2500 -999 2500 -999 2500 -999 ~500 -999 500 -099 ~500 -999 25OO -999 2500 LVP oln. Ho?,. V~RIFICA?IO~J LISTING -999,2500 2.4512 II, M 91.1250 DT 29o9.25oo ~HO~ 999.2500 NRAT -990.2500 GR 99.2500 RHOB -999.~500 NRgT -999,~500 URRN -999,2500 DT DEPT ,i~00.o000 5P ' 35.7813 NPHI 99'9.2500 DRHO FCNL 099 2500 CALl PEF 999i2500 L[,$ 999 9500 NPHI -999.2500 DRHO ~CN[, -999 ~5()0 GR '999i~500 THOR CGR -999 ~500 -999 2500 3 0117 -999 =909 °999 -999 -999 -999 -909 5625 DT 2500 RHOB 2500 NRAT 2500 GR 2500 C~t,I 2500 R~OB 2500 ~500 I.IR~N ~500 DT D~PT 6800 0000 5FI,U sP .]4:o]~ NPHI -999.~500 DRHO FCNL -909.~500 51,5 '999.~500 NPHI '999 ~500 DRHO WCNI, -o49[~500 CALl GR -99q ~500 TUOR CGR -999 ~500 · GR -~99.7500 3789 ~ J,,,~ 61 -9gq -999 -099 -999 -999 -q99 -999 -999 5000 DT 2500 RHO~ ~500 NRAT 2500 ~ 2500 CILI 2500 ~HOB 2500 N~AT ~500 DT D~PT 5P NPH I FCN L PFF NPlt [ FC~L C,R 6ZOn.nOOO SFLU 4].03t3 -999.~500 -009.2500 LLD -090.~500 DR[tO -999.2500 -490.~500 -~99.2500 -990.~500 2 7871 I[jM 68.4375 DT -999.~500 RHNR -999.2500 NR~T - 09 ?500 .92:~500 -99q,~500 -g29,7500 DEPT SD NDHI FCNI, 6600,0000 5FLI.! -48.2913 CR -094.2500 {)RHfl -999.2500 CALI 2.7480 91 1750 DT 900 2500 NR~T 2,4395 101,,4375 GR -999.2500 NCNb -999.~500 RNRA '929 2500 -999i2500 GR -999 ~500 NCNI,j -999.2500 RNCA -999.2500 PO?A -999.2500 DTL 2 7422 99i5625 GR -999 2500 NCNI,,, -999 2500 ~NR~ -999 2500 -999:~500 GR -999 2500 NCNb -999:2500 RNRA -999~7500 POTR -999.2500 DT~ 2.4980 IbP 94.8125 GR =990.~00 NCNb -999. 500 RflRR -990.2500 MSFL -999.2500 GR -999.2500 NCNL -999.2500 ~N~ -90g,7500 POIA -999.2500 DTL 2,9453 ILD 93.1875 GR -999.2500 NCNL -999.2500 RNR'~ -92Q,2500 GR -999,~500 NCNL -994.2~00 RNR~ -909.~500 POTA -999.~500 DTL 3,5f170 II, O R3.0oO0 ~R -994.2500 NCNI, =994,2500 RNRA 91 -999 -999 -999 -999 -999 -999 -099 -999 PAGE 2 5762 1250 2500 2500 2500 2500 2500 2500 2500 2500 2 7246 87 5625 -999 2500 -999 ~500 -999 500 -999 2500 -999 ~500 -999 500 -999 2500 -999 2500 2 4238 6~ 5000 -99 t500 -999 500 -999 2500 -999 -999 500 -999 ~500 -999 2500 -999 2500 2 9609 68 4375 -999 2500 -999 2500 -qoq 2500 -999,2500 -999,2500 -999.2500 -999,25~0 -999,2500 3 3457 9J:1250 -999,2500 LVP 010,HO? VERITICAT[flN LIS?ING NPH 'Il. -009.7500 SGP -o99.9500 LLD -99o.7500 DRHO -999.7500 THO~ '999.2500 SGR -999.~500 ~99~ ~500 999:2500 CaLl -999.7500 -990,~500 -999 ~500 I.IRAN -999:2500 DT DEPT NPHT ~CNI, PET ~PHI Cgn 6500. 0000 STLU -85,5625 99,2500 CaLl -999,2500 '999 ~500 .o99.~500 Clt, I ~999~'500 T,O" 999 2 7031 49 031] DT -OqO 2500 -999 2500 ~AT -999 ~500 -999 2500 CaLl -999 2500 -999 ~500 -999,7500 PT DEPT SP NPHI ~CNI, PEF NPHI ~CNL 6400.0000 SFI,U -909.2500 -ggg,?500 -090,~500 [,,I.,D -009,2500 DRHO -999.~500 CAL! 999.2500 SGR 3 2949 ILM 34 7500 DT -099 ?500 ~HO8 -909 2500 N~AT -999 ~500 ~a -999 ~500 CaLl -999 ~500 R}.IOB -999 ~500 NR~T -999 ~500 [IR~N -999,~500 DT D~PT S? NPHI ~CNt, NPHI ~CNI, GR ~300,O000 8Tl,,II 110,56~5 GR -909,~500 DaHO :999 2500 C~LI 099~500 SGR -099.2500 LI.D -999.~500 DRRO -099.~500 CAI.! -99o.~500 THOR -999.2500 SGR -999,~500 ] 6]67 59 5000 DT -~qq 2500 -999 2500 NPAT -qqg ~500 -099 RSO0 PIIOB -999 ~500 -999 2500 IJRIN -9~9 ~500 DT DEPT NPHI FCNL ,V PHI TCNL 6~nO 0000 STt, l) 59~7813 GR -990,7500 DR}tO -999.2500 CA[,I -~00.7500 -099.7500 I,I,D -O99 2500 -oqq~?500 -990.3500 THO~ -09o,~500 2,6914 II,M 61.~125 DT -999,~500 R{IOB -999,~500 NRAT 999.2500 GR :999.2500 C&hI . ,~500 NRAT 09,7500 D* '999. 2500 M,SFI~ -999,2500. C.,R -999,2500 NCNb · .99'9 2500 RNRA .999i2500 P[1TA -999 2500 DTI,, I 6719 'lbD 94~0000 GR -999,7500 NCNb -999.2500 RNRA -qqq,~500 .9~9.~5oo GR -999,~500 NCNb -999,~500 RNRA -999.2500 Pt]TA '999,2500 DTL 0,9961 IhD 96,4375 GR -999,2500 NCNG -999.2509 RNRA '999,~500 GR '909,~500 NCNb -999,2500 ~NRA -990,~500 POTA -999,2500 DT[, 1.1159 TLD 97.3125 GR '999.2500 NCNb '999.2500 RNRA '099.~500 '999,~500 GR -999,~500 -999.2500 RN~A -999.2500 P~TA -999,2500 DTL ~.6270 II, D 96,3125 GR -909.2500 NCNb -999.2500 RNRA -999,2500 MST[, -999,2500 GR -999.~500 ~CNI, -999°?500 ~NRA -990.~500 POT~ -999.~500 DTI. PAGE 15 ~99 2500 99:~500 -999 ~500 -999'2500 · -999,~500 -999,2500 1 5068 49 0313 -999 2500 -999 O0 -999 2500 .999 2500 -999 ~500 -999 2500 -999 2500 0 ~208 t4 500 -999 2500 -999 3500 -999 500 -099 2500 -909 2500 -999 2500 -999 2500 -999 2500 I 1865 52 5OO0 -999 2500 -999 2500 -999 2500 -999 2500 -999 ~500 .999 ~500 -999 2500 -999 2500 2 ]887 61 8125 -999 2500 .999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 [..VP OtO,H02 VERIFICATION I..',ISTTN(,; -g99,2500 DKPT alOn.nOO0 SFI.U PEF -999i2500 SGR bI.S -999 7500 NPHI -999 ~500 DRHO FC~L -999~500 CAI, I GR -999.2500 TIiOR CGR 'q99,~500 GR -999,2500 3,2539 ILM 41.3438 DT -900.2500 NRAT -099 2500 -oo9~2500 CAI. I -999,~500 -999,2500 NRAT -999.2500 DT ~EPT sp qPHT rCNI., rC~I, 6000,0000 SFLU -111.0625 ~R ~909,2500 DRHO 999,25oo cat.,t -9~9.25oo sGr -999,2500 LLn '909.9500 ORHO 'q99,2500 CAT,I -990,~500 2 6211 II.,M 19~9687 -999,2500 -009,2500 NRAT -q')0,2500 -000,2500 C~T,l -099,2500 -O99,~500 .09o ~500 IIRAN -999~2500 DT DEPT NPHI NPHI CGR GR 's90o oooo -~99 ~500 ORHO -999i2500 .999 ?soo sr;r . 99 2soo t,t,n -999 ~500 -~99 2500 ~AL! -099 2500 THOR -999 2500 '099 2500 3 2030 57 '999 -909 -q99 -999 -999 -999 -999 5625 DT 2500 RHOB 2500 NRAT 2500 ~r 2500 C!LI 7500 RHOB 2500 NR~T 2500 [IRAN 2500 bT DEPT SP NPHI ~CNL I., LS NPHI 5~ooi000o -999 9500 DRHO 999.2500 ~AI,I -090,~500 LLn -999.2500 2 5723 ILM 50 7500 DT -999 2500 ~HoB -999 2500 NRA[ -qq9 2500 ~R -999 2500 fill -999 ?500 RHOB -999 ~500 NR~T -999,2500 IIRAN -999.2500 DT DEPT NPHI FCNI, 5700 0000 -68,3750 -099,~500 DRHil '099,2500 CII,I 2 5664 51i9062 DT -099 ~500 RItO~ -909 ~500 I 0098 100:2500 OR -099,7500 NCNb -999,2500 -999,2500 GR -999,2500 MCNI{ -999,2500 POTA ,999.2500 1.1865 II, D 102.3750 ~R =999.2500 NCNb -999,2500 RNRA -099,2~00 -999,2500 GR -999,2500 NCNb -999.2500 -999,2500 POTA -999,2500 DTL 4.4297 101.1250 OR -999 2500 NCNb -99912500 -999,2500 MSFL -999.2500 GR :999 250(I NCNb 999:2500 RNRA '999,2500 POTA -999,2500 DTL 2,5313 i13,7500 GR -999,2500 NCNb -909,2500 RNRA '999.2500 ~SFb -999,2500 -999 2500 NCNb -999:2500 RNRA -999,2500 POTA -999,2500 DT[~ 2,4609 ILD 109 5625 GR -909:2500 HCNb -999.2500 RNRA -99 -999 -999 -999 -999 =999 =999 -999 PAGE 16 0 7954 3438 250n 2500 2500 2500 o0 2500 25O0 0 9570 39 9687 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 4 9414 57 5625 -999 t500 -999 500 -999 2500 -999 2500 -999 2500 -999 2500 .999 2500 .999 2500 2 2891, 50 7500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 2,3203 53,9067 -999,2500 -999.2500 L [., S -999.7500 SGR -999.2500 DRt,tO -999,2500 C~I.,T :999 2500 THOR ~9~500 SGR -999.2500 -999.2500 GR .Oqq.2sO0 C.~I..,I -999.2500 RHOB -999,7500 ~R~T ~q~q 2500 I~RA~ DEPT NPHI ~600.0000 110.~125 aR -999,7500 DRHO -qqq.2500 ~I,I -999,2500 '999,7500 LLD '099,~500 '900,2500 '999,2500 THOR -099,2500 -999,~500 3,3574 I[,~ 41,6250 DT. -900 2500 RHOB -999 ~500 N~AT -999 7500 UR -999 2500 CAI,! -909 2500 RHOB -909 ~500 NRAT -99q 2500 lI~ -999,2500 DT DEPT NPHI FCNL PEF NPHt 5200 nO00 SFl, il 60~531] -909,9500 DRHO -099,2500 CAI.! -099 ?SnO -999~7500 I,I,D -999,~500 -999.~500 :999 2SOO TUO~ -9~9,2500 2,1387 54,3418 -099 2500 RHOB -qg9 2500 NRhT -999 2500 GR -099 ~500 =909 2500 -~qq 2500 -99~ 2500 -999.2500 DT D~PT SP NPHI FCNI, NPHI ~CNI, 400 0000 SFI,II 102]~125 -099 ~500 DRHO -999i~500 Cll, I -99° 2500 SGR -999 ?500 hLD -999,7500 -999 ~500 ?HnR ] 6113 I[,~ 47 1~75 DT -999 2500 -999 2500 -0~9 ?5OO -9q9 2500 -9q9 2500 -999.7500 ~R~T -~99,2500 LIRAN SP NPHI ~OHI FCNL -999,~500 -999,9.500 CALl -99o, ?500 SGR 999.~500 ,.,LD ~990~500 DR[lC} qqq ~500 999 2500 THOR 4 7852 4~,7500 DT -99~,7500 R~OB -999,~00 NRAT 99 ?500 GR ,, . Q~2500 NRAT '999.~500 I.JR~N '999.~500 ~T ~999 2500 999~500 GR -999,2500 NCNh -999,2500 RNRA -999,~500 POTA -999,~500 DTL · . 1.6113 ILD !06.6875 GR -999,2500 NCNL '999,2500 RNRA -999,2500 ~SFL -999.2500 GR -999,~500 NCNb -999.2500 R~RA '999.2500 POTA '999.2500 OTb 2,2676 108,5000 GR -990.$500 NCNI,, -999 2500 RNRA -999i2500 -999 2500 GR -999 ~500 NCNL -999,2500 RNRA -090,2500 POTA -999.2500 DT[, 1.8125 II, D -999.2500 NCHb -999 2500 RNRA -999i2500 MSFL -999 2500 GR -999,2500 NCNb -999,2500 RNRA -999,2500 POTA -999,2500 DTL ] 5313 ILD 101i56~5 GR -099 7%00 NCNb -P~9,2500 ~N~ -090°2500 MSFh -999.2500 UR -999,~500 NCN[, -990.~500 POTA -999.~500 DTL -999,2500 -999.2500 -999 2500 999' - ,2500 -999,~500 -999,2500 4{ 320] 6250 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 m999,~500 -999,2500 2 0742 54 ]4~8 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 ,999 2500 -999 2500 -999 2500 I 4541 41 1875 ,999 2500 -999 2500 -999 !500 -999 500 -999 500 -999 2500 -999 2500 -999 ~500 2 93 49 75~6 0 -999 ~500 -999 2500 -999 ~500 -999 2500 -999 2500 -999 ~500 -999 ~500 -999 ~500 t, Vl~ OlO.H02 VERIrICaTIO~ I,ISTING -o99,2500 DEPT 5~0.0000 SFLU ~P 0.~675 NPHI -qq9,2500 DRHO ~CN[, -q99.2500 ~AI,I PEF -090.2500 SG~ bl,$ -9q0,7500 I,LD NPH! -999.2500 DRHO ~R -999,2500 ?HOR 2999,2500 ] 3203 ILa 61~9175 DT '999 2500 RHOB 'qqq:~500 NeAT -999,2500 GR '990,2500 CAb] -999.2500 RHOB -999,2500 ~IRAT -999,2500 IlRaN -999,2500 DT OEP? ~100.0000 SFI.,U SP 114.1250 Ga NPHI -990 2500 DRHO ~CN[., -990~500 C~LI PEF -999,7500 SG~ L[,$ -099,2500 [,lad NPHI -990,2500 DRH(] FCN[, -~99,~500 C~L! 2ooo1 5oo GR -990,2500 2 42 -999 -999 -999 -gOO -999 -999 1.914 0625 DT 2500 2500 NRAT 2500 2500 C~LI 2500 ~HOB ~500 NRAT 2500 DT DF. PT SP NDHI NPI!I RCNI~ CC, R 5000 0000 -60 531t -999 ~500 -999 2500 -999 2500 -099,9500 2999.2500 009.2500 -g99.75o0 '099,~500 '~99,7500 S F L U DRHO CALl S(.; R C~t.l THOR 2 R2 -999 -099 -999 -999 -999 'qoq, 51.56 IhM 5625 DT ~500 RHOR 2500 N~AT 25OO CR 2500 CbbI 2500 RHOB 2500 N~AT ~500 {,1RAN 2500 ~T DF, PT SP NPH! FCNI,, NP}tl I~CN[, G~ CGR 410o.n0oo 51.0938 2999 2500 9~0~500 -990 ?500 -999 2500 -990 ?500 -~99 2500 -qgg S F 1., II CAI, I D a H 0 CAI,,I THOR 3 -999. -qO9 -999 -909 -099 -999 -099 ~926 I[,~ 8750 DT 2500 2500 ~500 2500 CAI. I ?500 R~IOR 2500 2500 2500 DT DEPT SP NPHI FCNL 4,~.00 nO00 -, q 7500 DRHO -9c;9.?.500 C~I,I 3 4160 ILM 60i6250 DT -qgq 2500 R~tf'~ -9qg 2500 N~AT 3,6660 %LD 100,8750 GR -099.2500 NCNt, 999,2500 RNRA -999,2500 GR -999,2500 NCN[, -099.2500 RNRA -999,~500 POTA -999.2500 DTL 1,1807 ILD 114,3750 GR -999,2500 NCNb -999.2500 ~NRA -999,2500 qSFL =999,2500 GR '999 2500 NCNb -999i2500 RNRA -999 2500 PfITA -999,2500 DTh 2.50]8 IhD 177.8750 GR -ggg,2~O0 NCNb -990.2500 RNRA -999,2500 MSFL -999,2500 GR -9q9,2500 NCNb -999,2500 RNRA -999,2500 POTA -999.2500 PTI, 3.4727 IIJD 117.6250 GR -090 2500 NCN[, -999i2S00 R~RA -999,2500 :999 2500 999:~%00 RNRA -999.7500 POTA -999.2500 DTL 3.500p 116,8750 -99~.2500 NCNb -099.2500 -99 -999 -099 -999 -999 -999 -999 -999 42 -999 -999 -999 -999 -999 -999 -999 -999 PAGE 5566 9375 2500 2500 2500 2500 2500 2500 2500 2500 0225 0625 O0 2500 2500 2500 2500 2500 2500 2 5293 82 5625 -999 ~500 -999 500 -999 500 -999 2500 -999 2500 -999 2500 -999 2500 -999,2500 3,5664 81.8750 -999 2500 -999 2500 -999 2500 -999 2500 -999 ~500 -999 ~500 -999 2500 -999,2500 3,4688 69,6250 -999,2500 -999,2500 {8 GYP nlO,H02 VERIFICATION ~00.2500 GR .q0,2500 099.2500 ~990.~500 -909:2500 DT O~PT ]Zoo.oooo s~[.,t} S? 6].5918 GR NPHI 099,7500 D~HO FCNL 9gg 2500 CALl BLS -999,7500 LLD NPflI '999,2500 DRHO FCN[., -999,2500 CI[.,I GR -009.7500 THOR CGR -~99.2500 SGR G~ -999.2500 3,6660 ].I,M 76.0625 DT -gqg ~500 RHOB -~99~500 NRAT -999.2500 GR -099.2500 .C~LI -999.~500 RHOB -999 2500 NR~T -990~500 U~AN -g99.2500 DT O~PT 4600 0000 SFLU SP -69~]125 GR fl?HI -goo 2500 FCN[, -999~2500 C~I.,l P~IF -999.2500 SGR LLS -999.2500 LLD NPHI. -999.~500 FCN[,, -ggg.2500 CAI,I GR -990.~500 THOR CGR -999.2500 GR 4,7109 IbM 74.2500 PT -999 2500 RHOB =999 2500 MRAT -qgg ~500 GE -999 2500 CALI -gOO 2500 RHOR -999 ~500 NRA? -qgg ~500 URAN -999 ~500 DT o~:p? ~son nooo NPHI -o09 ?500 ~CNL -Q99!2500 CAL! PEF -QgQ ?500 SGR [.,{..,S -990 2500 I.,LD ~pHI -o99.75oo FCN{,, -999,~500 CALI <;R -qqO ?500 THOR CGR .999i9500 GR, -990.2500 50 -999 -qg9 -999 -999 -999 -999 -990 4 7031 6250 DT 2500 2500 ~'~T 2500 2500 CALX 2500 RHO8 ?50O -gO9 2500 DT D~PT 4.400inoo0 SF[,I..I .3!8710 S? -6~ 06;5 GR [t4 1875 BT NPHI 09o 2500 DRHO -q~g 2500 FCNL -000.2500 CALl ~90 ?500 ),,R ~ T P~?F 099 ~500 Stir .9°]2500 GR NPHI -q~O,?500 DR)lO -q90~2500 ~CN 1., -099.~500 CA[,I -999 ?500 NEaT GR 090 2500 THnR -~og: ~500 I.IR.A~ CG~ 2999' ~500 SGR -~99. 2500 8 , .... 99922500 GR '999.~500 NCNb '999,~500 RNRA -999 ~500 POT~ -999:2~oo nth 3 6836 .tt, D 125:]750 GR -999,2500 ~CNb -909,2500 RNR~ '999,2500 MSFb -999,2500 GR -999,2500 NCN[, -999,~500 RNRA 999 ~500 POTA :999:2500 4,3945 II,D i15,6250 GR -999,2500 NCNb -099.2500 RNRA -999 ~500 MSFb -999:2500 GR -999,2500 NCNb -999 ~500 RNRA -999:2500 POT~ -999,~500 OTb 2.7246 I[.,D 114.~500 GR -999 2500 NCNb -999~2500 RNRh -999.~50~ MSFh -999,~500 GR '999,~500 NCNb -999,2500 RNRA -999,2500 POTA -999.2500 DTL ~,9121 122,8750 GR "999,2500 NCNb '999,2500 RNRA '999,2500 MSFG '999,2500 GR -999,7500 NCNb -999.~500 RNPA '999.~500 DTL :999 2500 999 2500 -099 250n -999 2500 -999 ¢500 -999 2500 38926 760625 -9992500 -9992500 -9992500 -9992500 -9992500 -9992500 -9992500 -9992500 44883 742500 -9992500 -9992500 -9992500 -9992500 -999 2500 -999 2500 -999 2500 -999 2500 21523 50 -999 ~250500 -9992500 -999 ~500 -999 )50O -999 500 -999 2500 -999 2500 -999 ~500 4 3047 84 1875 -999 500 -9992500 -9992500 -9992500 -999 2500 -999 2500 -999 ~500 -999 2500 GVP OlO.H02 VF. RIFICATION NPHI Zo99.7500 DRFIO mCNI, 690.2500 ¢~[,! GR -999.7500 TftOR CGR -o99,2500 SGP GR -099,2500 -o..: 5oo 99~2500 DT DEPT 4700 0000 SFI.,U Sp -6]~59~8 GR NPWI -099,7500 D~HO FCNL -999,~500 C~GI PEF -690,~500 bbs -999.7500 LLD ~PHl -999.~500 GR -099,7500 THOR CGR -999.2500 Ge -999.2500 3.6660 I!,M 76,0625 DT, -999,7500 ~i99,2500 99,2500 .99,2~00 .C~[.,I -999°2500 -999,250~ -999 2500 U~AN -9~9~2500 DT DEPT 4600 0000 5F[,U ~PHI -999,2500 DRIll) ?CNL, -999,2500 C~I,I P~F -099,~500 SGR bLS -999,2500 LLD FcN[., -990:2500 CA[,I C~R -999~2500 SGR GR -099,7500 4 7109 74: 5oo -999,2500 -999,2500 NRAT 'q99.2500 GR '999.~500 -qOg,?500 URAN -999,2500 DT DEPT 450n n000 Sp -1to:~125 NPHI -qq9 ~500 DRH['I ~CNL -090!2500 C~l..,I P~F .090 ?500 LbS ~999 2500 NPHI -999;7500 FCNL -999 2500 CALl -999 ~500 -999 2500 4 7031 50 -999 -009 -099 -999 -999 -999 -999 -999 6¢50 DT 2500 RHOB ~500 2500 2500 ~500 RHOB 2500 ~R~T 2500 [IRAN 2500 PT DF. PT SP NPNT FCNL P~SF NPH I. WCN 4~00 OOOO SFI,I.I 68~0625 -090 2500 D~Hn -~0o!2500 C~LI - gq 2500 -099 2500 -990.250n -999,2500 CAI, I -900,2500 T~NR -090.2500 ] 87]0 I[,~ 84!1875 DT -999 2500 PHO~ -99~,7500 ~RaT -~gq 2500 GR -999:~500 CALI -999 ~500 ~HOD -999:?500 NRIT ~99.2500 PT -999 ~00 ~SFh -99922500 GR -999,2500 a~ -~99,7500 POT4 -900,2500 OTb i25:375o -999.2500 NCNb :999,2500 RNRA 999,2500 999.2500 :999,~500 NCN[, -g90,2500 RNRA '990,7500 POTA -999,2500 DTL 4,3945 115,6250 GR -909.2500 NCNb -099.2500 :999 2500 MSFb 999:~500 GR -999.~500 NCNb -999 ~500 RNRA -909i~500 POTA -999 2500 OTb 2,7246 114,2500 GR -gOO 2500 NCNb -909~500 RNR~ :999 2500 MSFh 999:2501) GR -999,7500 NCNb -999,2500 -999,;500 PDTA -999.2500 DTL t,9121 122,8750 '990,2500 NCNb '999,2500 RNRA '999,~500 ~SFL -999,~500 GR .99,2500 RNPA -OqO,~500 -999,2500 DTL PaGE -999 2500 8 '999,2500 -999,2500 '999,2500 '999,~500 '999,2500 3 8026 76 0625 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 4 4883 74 2500 -999 2500 -999 2500 -909 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 2 152~ 50 6250 -999 2500 -999 2500 -999 2500 -999 2500 -999 25OO -999 2500 -999 2500 -999 2500 19 4 ]047 84 ½875. -999 500 -999 2500 -999 2500 -999 2500 -999 2500 :999,2500 999.2500 -999,2500 LVP OlO,H02 VF. RIFICA?If~N LiS'I'INC, -999,~500 SP 92 3750 FCNI, -qq9,?SO0 Cal.,! P~F -009,7500 SGR FCML -qq9,2500 CA[,I GR -999.2500 THOR 6 2 109 ][{,~ -999 -909 -999 -999 -999 -999 -999 '999 2500 DT 2500 RHOB 2500 NRAT 2500 ~R 250o C~l,l 250n DHOB 2500 ,RAT 2500 t)RAN 2500 DT DEPT 4200.O000 SF[0U SP -92,9125 P~F -099.~500 SGR ~P}'tI -990.2500 DRHO GR -099 2500 THOR CGR '999i~500 SGR GR -9992500 4 5977 IIliM 61 '999 '999 '999 -Egg '999 '909 '999 8125 DT 2500 RHOB 2500 NRAT 2500 CD 2500 CaLl ?500 RHOR 2500 ~R~T 2500 II,AN ~500 DT DEPT SP NPH! FCNL L [., $ qPHI 4,100 0000 SFLI3 -108 ]1.25 GR -999 7500 DRHO -999 2500 CALl -qg9 ~500 -999 ~500 -0o9 2500 -099 mSnO C~I.I -999,2500 THOR 2999 2500 57 -999 -999 -OEO -999 -999 -999 -999 6 3477 Tl, M 7188 DT 2500 RHOR 2500 "~AT 2500 G~ 2500 CAI. T 2500 R)lO~ 2500 ~tT 2500 t)RA~, -999 2500 DT OF, PT $P MPI4T FCML P~F LI.S gpHI -74 -q9g -~99 -999 -999 -990 -~99 4000 n000 SFI.,U 7500 2500 CaLl 2500 I,LD 2500 2500 ?500 THnR -999 ?500 4,2305 72,0625 PT -999 2500 -999 2500 -999 2500 -999 2500 C~L! -999 ~500 RHOB -999 2500 NR~T -999 ~500 URAN -999 2500 DT DEPT SP FCNI, 3900 0000 SFI, U -114,~125 GR -990,7500 DRRO -990.2500 6,121J l[,~ 45,7~13 DT -009,2500 RHOR -990,2500 N~AT 4 8945 ILD 98:7500 GR -999,2500 NCNb -999,2500 RNRA -999,250o ~SF[, -999,2500 GR -999,2500 NCNL -999,7500 R{.IRA -999,2500 PATA -999,2500 QTL 3,66~1 TLD 117.1750 GR -999,2500 NCNL -999,2500 RNRA '999,2500 MSFL '999,2500 GR '999,2500 NCN5 -999,2500 RNR~ -999.~500 PFITA -999,2500 DT[, 4 3867 112 7500 '999 2500 NCNb -999 2500 RNR~ -009 2500 ~SFG -999 2500 GR -999 ~500 NCNb -999 ~500 RNRA -Egg ~500 Pf]TA -999,2500 DTL 3,8945 I[,D 116 2500 GR 999i2500 NCNL -999 2500 mSFb -999:~500 G~ -o99 2500 NCNL -999,2500 POT& -999.250o DTL 3,7266 TLD 1,19,8750 (;R -999.7500 NCNL -099,2500 ~t~a PAGE 20 ],9102 59,2500 -999 2500 -999 ~500 -909 500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 ] 0879 61 8125 -Egg 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 3 129 57 ~188 -gg9 2500 -Egg O0 -999 2500 -999 2500 -999 ~500 -999 500 -999 2500 ~ 92]8 72 0625 -999 2500 '999 2500 '999 2500 =Egg 2500 '999 2500 -999 2500 -999 2500 -999 2500 2,4766 45,7813 -999,2500 -999,2500 [,¥P 010.H02 V~IFICATION [,ISTING ~CNI, -999.2500 C~L! -999.2500 N~T ~ .~99.~5o0 T.o~ .~9 2500 CGR -999.~500 5G~ ~999~2500 OT G~ -99q,~500 sp .67:o6~5 n~ ' 6~ ~75o OT NnHI -qge. ?500 ~RHO -999:2500 RHOR FCNI, -099.~500 C~l.,I .990.2500 NR~T PEF -909.~500 ~GR -999.2500 GR BLS NPHI -999.2500 DRHO -999.~500 RHOR ~CNL -gqq.~500 CA~,T -999.~500 NRAT G~ -999.2500 THOR -999.2500 CGR -q99.2500 SGR -909.2500 DT ~CN[., .o99 ~506 CR[,[ -qqg.2500 NR~T P~F .999~2500 ~GR -9q9.2500 GR LbS -999· ~500 LI~D -999.~500 ~PH! -990.~500 DR~O -O99.2500 FC~I., -999.~500 CAI.,! .999.2500 NRAT C~R ~699~2500. SGR -999,2500 DT GR -~99,9500 SERVICF ~,1 ~ ~ E VERsTnN ~ D~TE : FTI, F TYPF NEXT FTT,~ NAOK : ** TAPF TRAILER ,R. ERVICK N ~",Fi :EDIT DhTE 184/02/24 O~IGIH :0000 T~PE ,,3 h ~K :8950 CONT] ~,I,I aT 1 FIN ~ COM~FNTS :TAPE 99 2500 ~SFL -999.2500 NCNb -999.~500 RNRA -999,2500 POTA -999.2500 DTL 2.7227 ILD 155,8750 GR -999,2500 NCNb -999.2500 RNRA '999.2500 MSFb -999.2500 GE -999.2500 NCNb -999.~500 RNRA -999.2500 POTA -999.2500 DTL ~5.2500 lbo 257.1875 GR -999.2500 NCNL -999.2500 RNRA -~qq 2500 NSFb -999:2500 GR -999.~500 NCNL -999.2500 RNRA ..9o.25oo Poma -999.2500 DTL 2999,2500 999.2500 -~99.2500 -999.2500 =999.2500 -999.2500 2 7852 61 8750 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 .999 ~500 -999 2500 -999 ~500 20OO 0000 47 4689 -999 2500 -999 2500 -999 2500 =999 2500 -999 2500 -999 2500 -999 ~500 -999 2500 · bVP OIO,H02 VF[~IFIC~TIO,~ S~RVICFt N .a. ~.~ E :EDIT C[1NTT~II~T'I~N ~ 101 g~XT R~':I, NAME ~ Cfl~MET~TS :R~]I~ CO~ENTS ,/ WELL NAME AR CO f '"' O [,FT./HR.) 30 DRILL RATE 0 - __ II -~-- ~ ' I _ .... ~ I ! I I ! 11 i , l-I l~ ~-t-~- - I i I J ~ ! I I ! 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