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188-049
Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: (907) 564-4891 01/12/2023 Mr. Mel Rixse Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Prudhoe Bay Surface Casing by Conductor Annulus Top-offs of Cement, Corrosion Inhibitor through 4Q 2022. Dear Mr. Rixse, Enclosed please find a copy of a spreadsheet with a list of Prudhoe Bay wells that were topped-off with cement, corrosion inhibitor in the surface casing by conductor annulus through the end of 4Q 2022. Cement top-offs are executed as needed to mitigate the void space left at surface by minor cement fallback during the primary surface casing by conductor cement job. The remaining void space between the top of the cement and the top of the conductor is filled with a heavier than water corrosion inhibitor to reduce the risk of external surface casing corrosion. The attached spreadsheets include the well names, API and PTD numbers, treatment dates and volumes. 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 have any additional questions, please contact me at 564-4891 or oliver.sternicki@hilcorp.com. Sincerely, Oliver Sternicki Well Integrity Engineer Hilcorp North Slope, LLC By Samantha Carlisle at 3:53 pm, Jan 12, 2023 Digitally signed by Oliver Sternicki (4525) DN: cn=Oliver Sternicki (4525), ou=Users Date: 2023.01.12 14:52:49 -09'00' Oliver Sternicki (4525) -253coG WELL LOG TRANSMITTAL DATA LOGGED 5/20,5 M K.BENDER To: Alaska Oil and Gas Conservation Comm. January 14, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 _ Anchorage, Alaska 99501 '_ . ` 1; , FEB 0 RE: Radial Bond Log: 14-37 OF) Run Date: 5/6/2014 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 14-37 Digital Log Image files 1 CD Rom 50-029-21810-00 Cement Bond Log 1 Color Log 50-029-21810-00 rCANNED 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: MAL°4414L7/) 6—ed ®rr��w � THE STATE 1� a,' ;a , ,d C . �e ( zj 333 West Seventh Avenue u Anchora e, Alaska99501-3572" CiOVI?RNOR SEAN i'ARNELL P�oin9072791g33O ` Fc x: 907.276.7542 aE� JUL Zn Sat4Dave Bjork Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 \,56'' C) Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 14-37 Sundry Number: 314-075 Dear Mr. Bjork: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, .. i°4-eie _. Cathy '. Foerster Chair DATED this z4 day of February, 2014. Encl. ' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED APPLICATION FOR SUNDRY APPROVAL FEB 0 6 2014 20 AAC 25.280 /)S 2fa///el- 1. Type of Request: AOGCC ❑Abandon 0 Plug for Redrill 0 Perforate New Pool ® Repair Well 0 Change Approved Program ❑Suspend 0 Plug Perforations 0 Perforate ®Pull Tubing 0 Time Extension ❑Operations Shutdown 0 Re-Enter Suspended Well 0 Stimulate ®Alter Casing 0 Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration (Alaska) Inc. ❑Ex Exploratory ❑Strati Stratigraphic 188-049 • 3. Address: ®Development ❑Service 6. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 50-029-21810-00-00 • 7.`If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU 14-37 , Will planned perforations require a Spacing Exception? ❑YesNo 9. Property Designatior 10.Field/Pool(s): ADL 028312 ' Prudhoe Bay/Prudhoe Bay ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 10009' • 9206' • 9965' 9165' 9413' 9725'(3);9775'; 9889',9894' Casing Length Size MD TVD Burst Collapse _Structural Conductor 110' 20" 110' 110' 1490 470 Surface 3443' 13-3/8" 35'-3478' 35'-3478' 4930 2670 _Intermediate 9594' 9-5/8" 32'-9626' 32'-8855' 6870 4760 Production Liner 668' 7" 9341'- 10009' 8596'-9206' 8160 7020 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9540'-9768' 8777'-8985' 4-1/2", 12.6# L-80 9426' Packers and SSSV Type: 9-5/8"x 4-1/2" Baker DB Packer Packers and SSSV 9300'/8559' MD(ft)and ND(ft): 12. Attachments: 13.Well Class after proposed work: , 0 Description Summary of Proposal 0 BOP Sketch ❑Detailed Operations Program 0 Exploratory 0 Stratigraphic 0 Development 0 Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation April 14,2014 • 0 Oil 0 WINJ 0 WDSPL 0 Plugged 16. Verbal Approval: Date 0 Gas 0 GINJ 0 GSTOR 0 Abandoned Commission Representative: 0 WAG 0 SPLUG 0 Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: J.E.B.Bolen,564-5110 Printed Name: Dave Bjork Title: Engineering Team Leader Email: J.E.B.Bolen@bp.com Signature: i ���/ Phone: 564-5683 Date: er/ „my c Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: •? \f•-•\— p'-(•S ❑Plug Integrity LJ BOP Test 0 Mechanical Integrity Test 0 Location Clearance Other: 0610 test ic) 35,- CPS i RBDAASS15MAY 11 2014 Spacing Exception Required? 0 Yes E;�No Subsequent Form Required: I/9 " 4 (,' 4 APPROVED BY / Approved By: �G .. ...)4e_4427-e-.- COMMISSIONER THE COMMISSION Date: - o;-�— Form 10-403 Revised 1 /2012 Submit In Du licate Approvt'JffIG1NAL iivlonths from the date of approval Duplicate', tt 1.1- Zi/ 9 //4 /177y '.N" • by Sundry Request for TxIAxOA communication repair Well: 14-37 Date: 02/05/2014 Engineer: J.E.B. Bole�� MASP: 2460 psi Well Type: Producer Estimated Start date: April 14, 2014 History: Well 14-37 was originally drilled and completed as a Sag producer in December 1988. The well came online with good rates. However, the rates had declined by mid-1991. A frac was pumped on 7/18/1991 ✓ and managed to place 116M lbs into the formation. The frac was successful and managed to bump rates. This allowed the well to stay online as a fulltime producer for the next —14 years before being SI for TxIAxOA communication in October 2005. ,/ 14-37 receives MI benefits from 14-25i. The most recent MI slug on 14-25i was between 12/03 to 09/05. Well Integrity Well 14-37 still retains its original 4-1/2" L-80 tubing string & 7" production liner. The IC hanger was treated with sealant three times in 1992 and 1993. It was granted a waiver for IAxOA communication (leak was likely through the wellhead) in 9/94 until 10/05 when the waiver was cancelled. A failed TIFL in 7/98 was mitigated by DGLVs in 11/98. The tubing pickoffs were tested on 02/11/07 and passed. The PPPOT-IC (05/16/2006)was unable to be conducted because the void was plastic packed. The well failed an MIT-T (01/28/2007), but passed a CMIT-TxIA to 3000 psi on 01/28/2007. The caliper shows the tubing to be in poor condition with a max pen =69% @ 7274' MD. A SLB LDL from 09/13/2007 found that GLM #6 (7808' MD) was leaking, with the possibility of another leak at 8600' MD indicated by spinner passes; however, stop counts indicate there is no leak below GLM #6. A valve with extended packing was set in GLM #6; however, the preceding MIT-IA still failed. The CMIT-TxIA performed at the same time passed to 2400 psi. Diagnostics for an extended patch began on 04/19/2008 when the TTP was pulled from 9413' MD. A brush and flush was performed due to paraffin restrictions in the tubing. The well was drifted with a dummy patch to the XN profile at 9413'. A WRP was set at 4570' MD and passed a MIT-T to 3000 psi. A lower packer assembly, with a TTP installed, was set in the 6' tubing pup above the production packer at 9296' MD on 06/14/2008. The packer failed a CMIT, and was blown down hole, and later fished out showing catastrophic failure. A caliper was run on the tubing tail showing no additional damage on 07/22/2008. A second packer assembly was set in the locator seal assembly at 9305' MD on 07/28/2008 and the well passed a CMIT-TxIA to 3000 psi on 8/2/2008. A kickoff GL design was set on 4/22/09 (with the S/O in station#4)to enable the well to be POP. The 04/27/09 IA&OA gas sample analysis shows similar composition thus confirming IAxOA communication. The OART that was measured on 5/12/09 came in at 60 psi/day. The well was SI and secured with a TTP set in the lower packer at 9315' MD on 5/13/09. The resulting CMIT-TxIA(that was performed on 7/17/09)failed to 3000 psi. The lower packer assembly was pulled from 9268' on 7/20/09. They found the bottom section missing (-13') and the latch of GLV#8 was bent into the tubing. The most recent voidage test shows the primary seal to be leaking. The well passed the CMIT-TxIA to 3000 psi in February, 2013. Scope of Work: The primary objectives of this RWO are to restore well integrity and return the well to operable status. Pre-Rig Prep Work: F 1 CMIT-TxIA(3,000 psi), MIT-OA(2,000 psi) W 2 Function LDS; PPPOT-T(5,000 psi); IC test not possible due to plastic packing S 3 Tag PXN plug, dump 10' of sluggits on top of PXN plug E 4 RCT to cut tubing in the middle of the first full joint above the packer F 5 Circulate well to seawater with diesel FP ✓ 6 Prep annular valves, Set a BPV. O 7 Remove the well house&flow line. Level the pad as needed for the rig. W 8 Excavate the cellar as needed to get top of spray-in liner below the 13-3/8" starting head. Line the cellar around the wellhead with impermeable, Rhino-lined Herculite. Proposed RWO Procedure: • MIRU Doyon 14. Pull BPV. Circulate seawater KWF. Set TWC. Load OA with KWF. • ND tree. NU and test BOPE with four preventers configured top down (annular, 9-5/8" fixed, blind shears, mud cross and 3-1/2"x 6"VBR's). Test the fixed, blind and VBR's to 3,500 psi and the annular to 3,500-psi. Pull TWC. • Pull 4-Y2" L-80 tubing from RCT cut(-9,400' MD). • RU E-line, Run USIT in the 9-5/8"casing to determine TOC in the 9-5/8"x 13-3/8"annulus. • Set 95/8" RBP —100' below logged TOC. PT RBP to 3,000 psi. • Dump 50' of sand on top of RBP. • Mechanically cut 95/8" casing in 1st full joint above the TOC. • Pull 95/8"casing to surface. • Scrape 133/8'casing and dress-off 95/8"casing stub. • Split the BOP stack and cut off 133/8"starting head. • Run 95/8" -back Ily cemented to surface with 15.8 ppg latex class G cement. • Install 9 /8"x 133/8" anger and 9-b/8" sliplock wellhead. Nipple up and test BOP equipment. • Drill out t 5/ " oe track and test casing to 3,000 psi.sZ • Recover the RBP. • Run new 4.5" 12.6# 13Cr VamTop completion with 95/8" x 4-'h" HES"TNT" packer and unique overshot. • MIT-T and MIT-IA to 3,000 psi. • Set a BPV and RDMO. Post rig Work • Slickline pull ball & rod, set gas lift design, pull RHC plug body, bail sluggits, pull PXN plug. • Re-set flowline and wellhouse. • POP well. 1 4 TREE= FMC GEN 4 !WELLHEAD FMC 14_3 7TYLE.NOTES: "*`WELL HAS HISTORY OF CA ACTUATOR= AXELSONCoSA KB.ELEV= 74' A oe BF.ELEV= I KOP= 3900' /Max Angle= 36 @ 7700' 2023' I—4-1/2"AVA TRSV SSSV NIP,ID=3.812" 0I ti LOCKED OUT(03/31/94) Datum MD= 9647' Datum-ND= 8800'SS GAS LIFT MANDRELS 20"CONDUCTOR,91.5#,H-40,D=19.124" H 110' A L ST MD TVD DEV TYPE VLV LATCH FORT DATE 1 3193 3193 0 FMHO DOME RK 16 04/22/09 13-3/8"CSG,72#,L-80 BTC,ID=12.347" — 3478' 2 4110 4203 17 FMHO DMY RK 0 12/21/88 3 5241 5116 31 FMHO DMY RK 0 06/26/93 4 6160 5900 30 FMHO SO RK 20 04/22/09 5 6982 6602 31 FMHO DMY RK 0 07/31/97 6 7808 7290 36 FMHO `DMY RK 0 01/30/08 7 8293 7684 35 FMHO DMY RK 0 07/21/98 8 9077 8358 26 FMHO DMY RK 0 04/17/10 9 9198 8466 25 FMHOI DMY RK 0 08/17/93 Minimum ID =3.725" @ 9413' *STA#6 HAS EXTENDED PACKING 4-1/2" OTIS XN NIPPLE Z 9300' I—9-5/8"X 4-1/2"BKR DB PKR,ID=3.875" TOP OF 7"LNR —I 9341' 9413' H4-1/2"PXN PLUG(10/30/11) 9413' H4-1/2"OTIS XN NIP,ID=3.725" 9424' —4-1/2"BKR SHEAROUT SUB 4-1/2"TBG-PC,12.6#,L-80,.0152 bpf,ID=3.958" H 9425' 9425' —4-1/2"WLEG,D=3.958" 9405' H ELMD TT LOGGED 06/26/89 9-5/8"CSG,47#,L-80 BTC,ID=8.681" H 9626' ' 9618' H7"MARKER JOINT PERFORATION SUMMARY ' REF LOG: BHCS ON 09/29/88 IL ANGLE AT TOP PERE: 24 @ 9540' ' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE ' 4" 4 9540-9557 0 12/17/88 4" 4 9596-9628 0 12/17/88 ' 4" 4 9630-9646 O 12/17/88 1 2-7/8" 6 9670-9675 O 12/26/98 11 9725'SLM —14.23'OF LWR KB PKR 1 2-7/8" 6 9713-9716 0 12/26/98 &2-7/8"X NIP w/2.313"PXN FLUG 2-7/8" 6 9742-9747 0 12/26/98 , 9725' SLM H FISH-KB PKR PARTS(06/23/08) 3-3/8" 6 9754-9760 O 10/05/94 •: 9725' SLM H FISH-OGLV(07/30/91) 4" 4 9760-9768 O 12/17/88 3-3/8" 6 9760 9764 0 10/05/94 9775' -FISH-3"OF JD PULLING TOOL DOG(07/31/97) �y ' 9889' -FISH-BRIDGE PLUG(03/08/92) 9894' -FISH-1-1/2"MC-GLV(05/02/89) PBTD - 9965' 11111111111111 7"LNR,29#,L-80 BTC,.0371 bpf,D=6.184" —I 10009' eA-A-A1A1A1A1A1, DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/03/88 WW1 ORIGINAL COMPLETION 05/04/10 MGNVPJC DRAWING CORRECTIONS WELL: 14-37 12/21/88 N9ES LAST WORKOVER 10/31/11 WEGJMD PULL NIP REDUCER(10/30/11) PERMIT No:1880490 12/14/09 JM/PJC SET PXN(12/13/09) 10/31/11 WEGJMD SET 4-1/2"PXN PLUG(10/30/11) API No: 50-029-21810-00 04/30/10 GTW/PJC GLV GO(04/17/10) 02/06/14 J.EB./JMD FISH CORRECTIONS SEC 9,T1ON,R14E,4579.88 FEL 2087.16 FNL 05/02/10 MBM/PJC PULLED PXN PLUG(04/08/10) 05/02/10 MBIWPJC SET NIP RED/XN NIP(04/09/10) BP Exploration(Alaska) X ' ca O Q� i N •- Q Ca Q O CO — O m M — � 1 Q, � U o U J ' -c , _ V) _1 a) Ucu o5U � rna xo 0 N QUMo >- m o , I CD I- I— N - Z 000_co J9 Q ~A C.� Z ~ 4' . . 1- Z O r^' r W • a) M I ,. OZ me - C6 O Q I ._„ i a- a N ' d ad . 0 = N (1) i ca 0) �i ISN , tU a. ,(C)- vU Ci TOM ca a ■ ` iii (11 s7=.9 241: v ap. \ Id t� ! i t,-. s i i hi' Al it t "404 p.‘‘,„,! , om. , Q=12'6 ,.� .t M 11''--.1 t-1 1 illa , ,. , ii kim .4 e i c•( I r I V ! it, ,i 111 , ilk 1 c d ,,v 1 4.--" 1 1 11 ' 1 lit i l tk 1.„..1::li-1\'.:113. i 1 A"' : 11 14V:" \\:'' '.''il f77:.‘::1/i .max i Pe,ps! c� > ,{1., 1 - • 111 x 10 • N O `s .• c>3 Q � o a) o L .Q O co co Q _,'' $ c? U c o c �n r, o fife ii / ' tJ / > J flH = o ra c`i C n Y,- 4- d = V) �" d lf) 0 O — `F' N o a.- X O c) Tr = _ m i— ....,_ O O Q , / N O et C)E EL Q f4 a) a) V Q � NN HAm `� • oN Q ca � U oC � p --., Z � _o o � � tc y � m 2c (1) 0_cB m c5c c� - .. es • OJ ,_ > M• OM c4 � � � N Ta 0, O D O ca —di'-_.�__.._. O vi au_ . cacfl0 U XY CD d o o a, _ E o_— Cl) N > o _ �C � � ca U, o � � 0)m � ,< 0)00N OCO � 0 � � fns N ca .0 ON ,_ C 0- co � aoNQ JmQ ao = U � _J 0 � � JU Et LO 0 C 0_ -6 ECMO Z — O QZ E � r- 0O � � > za • O � a3N .s:( Lf") Cl) � • Q a) F— N— U m c- > u_ 2 m V) J LL N 0 O� 0 V) 0 cn T —11 FMC GEN 4 WELLHEAD= FMC 14-37 CO SCALE(NOTES: ***WELL HAS HISTORY OF CA ACTUATOR= AXELSON KB.REV= 74' Proposed RWO BF.REV= KOP= 3900' Max Angle= 36 @ 7700' 1 4 +1 5' I--I13 3/8" Datum MD= 9647' Datum ND= 8800'SS 20"CONDUCTOR,91.5#,1-1-40,D=19.124" H 110' I '— 2000' H4-1/2"HES X NP,ID=3.813" 9-5/8"CSG,47#,L-80 HYD,ID=8.681' -3400' -3400' H 9-5/8"Overshot GAS LFT MANDRELS 13-3/8"CSG,72#,L-80 BTC,D=12.347" 3478' ST MD TVD DEV TYPE VLV LATCH PORT DATE ILI 7 3503 3500 0 6 5340 5200 32 5 6278 6000 30 4 6863 6500 32 3 7460 7000 34 2 8067 7500 36 Minimum ID =2.313 @ 9413' 1 8661 8000 31 2.7/8" NIPPLE REDUCER9125' HIX ►.1 9135' -4-1/2"x 9-5/8"HES TNT PKR I 9160' -4-1/2“HES X NP,D=3.813" 4-1/2"TBG,12.6#,13Cr-85,.0152 bpf,E)=3.958" H 9425' r 9225' -4-1/2"x 9-5/8"Overshot X 9300' 1-9-5/8"X 4-1/2"BKR DB PKR,ID=3.875" TOP OF 7"LNR H 9341' _ MI 9413' F-4-1/2"OTISXNNIP,D=3.725" 4-1/2"TBG-FC,12.6#,L-80,.0152 bpf,ID=3.958" H 9425' —ii NI 9424' H4-1/2"BKR SHEAROUT SUB 9425' H4-1/2"WLEG,ID=3.958" 9-5/8"CSG,47#,L-80 BTC,ID=8.681" -i 9626' , 9405' H Elmo TT LOGGED 06/26/89 PERFORATION SUMMARY 9618' H7"MARKER JOINT REF LOG: BHCS ON 09/29/88 ' ANGLE AT TOP PERF: 24 @ 9540' Note:Refer to Production DB for historical pert data I SIZE SPF INTERVAL Opn/Sqz DATE 4" 4 9540-9557 O 12/17/88 ' 4" 4 9596-9628 O 12/17/88 4" 4 9630-9646 O 12!17!88 I 9725' SLM 14.23'OF LWR KB PKR 2-7/8" 6 9670-9675 O 12/26/98N . &2-7/8"X NIP w/2.313"PXN PLUG 2-7/8" 6 9713-9716 O 12/26/98 2-7/8" 6 9742-9747 0 12/26/98 9725'SLM -{FISH-KB PKR PARTS(06/23!08) 3-3/8" 6 9754-9760 O 10/05/94 1 9725'SLM -I FISH-OGLV(07/30/91) 4" 4 9760-9768 0 12/17/88I 9775' -I FISH-3"OF JD PULLING TOOL DOG(07/31/97) 3-3/8" 6 9760-9764 O 10/05/94 a 9889' -1 FISH-BRIDGE FLOG(03/08/92) ' 9894' H FISH- 1-1/2"MC-GLV(05/02/89) PBTD H 9965' 7"LNR,29#,L-80 BTC, .0371 bpf,ID=6.184" H 10009' ���������������� DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/03/88 WW1 ORIGINAL COMPLETION 05/04/10 MGM/PJC DRAWNG CORRECTIONS WELL: 14-37 12/21/88 N9ES LAST WORKOVER PERMIT No:'1880490 12/14/09 JNVPJC SET PXN(12/13/09) AR No: 50-029-21810-00 04/30/10 GTW/PJC GLV C/O(04/17/10) SEC 9,T1ON,R14E,4579.88 Fa 2087.16 FNL 05/02/10 MBM/PJC PULLED PXN PLUG(04/08/10) 05/02/10 MBM/PJC SET NIP RED/XN NIP(04/09/10) BP Exploration(Alaska) , \k L.• |°) § ] (` ii o \ o» 5 §§ . \ ` %. ) \ ) • ( /© &§(p \ ) o/ o§\ � , _ .\ $ �\ § / ;» = ,< co § ,— CV rn _ z = I, 01 §o %o \ § � ® a § §o, g0 1; E°® |°' ) ( I , | % (3 | 0 | 1 | • =o , - CO . ` , ,\ _ z p� \,, ! ;a 2\1 �� '11111 ( ; :© \\\ \\ \ / } % ) gi ■ Y` \ % ]b � - �= C-> \ . } )§ (/§ _ k, ƒ \ z ƒ g « f2\ \ \ $ »K% - : 7 ! !, ; q§ § 8 8 89 / w e ) 99 \ § 5 DA § - a \ \ } . I % ^ ` 1 !! \\ \ \{\ \ '2 \ /\ » i , 72. @ 2|} 3 @ 1 s /! §| — -�—-- � | | 1 ---i—be- ili £ _ - . .._ 1 \ »O r i |1 T, —--—i—_ | .— g _: : T _--- \ U- � , | . y—. 7 I } ; - I CO ? - 1• •I •I ( I i i I I w I I 1 11 � 1= 1 I 1 I ; I Ice ! o - j i ! � £ i I ! � I I \ I --1 \ 1 � � ii i c7 1 1 : h \� I ail") � 2iCr & I vii = i C~ BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 Dec 07, 2009 t '' ~ (~1~ ~yq~y~ • t • by ~.. , DE;C ~ "~ ~C~Q9 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS 14 Dear Mr. Maunder, . .._ i$$-a~q i~r-37 Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 14 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, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • s BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) DS-14 narn~ ~~m~mo Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al 14-01A 1931850 500292031701 Sealed Conductor NA NA 14-o2C 2071150 500292031803 Sealed Conductor NA NA 14-03A 1961290 500292031901 Sealed Conductor NA NA 14-04A 1961640 500292032001 Sealed Conductor NA NA 14-05A 1920010 500292032701 Sealed Conductor NA NA 14-06A 2040360 500292032801 Sealed Conductor NA NA 14-07 1780660 500292032900 Sealed Conductor NA NA 14-O8A 2022100 .500292033001 Sealed Conductor NA NA t4-O9B 1820340 500292053402 Sealed Conductor NA NA 1a-10 1801300 500292052800 Sealed Conductor NA NA 14-11A 2051260 500292052901 Sealed Conductor NA NA 1a-12 1811090 500292063100 Sealed Conductor NA NA 14-13 1811010 500292062x00 Sealed Conductor NA NA 14-14 1811020 500292062500 Sealed Conductor NA NA 1a-15 1810840 500292061100 Sealed Conductor NA NA 14-16A 1971670 500292060801 Sealed Conductor NA NA 14-17A 2030010 500292056201 Sealed Conductor NA NA 14-18B 2071290 500292055102 Sealed Conductor NA NA 14-19 1810450 500292057800 Sealed Conductor NA NA 14-20 1810700 500292059800 Sealed Conductor NA NA 14-21A 2051070 500292075601 Sealed Conductor NA NA 14-22A 1921230 500292074701 Sealed Conductor NA NA 14-23A 2090200 500292075701 NA 4 NA 25.50 10/20/2009 14-24 1830910 500292097000 NA 0.6 NA 3.40 10/20/2009 14-25 1831020 500292098100 NA 2.1 NA 15.30 11/16/2009 14-26 1811100 500292063200 Sealed Conductor NA NA 14-27 1831700 500292104600 NA 3 NA 17.00 10/25/2009 t4-28 1820120 500292070800 Sealed Conductor NA NA 14-29 1811680 500292068000 Sealed Conductor NA NA 14-30 2050940 500292067901 Sealed Conductor NA NA 14-31 1831110 500292098900 Sealed Conductor NA NA 14-32 1831220 500292099900 NA 0.6 NA 3.40 10/19/2009 14-33 1831250 500292100200 Sealed Conductor NA NA 14-34 1831330 500292101000 NA 7.3 NA 47.60 10/20/2009 14-35 1831420 500292101800 Sealed Conductor NA NA 14-36 1831630 500292103900 NA 0.7 NA 3.40 10/20/2009 14-37 1880490 500292181000 NA 1.3 NA 5.10 10/20/2009 14-38 1881030 500292186200 NA 0.8 NA 3.40 10/24/2009 14-4oA 2011350 500292187501 Sealed Conductor NA NA 14-41 1920960 500292229000 NA 0.8 NA 6.80 10/18/2009 14-43 1921080 500292229600 NA 1.4 NA 10.20 10/23/2009 14-44A 2021930 500292257301 NA 10 NA 88.40 11/24/2009 BOP Stack Change for Well W~ Platform • Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, August 05, 2009 12:41 PM To: 'Allely, Josh (BPXA)' Subject: RE: BOP Stack Change for Well Work PlatForm ~S `~-~ ~ ~~~ ~ ~~~ Josh, This is not an issue. Clarifying the size changes is valid and I will place a copy of the documents in the files. I thought the Klondike has already started work, but that doesn't seem to be the case according to the newest drilling schedule. Did work get delayed? Call or message with any questions. Tom Maunder, PE AOGCC From: Allely, Josh (BPXA) [mailto:Josh.Allely@bp.com] Sent: Tuesday, August 04, 2009 2:42 PM To: Maunder, Thomas E (DOA) Subject: BOP Stack Change for Well Work Platform ~ ,a~ :t ~ ~!~t~s'i . t _. „W...1 .r~,~ ~~_ Tom The CP Wells Group is beginning it's "Well Work Platform" campaign within the next week. This is typically performed with 2-3/8" coiled tubing. Due to pipe availability, the pipe has been changed to 2" coiled tubing; the scope of work remains the same. The current sundries approving this work have a BOP stack set up for 2-3/8" coil. Given the new coil, the BOP stacks have been altered and optimized for 2" coil. Attached are the original approved sundries as well as the new BOP stacks for 14-15 and 14-37. Is this note sufficient communication to the State or do we need to go through the Sundry process again? Feel free to contact me if you need additional info. Thanks Josh Allely «14-15 sundry308-371.ZIP» «14-37 sundry309-243.ZIP» «14-15 BOP stack - 3.5 liner BOP diagram.ZlP» «14-37 BOP stack - 2.875 tbg patch BOP diagram.ZlP» Josh Allely Wells Group PE BP Alaska 907-564-5732 907-350-7362 (cell) 907-564-5510 (fax) josh.allely@bp.com 8/5/2009 ! • BOP-Tree F 0 ~ 7-1/16" 5000 psi BOP's ID = 7.06" 0 ~ 0~ ~ r Line GL ID = 6.375" with 6" Otis Unions ~~~7 1/16" 5000 P~S 7 1/16" 5000 psi (RX-46) nbi or ,~S 4 1/16" 5000 psi (RX-39) _ ~~ Wing FMC 4-1/16 bore x 4-1/16 flange bp Tree Size o ~ ~~ SS~ Master Valve No Tu~nS ~inpur # turns bTu ni g Hanger Base Flange Line Page 1 • • :. ~ ~ ~ ~ ~.~ ~ ° ~ ~ a ~ ~~ ~p~~ T ~ ^k ~ ~~~ K~~h, a ~ ~ ~ ~ ~~ ' ; k ~k ° ~ ~ ,~~~ y ~ ~°~ ~y ~$ ~ SARAH PALIN, GOVERNOR ,-~~ ~ '~ ~ ~ ~ ~ t _ ._ ~ _ .. ~ ,. ~ ` ~~ i,~ ~ e~ .~~ ~ ~ ~~ # ~ ~ ~, ~ ~ ~a, ~5~~ 0~ tu`D G~a7 ~ 333 W. 7th AVENUE, SUITE 100 CO1~T5ERQA'1`IO1~T COMDIISSIOI~T (' ~4NCHORAGE,ALASKA 99501-3539 1 PHONE (907) 279-1433 F FAX (907) 276-7542 Mr. John Alley Production Engineer BP Exploration (Alaska),Inc. , , , , ~4 T P.O. Box 196612 ~~~~:'$~4~~~" ~~ ~ `` ~ 200~ Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Pool, PBU 14-37 ~~ Sundry Number: 309-243 ~~ ~ ~ ~ ~ ~~ /~ Dear Mr. Alley: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pagerj. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. ~ Chair DATED thi~~day of July, 2009 Encl. "' ~j'~ STATE OF ALASKA ~I~~LAS IL AND GAS CONSERVATION COMMI~N APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ~ ~'a,~ ~ 1 ed ~ V.e'~~ ~ ~'~ ~u~ ~ s zoo9 F~gaslca ~ ~ ~as Cans. Commissian 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ^ Waiver ^A[iGha[Sg2 Other ~ Alter casing [] Repair well Q- Plug Perforations ~ Stimulate ^ Time Extension ~ TUBING PATCH- Change approved program ~ Pull Tubing ~ Perforate New Pool ~ Re-enter Suspended Well ~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ~_ Exploratory ~ 188-0490 - 3. Address: P.O. Box 196612 Stratigraphic ~ Service ~ 6. API Number: Anchorage, AK 99519-6612 50-029-21810-00-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Weil Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ^ PBU 14-37 - 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): _ ADLO-028312 - 74 KB PRUDHOE BAY Field / PRUDHOE OIL Pool 12• PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10009 ~ 9205 - 9767 8984 PBTD tagged @ 9767' 9698 9715 9775 9889 Casing Length Size MD ND Burst Collapse Structural Conductor 110 20" SurFace 110 Surface 110 Surface 3401 13-3/8" 72# L-80 Surface 2478 Surface 2478 4930 2670 Intermediate Production 9549 9-5/8" 47# L-80 Surface 9626 Surface 8855 6870 4760 Liner 668 7" 29# L-80 9341 10009 8596 9206 8160 7020 PerForation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 4-1/2" 12.6# L-80 SURFACE - 9425' Packers and SSSV Type: 9-5/8"x4-1/2" baker db pkr Packers and SSSV MD (ft): 9300' bkr straddle pkr 9294' - 9322' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ~ BOP Sketch ^ Exploratory ~ Development Q- Service ~ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: 7/30/2009 Oil Q- Gas ^ Plugged ^ Abandoned ~ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Prepared by Gary Preble 564-4944 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact ~osh Alley Printed Name Josh Alley Title PE Signature / Phone Date ~ ~`!`"'"ri ""^ !/ ' 564-5732 7/16/2009 COMMISSION USE ONLY ~1tGl\S~ i`~C~'c7S '~Jar- Qcac`~v~ a0 ~~S A~~Mr~.~ aO0`~1 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ?0 „ Plug Integrity ~ BOP Test [~ Mechanical Integrity Test ^ Location Clearance ^ ~ ,J Other: '~J~~ ~S~a 6'G.~~ L T r7.~ ~ s ~ p s. ~:~~Z ~~~..~~~~~c~.c~ S~- Subsequent Form Required: 'l~~ ~ ~,~ ~)~"~I. ,1~~ ~, 7 ~do9 APPROVED BY Approved by: MISSIONER THE COMMISSION Date: ~ ~3 14-37 188-049 PFRF OTTO(:HMFNT n ~ Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 14-37 12/17/88 PER 9,540. 9,557. 8,776.69 8,792.14 14-37 12/17/88 PER 9,596. 9,628. 8,827.63 8,856.79 14-37 12/17/88 PER 9,630. 9,646. 8,858.62 8,873.21 14-37 1Z/17/88 PER 9,760. 9,768. 8,977.43 8,984.75 14-37 10/5/94 APF 9,754. 9,760. 8,971.94 8,977.43 14-37 10/5/94 RPF 9,760. 9,764. 8,977.43 8,981.09 14-37 12/26/98 APF 9,670. 9,675. 8,895.12 8,899.69 14-37 12/26/98 APF 9,713. 9,716. 8,934.44 8,937.19 14-37 12/26/98 APF 9,742. 9,747. 8,960.97 8,965.54 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICA~ ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE n U ~ ~~ To: J. Bixby / C. Olsen, GPB Well Ops TL From: Tiffany Quy, Welis PE Subject: 14-37 Extended Patch Procedure PBD14WL37-N This procedure includes the following steps: • Date: October 7, 2008 Est. Cost: $300 M IOR: 300 BOPD Step Type Procedure 1 DHD Shoot T, IA, OA fluid levels. 2 F Circulate well with inhibited sea water and diesel freeze protect in T& IA to ~4700' (pre-extended patch) 3 C Run 4905'of 2-7/8" 6.5# 13-Cr80 jointed tubing for extended length patch from 4400' DD - 9305' DD. MIT-IA, establish LLR if fails. ** Will re uire Work Platform and 2-3/8" coil 4 SP Pull TTP, Drift & Tag, and POP. (pending passing MIT-IA) Current Status: PAL - Secured with TTP. Not Operable for TxIA communication Last Well Test: 09/25/2005: 366 BOPD; 6723 BWPD; 7400 Mscf gas; GOR 20250 3503 MCFD gas lift rate; 377 psi FTP Max Deviation: 36 degrees @ 7700' DD Top Perfs Deviation: 24 degrees C~ 9540' DD Minimum ID: 3.725" @ 9413' DD, 4-1/2" Otis XN Nipple Last TD tag: 12/19/2006: 2.5" Drift w/ TEL & SB - Tag hard BTM @ 9774' ELM. Last Downhole Ops: 7/28/2008: Set lower packer Q 9305' DD. Latest H2S value: 08/01/2005: 90 ppm Tie-in Log: SLB LDL (09-13-2007) (Log is included and is tied in to DD) Proqram Obiectives: The objective of this procedure is to repair communication and restore well integrity by setting a 2-7/8" 13-Cr extended patch from 4400' DD - 9305' DD with coil tubing using the Wellwork Platform. The lower patch assembly has been set at 9305' DD and a successful CMIT performed to 3000 psi. Well Historv: Well 14-37 is a gas lifted producer completed in 1988 with 4-1/2" L-80 tubing. It is currently inoperable due to TxIA communication. It also has slight IAxOA communication manageable by bleeds. i ~ 14-37 passed a CMIT-TxIA to 2400 psi 02/02/2008. The last MIT-OA passed to 2400 psi on 7/1/05. A caliper run 3/8/2007 shows the tubing in poor condition below GLM#3 (see attachment). A SLB LDL run 09/13/2007 found that GLM #6 was leaking with a possible leak at 8600 ft indicated by spinner passes. Stop counts did not confirm the second leak below GLM #6 (7808' DD). A GLV with extended packing was set in St #6 01/30/2008, but a MIT-IA still failed. Diagnostics for an extended patch began 04/19/2008. A brush and flush was performed due to paraffin restrictions in the tubing. The well was drifted with a dummy patch to the XN profile at 9413'. A WRP was set at 4570' DD and passed a MIT-T to 3000 psi. A lower packer assembly with TTP installed was set in the 6' tubing pup above the production packer at 9296' DD 06/14/2008. The packer failed a CMIT, was blown downhole, and fished out showing catastrophic failure. A caliper was run on the tubing tail showing no additional damage 07/22/2008. A second packer assembly was set in the locator seal assembly at 9305' DD 07/28/2008 and the well passed a CMIT-TxIA to 3000 psi 8/2/2008. NOTE: This well has plastic coated tubing and a history of paraffins. Production Risk: • SNAP was used to model the tubing restriction effect of this patch program. Using the last well test, the following was found: o Last well test: 366 bopd, 6723 bwpd, 7400 mscf gas, 20250 GOR o Lifting from GLM#2 (4929' 2-7/8" Cr): Leaves 275+ bopd (less 20-25% original production) o Lifting from GLM#1 (5845' 2-7/8" Cr): production) o Adding a GLM in the patch to lower the by another 100 bfpd (~5 bopd). Most restriction, not lift. leaves ~255+bopd (less ~30% original lift point would only increase fluid rates production loss will be from the tubing If you have any questions or comments regarding this procedure, please call Jennifer Julian at 564-5663 (work), 274-0929 (home), 240-8037 (cell), Olivia Bommarito at 564-4096 (work), 230-4212 (cell), or Tiffany Quy 564-5322 (work), 253-576-6153 (cell). Cc: Well File 2 ~ . Pre - Job Planninq and Safetv The risk assessment from previous jointed pipe operations with the wellwork platform is attached FYI. Please refer to these additional references. (Please make sure the attached SOP and RP's are still current.) • ADW RP for WWP Operations • ADW RP for handling and running 13 chrome plus latest pipe dope recommendation. • ADW RP for running CTD liner • ADW RP for Rigging and Lifting • ADW RP for Crane Specification and Handling • ADW RP for Mobile Crane Critical Lift Procedure o Attachment A- Lift Plan Template and Calculations o Attachment B- Lift Plan Checklist • Risk assessment/HazID - to be finalized on the slope NOTE: All the above references are attached in a separate PDF file. RP's/SOP's can also be found in their respective sections in the PE manual (both on/offline versions). Lifting RP's can be found in the new "Cranes and Lifting Operations" under the "HSE" tab. Risk Discussion/Requirements • Sundry reporting requirements will include form 14-404. This is not required to perform the work, but it will need to be completed within 30 days after completion of the work. A 14-404 is required for all patch work on producing wells and will be handled by Gary Preble. Please send an e-mail to PREBLEGB@bp.com after the work is completed and he will complete the sundry form. • Plan to hold a Pre-Spud meeting to review all aspects of the planned work. Review the HAZID and update to reflect site specific and work specific aspects of this procedure. Ensure that all lifting operations have been reviewed and a lift plan prepared as necessary. • Depth control for this job is based on Drillers Depths (DD). The tie in log is the SLB LDL 13-Sept-07. Note this log has been tied into DD, The PDS caliper of 19-Apr-08 was originally issued tied into ELMD but has since been corrected and is also tied into DD and is included in this program. • During the LDL, crude was pumped down the IA at a maximum rate of ~6 BPM @ 600 psi therefore the leak is significant and the well should circulate. The primary leak is at GLM #6, 7808' DD and a secondary leak is suspected at 8600' DD. • The well currently has primarily crude in the IA and diesel in the tubing down to the TTP. This leaves the tubing under balanced across the TTP and in the unlikely event the plug failed while running the patch, significant flow differential would be present. To mitigate this risk, the well will be circulated to inhibited sea water with a diesel freeze protect in the tubing and IA to condition and balance the well prior to setting the 3 • i patch. By freeze protecting down to a depth of ~4700' MD, this will leave ~150 psi overbalance on the formation. Assuming gas under the plug in the lower packer, ~60 psi overbalance at the 2-7/8" tubing tail. Due to the large displacement volume of the patch while RIH, inhibited water in the tubing will ultimately rise to a depth of ~980' if returns are taken only up the tubing. This would leave water across the permafrost zone. By having a deep freeze protect in both the IA and tubing as planned, taking nominal returns from the tubing combined with some returns from the IA will mitigate this risk by keeping all freezable fluids below the permafrost as the patch approaches landing depth. If returns are not taken while RIH, diesel can be u-tubed from the IA to tubing once the patch is close to bottom. The objective is to have the IA and tubing balanced before setting the patch. • Baker will model and determine the required spaceout due to extended patch length. This is typically 1' to 2'. • 2-7/8" 13-Chrome jointed pipe will be used for this patch. All patch material will be Chrome. There is plenty of it on site as well as all sizes of space out pups readily available in the warehouse. Contact is Les Peck or Jim Bolling to call out the pipe for the Klondike (659-4003). • Procedure will require 2-3/8" coil with WWP. • A coilcade has been run and is attached for 14-37 tubing patch. • Lower packer assembly was set and pressure tested 8/2/2008. 4 ~ . 14-37 SPECIFICATIONS/JOB PLANNING DETAILS: AnnComm history: o Well inoperable for TxIA communication o Well was SI September 2005 when IAxOA waiver was cancelled. Communication is likely through the wellhead. o IC hanger was treated with WKM and McEvoy sealant three times in 1992 and 1993. o Tubing packoffs were tested on 02/11/07 and passed. The PPPOT-IC (05/16/2006) was unable to be conducted because the void was plastic packed. o Recent online re-pressurization rates are lower than historic ones o IAxOA currently manageable by bleeds o Well passed a CMIT-TxIA 8/2/2008 and 2/3/2008 o Well passed MIT-OA 7/1/2005 Bottom Packer Set Depth @ 9305' DD. Depths Tied into SLB LDL dated 13-Sep-07. Leak Rate: Large ~5 bpm @ 600 psi (from CMIT-TxIA where FB pumped down IA and plug failed) Gas Lift Design: All valves are dummied off. Tag History: 7/22/2008 tagged/retrieved packer from 9716' SLM 12/19/2006 tagged soft bottom @ 9774' corr SLM Volumes: Tubing Volume: ~145 bbls IA Volume: ~500 bbls Liner volume to bottom perf: ~14 bbls FP Volume to 2500': = 38 (T) + 134 (IA) = 172 bbls Kill Volume: = 1.5 * 159 =~239 bbls Statics: 12/19/2006: 3291 psi and 217°F C 8800' TVD 5 ~ • PROCEDURE: Pre-CTU Weliwork 1) Take T and IA Fluid levels. a. Last Fluid Levels 7/30/2008: T@ 756' (11 bbls). IA C 132' (7.7 bbls). 2) MU LRS and associated equipment to circulate out T and IA. a. Circulate well with inhibited 1% KCL or inhibited seawater until well is dead. b. Pump sufficient diesel (250 bbls for IA, 71 bbls TBG =~320 bbls) to freeze protect the IA and tubing to ~4700` MD. This should result in ~150 psi overbalance. Pump small lead and tail spears of inethanol before and after diesel. c. Once diesel has been pumped into the well, slowly U-tube diesel and allow well to equalize. d. Bleed IAP and TBG to zero and monitor well for 30 minutes. e. RDMO WWP Preparatian 3) Remove well house and prep well for Work Platform. a. Ensure that the s-riser and gaslift line is de-pressured. b. Service and test tree valves. i. Tree last serviced 06/20/2008 for wireline, serviced swab 7/28/2008. c. Shoot T, IA, and OA fluid levels and make sure they are at surface. i. Should already be circulated out and fluid packed with FB. d. Record WHPs. If needed, bleed all pressures to 0 psi. 4) Check liner/patch handling equipment and other support equipment. Contacts are below. This list includes all required Vendors/Materials for WWP Operation. Check and finalize on slope. Please send any concerns or changes to Jennifer Julian! NOTE: This is a generic list for various types of tubing patches and scab liners. Carefully review service company BHA's, OD's, and tubing connections for the specific patch or scab liner to be run. Drill Site Maintenance (DSM) - CH2M-Hill (659-5182) Assorted Lifting Straps 6'-8' Cable Sling's - for elevators Assorted large shackles for elevator to sling connection Extra Well Support Hands to help with Liner/Pit watch and manage WWP support. Spacer spools for BOP's & thru rig floor extension ST-L and/or FL-4S lifting nubbins Assorted XO's - 1-1 /2" MT to 2-7/8" STL and 3-1 /2" FL4S Chart recorder with 1 hour - 15 minute clock Cat ID # 301419 Charts for the 1 hour - 15 minute clock Cat ID # 301421 Dowland-Bach HCR control panel with hoses to actuated gate valves - Actuator volumes = 0.223 gal. ea. Operatin pressure, w/5000psi on - Operating pressure, w/5000psi on valve =~973psi Flow cross w/ 2-1/16" Cameron FL gate valves and Baker Gatemaster Actuators TIW valves (these stay on the unit); three (3) should be available. - Three (3) TIW valves should be available - TIW valves should have 1-1/2" MT connections - TIW valves to be redressed and tested prior to each job - A large ID TIW may be required for possible DH tools needed C-Plate Snubbing line for backup tongs Baker - Thru Tubing (659-2367) / Fishing (659-2467) BHA Fishing Tools Safety Joint - Pipe & XO's Bowl Hand Slips Collar Safety Clamps Lifting Subs to cover full range of DH tools & pipe, including Safety Joint Job Specific - Liners, Packers, Etc. as required (Reference Wellwork Program) Schlumberger - Coil Lead (659-6122) 7-1/16" Hydril Annular Preventer 7-1/16" TOT Dual-Ram Preventer, w/ Blind-Shear rams CT (top) / Pipe-Slip rams CT (bottom) 7-1/16" TOT Dual-Ram Preventer, w/ Pipe-Slip rams for Liner (top) / Variable Pipe rams (bottom) Nabors Coil Crew - Casing (659-2450) Casing Crew Power Tongs, dressed w/ correct size dies Power Unit Back-up Tongs Elevators - YT for ST-L Flush and FL-4S Torque Gauge Feeler Gauge Stabbing Guides for CRA - appropriately sized Brushes Pipe Dope - approved for CRA tubulars CAM System computer Warehouse/Drilling Too/ Service* (659-4003 or -4009) 2-7/8" ST-L 13-Cr80 tubing - approx 182 jts plus variety of pUps (assumes 10% reiection and 30' ioints). Space out 7 patch components pre-WWP. Any other miscellaneous equipment Fluids/Tanks- (CH2MHill 659-5104): (P/ease verify these volumes. Well is secured with TTP, but will want enough f/uid on location for kill as a contingency. U/R's with 500 bbl 1% KCL non slick (Seawater is OK) U/R with 300 bbls 1% slick (Seawater is OK) MEOH Transport 40 bbl gauge tank 2 - 400's and Tiger Choke Manifold Supply line with HP hose manifolded to WWP floor Central Dispatch (659-5049) Third party (Peak) crane Perform site inspection and prepare lift plan as necessary prior to rigging up coil. 5) RU WWP. NU stack. 7-1/16" stack will include the following in order from top to bottom: • Hydril Annular • Blind/Shear Rams • Pipe/Slip Rams for 2-7/8" tubing • Flow cross to choke and kill lines with flanged connections out to through a hydraulic and manual control valve and flanged Kelly hose. • Pipe/slip rams fit for 2-3/8" CT • 2-3/8" x 3-7/8" Variable Rams Stack should be spaced out so that the top of the hydril is at the WWP rig floor level. Use 7-1/16" flanged spool below the stack to the tree and 7" quick connect riser above the tree if necessary. Schematic below: 8 Lubicator Ext. Top of Annular _• ~~ Bottom of Annular Blind/Shears 2-7/8" Pipe/Slips (Patch) Choke / Kill Lines 2-3/8" Pipe/Slips (Coil) 2-3/8" x 2-7/8" Variables X-over Tree (XO will attach to Swab or SSV depending on tree and mast heights) SSV ~ Lubricator ~ RIG FLOOR ~~ LubricatorlD = 6.375" with 6" Otis Unions Annular 7 1/16" Annular x 5000 psi 7 1/16" 5000 psi, RX-46 ~ z-~ie° co~ nnua c~oss 2-3/8" Cor ~ ~ 2.375" - 2.E Variable X-over -~ ~~ , ~ f ~~ ~ Master Valve -~ Base Flange i iai iyCU cvi u iacu~i i~ - manual and hydraulic Flanged Kelly Hoses to coil and choke Test & Monitor Line 6) Draft BHA: Make up blank patch assembly as per normal running procedure. PU the top Packer BHA consisting of CTC, swivel, XO, 1 or 2 Jts. PH6, XO, Hyd. Dis., packer running tool, and top packer. Patch to be set into lower packer element pre-set with EL @ 9305` DD. Lengths are approximate and should be confirmed with the final tally. Ensure that dual BPV (CT check) is not run due to the plug set in the lower packer assembly. Summary of BHA (DO NOT RUN UNTIL CONFIRMED BY BAKER - please finalize on slope): 9 Description OD ID Length Depth Depth to to bottom (max) (min) (feet) (top) (bottom) a 2 3/8" Coil Connector 3.38 1.00 1.05 b Lockable Swivel * 3.13 1.00 1.56 c Crossover 3.080 1.00 0.90 1 or 2 joints of PH6 tubing (reduces 2-3/8" CT helica/ effect on BHA 2.375 d Crossover 3.00 1.20 0.52 e Hydraulic Disconnect ( 7/8" ball) 3.00 0.812 1.45 f 4" GH Packer Running Tool Set To Disconnect at 3500 psi 5/8" setting ball or hydraulic re/ease 3.63 0.59 1.92 Total Runnin Assembl OD (max) ID (min) Length (feet) Depth (top) Depth (bottom) g 4.5" Chrome KB Liner Top Packer 3.70 2.56 5.10 h Crossover, 4.5" 10rd NUE Pin X TBD TBD TBD 2.875" ST-L Pin i ~182 joints 2-7/8" 6.4# 13 chrome 2.875 2.441 TBD ST-L blank pipe plus pups as needed for space out and tie-in I XO to 2-7/8" Seal Assembl Locator Assembl 2-7/8" STL Box 3.68 2.39 0.35 0 2-7/8" Baker Seal Unit + Spacer 3.00 2.39 9.50 Tub to Locator (we'll be stabbing into the 4.5" Baker lower packer assembt set eariier b wireline BHA TOTAL BHA & Running Assemblv ** Total Wt of assembly is estimated to be ~32,000 Ibs and will require third party crane. ** Baker 45 Packers for 4-1/2" tubing are rated to 3500 psi over under differential. 7) Arrange for the delivery of the following to be set on pipe racks. Contact Les Peck or Jim Bolling in the warehouse at 659-4003. Contact Nabors @ 659-2439 or pager 659-3645 for the pipe racks. a) ~180 joints 2-7/8"13-Chrome blank joints (assumes 30' joints and 10% rejection, may want more - wellwork platform cannot handle joints longer than 30'). Include a variety of space out pups to be readily available. All pipe should be ordered and ready (verified with Chris Wooster.) 10 ~ • • Rabbit ALL BHA components of extended patch and drift with 2-7/8" TTP!! • Have BOT make up as much of the top packer assembly as possible in the shop to reduce the number of connections necessary when stabbing onto the patch. • Tally, drift with 2-7/8" TTP, and number the joints. Ensure CH2MHill straps all pipe without the threads. If there are previous #' on the pipe, remove them. • MU lifting nubbins with 24" pipe wrench and back-up. • Pre-load as much of the 2-7/8" tubing in the pipe rack as safely possible and for ease of deployment prior to job. • Note all OD's, ID's and lengths on the tubing tally. • Ensure the BHA has no square shoulders "looking down" or "looking up" in the event that it has to be pulled back OOH. 8) Function test and pressure test BOP stack prior to the arrival of the CTU if possible. Make up test joints. Arrange with SLB and CH2MHill to have completed before service coil's arrival. NOTE: AOGCC will need 24 hours notice to witness BOP test. Their number is 659- 3607. GT Operatians wi#h ~he WWP ** Please use 9/13/2007 SLB LDL as reference log. All depths tied in with E~D. 9) RU CTU to WWP. Pig the CT with the maximum diameter for the chemical cutter used in case it is needed. This may have been completed prior to this job; ensure current CT tracking log indicates the drift. If the last operation was cementing or a sand dump, it is prudent to ensure there are no debris in the coil that could end up on the ball seat, or worse, not allow a chemical cut. Pump a gel pill if warranted to clear coil. Leave coil fluid packed with diesel prior to running patch. 10)MU BOT CTC and pull test. MU lockable swivel and stand back injector head. 11)Call out 3rd Party Crane (Central dispatch C«~ 659-5049) 12)Clean rig floor and prepare for patch with Nabors and CAM system computer. 13)Monitor returns to ensure well is dead. Conduct no-flow tests. 14)MU crossover and open TIW valve on top 2-3/8" safety joint. Position this assembly in the tubing board for quick access and ensure wrench is on floor and properly identified. 15)Hold well control drill with the safety joint so personnel are prepared to stab it in short order as needed. Document drill in AWGRS. 11 ! ~~ 16) Space out patch to position upper sealing element at 4400' DD. Reference 09/13/2007 SLB LDL (tied in with DD). Total assembly length will be ~4905'. Install pups to achieve required length and tie-ins. 17)Make up blank patch assembly as per normal running procedure and RIH with seal locator assembly. Patch will be run open ended so it will not need to be filled while RIH. Use a dog collar on every joint of patch and any assembly with no slip recess. Be sure ALL components are drifted with TTP in the shop. Patch running notes: • Use standard WWP operating procedures. Will need third party crane as WWP crane is not sufficient to run entire patch. Total assembly should be ~32,000#. • Lockable swivel will be used to rotate patch assembly if there are problems stabbing in to lower packer • If the well starts to flow while the upper patch assembly is being run, close slips, close the annular preventer. Contingency kill if lower packer and plug lose integrity is to pump into well with KCI water. Kill volume = 1.5 x WBV = 236 bbls. IA Volume to the packer is 500 bbls (this may be needed to kill well due to high TxIA leak rates. (This volume includes Liner, T, and IA due to large TxIA leak rate) • Review RPs for operation of the WWP for further contingency options (attached). The appropriate TIW stabbing valve and wrench must be on WWP floor and properly identified prior to makeup of the patch. • Special handling is required for chrome. Review RPs for Chrome tubing handling and operating procedures (attached). • Document all lengths, ID's, and OD's of the patch and record on BP standard liner summary sheet. Be sure to file in well file and download to s: drive for documentation. • Check the load rating on the straps that hold the elevators. You may need stouter straps for this patch. • Run patch into well slowly with crane to avoid fluid surging up through each joint and squirting out the vent holes on the lifting nubbins. This could result in a spill. 18)PU and pull slips, bowls, etc. PU string and hang in BOPs. 19)Close pipe slips on patch. Slack off. Stab TIW valve onto patch. 20) MU Baker patch running BHA including: 1 or 2 Jts, PH6, XO, Hyd. Dis., cire sub, packer running tool, and top packer assembly (finalize with Baker). 21)Lay down TIW valve. PU BHA and MU to 2-7/8" patch. a. Move injector up to WWP floor and strip down to stab into patch with top packer assembly. The patch will be set in the BOP slips. b. Pull test running tool connection against the slips to + 5k over string weight per Baker recommendations. Pull test will ensure the setting tools are securely attached to the to acker and able to handle the wei ht of the atch before the sli s are o ened and 12 l J ~ the problem is found out the hard way. c. Slack off to estimated string weight. d. Open BOP slips e. Set electronic counter to patch length. 22)RIH with patch assembly at ~60 fUmin. Slow down across jewelry. NOTE: As patch is RIH, freezable fluids will be displaced uphole. Calculate volumes and once inhibited water is ~2500'. SI tubing and continue taking returns from the IA while holding backpressure to prevent u-tubing. 23)With end of BHA at ~9250', record pick-up, slack-off, and neutral weights. 24)With pumps off, continue RIH to stab seals into lower packer (mid-element set @ 9305' DD), set upper packer, and pressure test as summarized below. Service company (BOT) will finalize this sections: • RIH and stab Seal Assembly in lower packer with +/- ~2000 Ibs compressive weight (on indicator). PU to space out locator ~ 1' to 2' above tie back sleeve as per Bakers tubing movement calcufations. • Pressurize coiled tubing to 2500 psi (adjust as necessary for current hydrostatics) to set packer (calculated setting pressure required to set packer is 2100 psi differential). Bleed Off pressure. • Pick up on coiled tubing to +/- 3000 Ib., above recorded pick-up weight, to verify top packer is fully set. Slack off to ~5,000 Ibs down as per Baker representative. • Pressurize CT x T annulus to 500 psi to test packer sealing integrity. • Once testing is complete, bleed off annular test pressure. Slack off to ~10K#'s down weight at the packer. • Increase coiled tubing pressure to 3800 psi to release Setting Tool from packer (calculated pressure to release setting tool from packer is 3500 psi). Pull out of hole with Setting Tool. Note: After released from the packer, circulation ports of the Setting Tool are exposed to facilitate circulation or jetting out of the hole. • Ensure well is freeze protected and POOH. 25)MIT-IA to 2400 psi. (Note: 2400 psi surface test pressure will result in 2715 psi pressure differential at the patch due to different fluids in/out side of patch.) a. If passes, will not need state witnessed MIT-IA. b. If fails, LLR. Contact Jennifer Julian or Tiffany Quy for next step. May need further diagnostics (LDL). 26)Once at surface, tag well noting wefl is freeze protected and secured. 27)RDMO CTU and WWP. Send request to replace wellhouse and AL line. 13 28) RU SL. 29)Set GL design per gas lift engineer (Johnny/Stan @ 659-5863) specification. 30)Pull 2-7/8" plug from x-nipple from lower packer assembly (~9315'DD). 31) Drift and tag to TD. 32) Notify operations to POP. List of Fiqures: Patch schematic Wellbore Schematic BOT Bottom Packer Assembly Drawing Tie-In log Tubing Tally Caliper Summary Hazard Identification - to be reviewed and finalized on the slope List of Attachments: (These Recommended Practices all found in attached PDF): ATTACHMENT A: AD&W RP for Operation of the WWP ATTACHMENT B: AD&W RP for Running and Handling 13-Chrome ATTACHMENT C: AD&W RP for Running and Cementing a CTD Liner ATTACHMENT D: ADW RP for Rigging and Lifting ATTACHMENT E: ADW RP for Crane Specification and Handling ATTACHMENT F: ADW RP for Mobile Crane Critical Lift Procedure • Attachment A- Lift Plan Template and Calculations • Attachment B- Lift Plan Checklist 14 i r~t = rn,~. ~r~v 4 W E1LFfAD = . . _ _ _m. FMC ~.__. . _ . ACTl1ATOR= - . AXELSON _ . _- KB. ~EV = ~ 74' BF. ~EV _ . _.. KOP = ° 3900 Max Angle = 36 Q 7700' DaNm MD = 96a7' _._._ . DatumND= 8800'SS ~ ~ SAFETY NOTES: "'WELL HAS HtSTORY OF CA CO 14-37 SCALE ~i~ ~133+8' CSG. 721f. L-80, D=~2.sar H 3~ Minimum ID = 3.725" @ 9413' 4-1/2" OTIS XN NIPPLE ~4905' Jointed Chrome Patch will be run from 4400' DD - 9305' DD IroPOFr ~r~ I I 2023' I KID OUT (03/31/94) GAS LIFT MArDf1ELS ST A~D ND DEV TYPE VLV LATCH POFZT QAlE 1 3193 3193 0 FM10 DMY Po( 0 04l02l07 2 4110 42Q3 17 Fh110 DMY RK 0 12/21/88 3 5241 Stt6 31 FMiO DMY PoC 0 06/26/93 4 6160 5900 30 FM10 ~MY RK 0 04102/07 5 6982 6602 31 FMiO DMY PoC 0 07/31/97 6 7808 7290 36 FM10 'DhAY PoC 0 01/30J08 7 8293 7684 35 FM~O DhfY Po( 0 07121l98 8 9077 8358 26 FMiO DM+f Po( 0 12/21/88 9 9198 8466 25 FTo1i0 D6MM PoC 0 08J17/93 "S1A if~ F1AS tJ(I tNJtU YA(]CWIi 9300' H~sre•xa-~irexROe~.~=~ Lower Packer Assembly set mid element (~1 9305' DD. TTP is installed and passed CMIT-TxIA . 41f2' OT~ XN NP, ID = 3.725' ~4112' TBG•PC, 12.6#, L-80..0152 bpf. D=3.958' ~ ~tFVRanori sunnnno,Rr I~ LOG: BHCS ON OSI29/88 A NGLEAT TOP P6iF: 24 (dl 9540' Note: Ref er to Roducdon DB for historical perf data S¢E SPF 1~(TS~VAL OpNSqz DATE 4' 4 9540 - 9557 C 12/17f88 4' 4 95A6 • 9628 C 12/17f88 4' 4 9630 - 9646 C 12/17/88 2-7l8' 6 9670-9675 C 12l26J98 2-7/8' 6 9713 - 9716 C 12/26JJ8 2-7/8' 6 9T42 - 9747 C 12/26/98 3-3/8' 6 9754 - 9760 C 10/05/94 4' 4 9760 - 9768 C 1211T/88 3-3/8' 6 9760 - 9764 C 10l05J94 ,v: FISH - KB FKR PARTS FISH • OGLV (07/3Q+9 FISFI• 3' OF .JD PILLN FISH - BRIDGE PU1G ( FISH • 1-112' MGGLV QATE F~/ BY COMMENTS QAlE REV BY COMrBdTS PRUDFIOEBAY Ud(T 10f03188 OFaGINAI COMPLETION 05/04J08 JRA/PJC PULL PXN. GLV CORRECTION WH.L: 1437 14/21/88 LAST VYORKOV ER 071031Q8 RCCJPJC STRDL RCR witiNJLE5H0E(06J14a ) P9thif No: ~188(I490 07/22+06 DAVlPJC TRSV LOCKm0UTI3J31l9S) 071081Q8 SWGPJC FISH PKRPARTS (06i23~'QB) ARNo: 50-029-21810~OQ ~ yaz5' t--1ai~r w~w. ~u=s.y~s- I 9405' aF,n rr ~oc~cm os~~2s~as 15 os/2slo7 SChlll~ilh~l'I~~I' N0.4440 Alaska Data & Consulting Services ~~.+b13~~ ~1~y ,t ey ~~~~ Company: State of Alaska 2525 Gambell Street, Suite 400 ~.+ b13 LJ Fi o Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well .Inh $ Inn nncrrinfinn n~sn Qi C..1... rn 15-39A 11661174 MEMORY PROD PROFILE 09/23/07 W-42 11745235 MEM SBHPSITEMP 09N4/07 Z-07A N/A SBHP SURVEY 09!14!07 1 A-04 11594519 SBHP SURVEY a - 08/26107 1 Y-24 11630499 LDL 09/04/07 1 L5-28A 11855810 PRODUCTION PROFILE - b 08/31107 1 X-33 11849931 SBHP SURVEY S - ~JL 08/31/07 1 E-14A 11686784 LDL -~ ~ 09/23/07 1 01-15A 11855509 DDL ~ - a~ b 09122/07 1 D-21 11626119 PRODUCTION PROFILE ~jf'~ - ~ 09/11107 1 K-07D 11745234 MEM PROD PROFILE C - 09106/07 1 11-32 11630498 PRODUCTION PROFILE j L _ 09/03/07 1 L-01 11745233 MEM LDL ~ (~ ~ - ~ 09/04/07 1 07-30A 11661168 MEM STP & CORRELATION 08128/07 1 Z-28 11630500 INJECTION PROFILE ~_ 09/05/07 1 Z-16 NIA SBHPS/JEWELRY / 09/13/07 1 14-26 11676959 LDL ./j 09/09/07 1 04-02A 11630504 LDL j 09111/07 1 14-37 11695075 LDL 09/13/07 1 3-351E-36 11630502 PRODUCTION PROFILE 09/09/07 1 f'LCIipG FiV f\n VYYLCVVC RCli Clr' 1 6i JIVry1ryV HryV.RC 1 VKryiry~' VNC VUr'C CAlil'1 1 V: ,., ~ .,. BP Exploration (Alaska) Inc. '" Petrotechnical Data Center LR2-1 - 900 E. Benson Blvd. Anchorage, Alaska 99508 ~~°-,~~~ sa °a (`a{1~ '~,a~ _ Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-28 ~ ATTN: Beth Received by: • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown _ Stimulate_ Plugging_ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2363' FNL, 1636' FEL, SEC. 09, T10N, R14E, UM At top of productive interval 2167' FNL, 844' FWL, SEC. 09, T10N, R14E, UM At effective depth At total depth 2087' FNL, 4580' FEL, SEC. 09, T10N, R14E, UM 5. Type of Well: Development__X Explorato~ Stratigraphic__ Service__ 6. Datum elevation (DF or KB feet) RKB 77 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 14-37 9. Permit number / approval number 88-49 10. APl number 50-029-21810 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summar Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 1 10' Surface 3401' Production 9549' Liner 668' 10009 feet Plugs (measured) 9205 feet PBTD tagged @ 9767' MD (12/26/98) 89849767 feet feet Junk(measured) 0RJGINAL Size Cemented Measured Depth True vertical Depth 20" 2150# Poleset 110' 11 0' 13-3/8" 200 Sx CS H, 200O Sx CS m, & 3478' 3478' 600 Sx Class G 9-5/8" 88o Sx C~ass G 9626' 8855' 7" 450 Sx Class G 10009' 9205' Perforation depth: measured 9540' - 9557'; 9596' - 9628'; 9630' - 9646'; 9670' - 9675'; 9713' - 9716'; 9742' - 9747'; 9754' - 9768'; true vertical 8777' - 8792'; 8828' - 8857'; 8859' - 8873'; 88895' - 8900'; 8934' - 8937'; 8961' - 8966'; 8972' - 8985'; Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 4-1/2", 12.6#, L-80 PCT @ 9425' MD. 9-5/8" x 4-1/2" Baker DB Packer @ 9300' MD. 4-1/2" AVA TRSV SSSV @ 2022' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. OiI-Bbl Prior to well operation 138 Subsequent to operation 229 Representative Daily Average Productionorlnjection Data Gas-Mm Water-Bbl 100 4242 1008 6231 Casing Pressure Tubing Pressure - 242 - 240 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations .__X 16. Status of well classification as: Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ba~'"~Erin 0 ~'~['~ Title Arco Engineering Supervisor Prepared by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 14-37 DESCRIPTION OF WORK COMPLETED PERFORATION Date Event Summary 12/26/1998: MIRU ELU. PT'd BOPE. RIH w/perforating guns to PBTD @ 9767' & shot 13' of Add Perforations @' 9670'-9675' (Zone 4) Ref Log: BHCS 9/29/1988. 9742' - 9747' (Zone 4) 9713' - 9716' (Zone 4) Used 2-7/8" carriers and all shots were 6 SPF, underbalanced, 60° phasing, & random orientation. POOH w/guns. ASF. RD. Returned well to Production & obtained a valid well test. STATE OF ALASKA ALASKA _ AND GAS CONSERVATION CC .41SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perlorate X Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 2363' FNL, 1636' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 2167' FNL, 844' FWL, Sec. 9, T10N, R14E, UM At effective depth 2159' FNL, 829' FWL, sec. 9, T10N, R14E, UM At total depth 2087' FNL, 698' FWL, sec. 9, T10N, R14E, UM 5. Type of Well Development Exploratory Stratigraphic Service X 6. Datum of elevation(DF or KB) 77 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 14-37 9. Permit number/approval number 88-49 10. APl number 50 - 029-21810 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 10009 feet 9205 feet Plugs(measured) PBTD Tagged @ 9765' MD (10/5/94) Effective depth: measured true vertical Casing Length Size Conductor 80' 20" Su dace 3443' 13-3/8" P roductio n 9594' 9-5/8" Liner 668' 7" 9765 feet 8982 feet Junk(measured) Cemented 2150# Poleset 2000 sx CS III & 600 sx CI G, Top job w/200 sx FS II 880 sx C I G 300 sx Cl G & Sqzd liner lap w/150 sx CIG Measured depth 110' 3478' 9626' 10009' True verticaldepth 110' 3478' 8855' 9205' Perforation depth: measured 9540-9557'; 9596-9628'; 9630-9646'; 9754-9768' true vertical 8776-8792'; 8827-8856'; 8858-8873'; 8971-8985' Tubing (size, grade, and measured depth) 4-1/2", L-80, 12.6#, PCT @ 9425' MD RECEIVED V -' 1 1994 Gas Cons. Commission Anchor~_., :; Packers and SSSV (type and measured depth) 4-1/2" AVA TRSV SSSV @ 2022' MD; baker DB packer @ 9300' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure '14. Prior to well operation Subsequent to operation ..R...epresentative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 831 2992 4609 865 3405 4463 Tubing Pressure 258 279 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x Gas .. Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,¢~~~~~,~///~,,¢,~/~'"~' (-'/' Title Engineering Supervisor Form 10-404 Rev 06/15/88 1248/15 cc: KZ, JWP Date SUBMIT IN DLf"PLICATE 14-37 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED I 0~5~94: MIRU & PT equipment. 10' of perforations as follows: Added perforations: 9754 - 9760' MD (Z3) Reperforated: RIH w/perforating gun & tagged PBTD at 9765' MD, then PU & shot Ref. Log' BHCS 9/29/88. 9760 - 9764' MD (Z3) Ref. Log' BHCS 9/29/88. Used a 3-1/8" carrier & shot 6 spf at 60 degree phasing, at underbalanced pressure. POOH w/perf gun. Rigged down. Returned the well to production w/gas lift & obtained a valid welltest. GeoQuest r~x] W. Intemalional Airport Road Anchorage, AK 99618-1199 ATTN: Sherrle NO. 8993 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 10/13/94 Field: Prudhoe Bay Well Log Description BL RR Sepia RF Sepia Mylar D.S. 11-16ST#1 ~1~(., '{ 'D_.~EAKDETEOTION(10-4-94} 1 1 D.S. 14-01A cf "~ _ I ~ ~ DUAL BURST TDT-P (10-3-94} 1 1 D.S. 14-16 ~'~ ~ ~ DUAL BURST TDT-P (10-4-94} 1 1 D.S. 14'23 ~ ~- ~ ~ GAS LIFT SURVEY (10'5-94) 1 1 D.S. 14-37 ~'";?' ,ERF RECORD (10-e-94} 1 1 Please sign and return one copy of this transmittal to Sherrle at the above address. Thank you.- DATE: ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska ~510 DATE: REFERENCE: ARCO CASED HOLE FINALS -11 1-24-93 Perf Record -11 2-7-93 Peri Record Run 1, 5" 1-13 2-7-93 Peri Record Run 1.5" /~.~1-24A 2-20-93 Peri Record Run 1, 5" ~'-Z-~~1-30 1-24-93 Peri Record Run 1. 5" 2-14 7-27-91 TMD Run 1. 5" 3-9 12-19-92 Peri Record Run 1, 5" ~._~.~J~k3-24 1-25-93 Peri Record Run 1. 5" ~/3-32 4-25-92 P(IST Computed Results Run 1.5" "~a:-~ 3-32 4-25-92 PSGT Run 1.5" q.~_~~-32 2-19-93 Peri Record Run 1.5" -~3-34A 2-19-93 Peri Record Run 1, 5" .4-35 8-16-92 TMD Run 1, 5" 8-18-92 TMD Boron Injection Run 1, 5" ;.. ,,, ,.,,,-,,..,,or. ,,,,.,,,,., 3-2-93 Peri Record Run 1.5" ., 3-1-92 PSGT Computed Results Run 1, 5" 9-27 3-1-92 PS(IT 5 Ft/Min Run 1, 5" q'~-'~,., ~-27~~I 3-1-92 PS(IT 10 Ft/Mln Run 1.5" 2-6-93 Peri Record Run 1.5" - 2-8-93 Perf Record Run 1, 5" 1-1 4-21-92 P S(ITCo ut ed Results Run 1, 5" mp 1-1 4-21-92 PS(IT Run 1.5" 1-13A 3-8-93 Peri Record Run 1, 5" 1-18 4-14-92 PSGT Computed Results Run 1, ~' 1-18 4-14-92 PS(IT Run 1, 5" --12-4A 2-11-93 Peri Record Run 1, 5" ~..~\c~%.-~12-19 2-11-93 Peri Record Run 1, 5" 12-29 12-22-92 Peri Record Run 1, 5" .~12-32 12-26-92 Peri' Record Run 1, 5" /14-5A 2-20-93 Peri Record Run 1, 5" -~14-12 4-24-92 PS(IT Computed Results Run 1, 5" 4-12 4-24-92 PS(IT Run 1, 5" ~~14-37 4-13-92 PS(IT Computed Results Run 1, 5" ~~14-37 4-13-92 PSGT Run 1, 5" RECEIVED APR 9 199 ~aska Oil & Oas Cons, Commle~lon Run 1, 5" Run 1, 5" Run 1, 5" Run 1, 5" Run 1, 5" 6-21 7-23-92 PSGT Computed Results 6-21 7-23-92 PSGT 6-27 8-23-92 Peri Record 7(~ ~16-30 2-12-93 Peri Record ~ ~~17-21 12-20-92 Peri Record _~-~.. Please sign and return the attached copy as receipt of data. Sonya Wallace ATO- 1529 Trans# 930 HIS HIS HIS HIS HIS HIS HIS HIS HIS HIS HIS HIS HIS HIS HIS HIS HIS HIS HIS HIS HIS HIS HIS HIS H£~ HIS HIS HIS HIS HIS HIS HIS HIS HIS HIS HIS HIS HIS HIS HIS # CENTRAL FILES # CHEVRON # LUCILLE JOHNSTON # EXXON # PHILLIPS # MOBIL # BPX # STATE OF ALASKA * The correct api# for 3-32 is 50-o2g-21141-00. ---- STATE OF ALASKA ALASKA _AND GAS CONSERVATION CC' 'AISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed' Operation shutdown Stimulate X Plugging Perforate Pull tubing Alter casing Repairwell Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 2363' FNL, 1636' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 2167' FNL, 844' FWL, Sec. 9, T10N, R14E, UM At effective depth 2159' FNL, 829' FWL, Sec. 9, T10N, R14E, UM At total depth 2087' FNL, 698' FWL, Sec. 9, T10N, R14E, UM 5. Type of Well Development , X Exploratory Stratigraphic Service , , RECEIVED SEP 1 6 1991 Alaska 0ii & Gas Cons. Corn~s~'te~ 'Anchorage 6. Datum of elevation(DF or KB) 77 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 14-37 9. Permit number/approval number 88-49 10. APl number 50 - 029-21810 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 10009 feet Plugs(measured) 9205 feet Effective depth: measured true vertical Casing Length Conductor 80' Sudace 3443' Production 9594' Liner 668' Perforation depth: 9638 feet 8866 feet Junk(measured) Size Cemented Measured depth 20" 2150# Poleset 110' 13-3/8" 2500 sx CS III & 600 sx CI 'G' 3478' Top job w/200 sx CS II 9-5/8" 880 sx CI 'G' 9626' 7" 300 sx CI 'G' 10009' Sqzd liner lap w/150 sx CI 'G' True vertical depth 110' 3478' 8855' 9205' measured 9540-9557'; 9596-9628'; 9630-9646' [9760-9768': isolated below bridge plug] true vertical 8776-8792'; 8827-8856'; 8858-8873' [8977-8985': isolated below bridge plug] Tubing (size, grade, and measured depth) 4-1/2", L-80, 12.6#, PCT @ 9425' MD Packers and SSSV (type and measured depth) 4-1/2", AVA TRSC SSSV @ 2022' MD; Baker DB packer @ 9300' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Shut in. 1086 1753 4864 Tubing Pressure 432 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil, X,,, Gas Suspended Service 17. I hereby certify that t!~ ~----~"~'~'~J foregoing is true and correct to the best of my knowledge. Signed Title Sr. Area Operations Engineer Form 10-404 Rev 06/15/88 753JCA c: SW, JWP Date SUBMIT IN DUPLICATE DS 14-37 DESCRIPTION OF WORK COMPLETED BRIDGE PLUG INSTALLATION & FRACTURE TREATMENT OF SAG/Z4 3/24/91: MIRU & PT equipment, then RIH w/CT mounted Inflatable Bridge Plug & set plug at 9730' MD (center of element), to isolate high water production perforations at: 9760 - 9768' MD (Z3) Ref. Log: BHCS 9/29/88. Pumped 2 bbls of 20/40 mesh sand slurry down the CT, to place a sand plug on top of the Bridge Plug. POOH. Rigged down. 3/25/91: RIH & tagged top of sand plug at 9722' MD. 7/1 8/91: MIRU & PT equipment to 9000 psi, then pumped a Propped Fracture Treatment using gelled water & intermediate strength proppant through the perforations located above the Bridge Plug/Sand Cap, at: 9540 - 9557' MD (Sag) 9596 - 9628' MD (Z4) 9630 - 9646' MD (Z4) Ref. Log: BHCS 9/29/88. Pumped: a) 262 bbls 10# Gelled Pre Pad, @ 30 - 46 bpm, followed by b) Shutdown. ISIP @ 2088. Resumed pumping: c) 833 bbls Crosslinked 40# Gelled Pad, @ 45 bpm / 4000 psi, followed by d) 428 bbls Slurry w/proppant concentrations of 2 to 10 ppg, followed by e) 145 bbls Flush. Placed a total of 116,000 lbs of proppant into formation. Rigged down. 7/26/91 & 8/1 7/91: Performed proppant fill cleanouts down to 9700' MD. Returned well to production w/AL and obtained a valid production test. Alaska Oil & Gas Cons. 'Anchorage ARCO ALASKA, INC. F'. O. BOX i ANCHORAGE, ALASKA 995i DATE: 7-26-9t REFERENCE: ARCO CASED HOLE FINALS -tO 6-26-9t F'ROD F'ROFILE 2-t2 6-29-9~ PROD PROFILE 3-33 6-26-9~ PROD PROFILE 9-0 6-~9-9~ LEAK DETECT ~~9-38 ?-~-9~ INJ PROFILE 2,&.9-44 6-i *-9t F'ERF RECORD 2-2; 6-t 5-9t COLLAR LOCA'rOR t4-Jt 6-t 5-9t F'ERF LOG 4-:;37 6-i 0-9t PITS i5-6 6-28-9i PITS 8-i 4 6-24-9i F'ITS RUN i, 5' RUN ~, 5' RUN t, 2'&5' RUN t, 5' RUN t, 5' RUN RUN i, S' RUN t, 5' RUN i, 5' RUN i, 5' RUN i, S' PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA. HAVE A NICE DAY! SONYA WALLACE ATO-i529 CAMCO CAMCO CAMCO CAMCO CAMCO HLS HLS HL$ HRS CAMCO CAMCO DISTRIBUTION CENTRAL FILES CHEVRON D & M EXTENSION EXPLORATION EXXON MARATHON MOBIL PHILLIPS F'B WELL FILES R & D BF'X STATE OF ALASKA TEXACO RECEIVED JUL 2 $ 1991 'qlaska Oil ~ ~as Cons. ~nchorage O°rnrnission ARCO ALASKA, INC. P.O. BOX i(.)0S66~ - ANCHORAGE, ALA;~'KA 995i ¢, DATE' 9-'!8-89 REFERENCE · 4-5 4-t9 7'-28 9-2 9'--S2 9-S6 i2-28 i 2.-St i 2-3J¢ iS-J4 i4-S7 i6-6 i6-i8 i6-2~ i PLEASE ARCO PRESSURE DATA 8-.50-89 BHF'--£TATIC GRADIENT 8-29-89 BHP--$TATIC GRADIENI' 8-29-89 BHP--$TAI'IC GRADI EN'f' 7-5-89 BHF'--$1'AT I C GRADZEN'¥ 9-:2-89 BHP--~TA'rlc GRADIEN'[ 9-2-89 BHP--~TATIC GRADIENT 8- i 5-89 · BHF'--FLOW I NG GRAD I EN'r 6-5-89 BHP--~TATIC GRADIENT 6-5-89 ' BHP--~TATIC GRADIENT 8-t~-89~ BHP--~TATIC GRADIENT 9-2-89 BHP--~TATIC GRADIENT 8-iS-89 ~ BHP--~TATIC GRADIENT 8-2t -8-9 BHP--FLOWING GRADIENT 8-t5-89 BHP--~TATIC GRADIENT 8-tt-89 BHP--~TATIC GRADIENT N AND RETURN THE ATTACHED COPY AS C A id C 0 CAMCO CAMCO HRS CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO (;ANCO CAMCO HRS CAMCO CAMCO RECEIPT OF DATA. RECEI'v'ED BY HAVE A NICE DAY! SALLY HOFFECKER ATO-i5'' ~9 DISTRIBUTION CENTRAL FILES ~ ~ ,PHILLIPS CHEVRON F'B WELL FILES D & M ~ ~ R & D EXTENSION EXPLORATION ~ BF'X EXXON ¢ $I'A'I-E OF ALASKA MARATHON ~" TEXACO MOBIL ARC(] ALAS'UA, INC P.,O~ BOX i.3('):36~~. ANCHORAGE, ALA~,~i<A 99-5i (3 DATE' 7-i 0-89 REFERENCE' ARCO CA~ED HOLE FINALS i_.'.)~ ~: ;o.-~ '~4/89 LEAK I)ETECTION RCN i · -3-i 6-i4--89 F'RODUCI-ION F'ROF'II_E RUN i , :3-26 6-2t-89 F'i:~:ODUCTION PROFILE RIJi'~i , :3-:34 6-i 3-89 F'I;:ODUCTION F'ROF.[L.E RUN i , ~.-~4 6-t 9-89 F'II-S RUN i , 4--t 9 6-!5-89 IN. JECTION F'ROFILE RUN ~ , 4-:3i 6-t 4-89 i'EMP RUN i , 9-i6 6-t 8-89 INJECTION PROFII_E RUN i, ti-i 6-t 6-89 PF:.'.ODUCTION F'ROFILE RUN i , ii-24 6-i -?-89 PRODUCTION F'ROFILE RUN t, t3'-6 6-23-89 IN.JEC'f'ION PROFILE RUN t , I4-27 6-25-89 F'F(ODUCI':[ON F'ROFILE RUN t, t4-37 6-26-89 PRODUCTION F'ROFILE RUN t, t4-:38 6-2:3-89 PRODUCTION PROFILE RUN t, t6-9 6-"22-89 F'RODUCTION PROFILE RUN i, PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA RECEIVED BY HAVE A NICE DAY! £'ALLY HOFFECKER A'FO- t 529 "F R AN ~' ~- 89~86 CA~]L;O C A p, C 0 C A M i.; U CAriCO C A ~-"i C 0 C A ~ C 0 CAMCO C A M C 0 CAMCO t]AMC() CAMCO CAMCO CAMCO CAMCO CAHCO DISTRIBUTION CENTRAL FILE~' CHEVRON D &.M ' .- EX'FEN£ION EXF'LORAi'ION EXXON MARATHON ' MOBIL .' ~'"' F'HILLI F'S' t~'B WELL F'ILE~¥ R & D '...I: B F'X -.- :,,'~'AI'E OF F~LAEKA ~."' i"EX~CO ARC() ALA~:KA, INC, F'~ O, BOX i ,.'-}(')S6£.~ ANCHORAGE, ALASKA 99510 DATE' 7-t 0-89 REFERENCE' ARCO CAS'ED HOLE F tNALS' __- ;... · .'o.- 5-t 6-i 4-89 3-26 ,"~_, -')_ i -89. S-34 6-~ S-89 ~!-S4 6- ~ 9-89 4- t 9 6- i '5-89 4-5~ 6-t 4-89 9-t 6 6-t 8-89 t i -t 6-t 6-89 t 'i -24 6-! 7-89 ~S'-6 6-25-89 t 4-27 6-25-89 t 4-S7 6-26-89 ~ 4-58 6-2S-89 t 6-9 6-22-89 /89 LEAK I)ETECTION PRODUCTION PRO!"' I LE PRODUCTION PROFILE PRODUCTION PROF J-'LE PITS INJECTION PROFILE ]'EMP INJECTION PF,,'OF I LE PRODUCTION F'F;,'OF' I LE PF,.:ODUCT I ON PROFILE INJECTION PROFILE PRODUCTION F'ROFILE PRODUCTION PROFILE PRODUCTION PROFILE PRODUCTION PROFILE RUN i , '2 "6:5" F;:U,'"4 i., ':.5" RLJN i , 5" l;:tJN, i, 5" RUN i , 5" RUN i, ..5 ' RUN t, .;~'" RUN i , 5" RUN t, 5" RUN t , ~' RUN t , .5" RUN t , 5' RUN t , 5" RUN t , ~' r. Ti RUN i , .... F'LEA~E SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA C A H C 0 C A M C 0 C A d C 0 C A ~'~ C 0 CAHCO C A H C C) C Arq C 0 UA¢iCO CAMCO CAMCO C A M C 0 CAHCO CAHCO RECEIVED BY HAVE A NICE DAY! SALLY HOFFECKER A'FO- t 529 CENTRAL FILES CHEVRON D &~M EXTEN£IO~ EXPLORATION EXXON - · '' MARATHON', ~.' MOBIL APPROVED ¢__ f'RAN$~ 89286 "" F'.H I L L I F'5' ir F'B WELL FILE,',,' R & D ~: BF'X ~ Si'ATE OF- ALA~'KA · "' 'f'EX~CO REVISED ' STATE Of ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION '*WELL COMPLETION OR RECOMPLETION REPORT AND LOG .__ 1. Status of Well Classification of Service Well OIL ~ GAS [~] SUSPENDED ~ ABANDONED i~] SERVICE [] 2. Name of Operator 7. Permit Number 88-49 ARCO Alaska, Inc. 3. Address 8. APl Number P_13 Rn~ 1¢113~¢,(3~ An~hnr~n~e~ AK 99510-0360 50- 029-21810 4. Location of well at surface 9. Unit or Lease Name 2363' FNL, 1636' FEL, Sec. 9, T10N, R14E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 2167' FNL, 844' FWL, Sec. 9, T10N, R14E, UM 14-37 At Total Depth 11. Field and Pool 2087' FNL, 698' FWL, Sec. 9, T10N, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool RKB 77' ADL 28312 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. ! 15. Water Depth, if offshore 16. No. of Completions 09/11/88 09/28/88 12/20/88*I 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 10009'MD/9205'TVD 9965'MD/9165'TVD YES ~ NO []I 2023' feet MD . . 1900'(approx) 22. Type Electric or Other Logs Run D IL/BHCS/GR/SP~ Z-Den/Cal/GR, CET/CBT/GR/CCL,GCT 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 11 O' 13-3/8" 72.0# L-80 Surf 3478' 17-1/2" 9-5/8" 47.0# L-80 Surf 9~,26' 12-1/4" ~f~ ~ CI~_~_~ G 7" 29,0# L-80 J 9341 ' ~10009' 8-1/?" ~,nn 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Perforated w/4 spf, 90° Phasing 4-1/2" 9426' 9300' 9540'-9557 ' MD/8776' -8792 'TVD 9596'-9628'MD/8827'-8856'TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9630'-9646'MD/8858'-8873'TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9760 '- 9768' MD/8977 ' -8985 'TVD N/A 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESlZE IGAS-OILRATIO I TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED=1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None * NOTE: Drilled RR 10/3/88. Perforated well 12/18/88. ~:~. :,. Tubing run 12/20/88. Form 10-407 WC 6/0 42 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Top Sadlerochit HOT OWC 9595' 9836' 9899' 8826' 9047' 9104' N/A 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~'~~. ~ Title Regional Dr ill i ng EngrDate 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 10407 ARCC AI_ASKA, INC F', O, BOX i ANC:HOF,:AGE, Ai_A~I< A 995 i 0 DATE' 2-t 5-89 I::.EFERENCE · ARCO PRESSURE DATA 2-2 t - t t -89 2-i S t "~-i~ 8-88 4-. t 8 i ~-"" t ¢-':;-.88..., 4-24 i2-2i-88 7-.50 i,...'-'..-. 1 7-.88 9-t i t-24-88 9-i t-i5-89 ~-4 i '~-5¢.-88 9.-4 i - i.,.=~-8c~, 9--Si i 2-S0-88 9-.52 i i-24-88 I t -i "'-., 'i -i -89 t2-9 i -7-89 t '"-t: i i ":'- i~ 7-88 t.5-5 2-i-89 i 4-S'7 i-Si -89 i4-S8 i-Si -89 i 4-40 i -;25-89 i 8-i S i 2-S-88 i 8-i 5 i 2-i -88 PWDW°--i: i-i~'-89, PI_EASE SIGN BHF'--F'LOW I NG GRADIENT BHF'--FI_OW ING GRADIENT BHP--STATIC GRADIENT BHF'--STATIC GRADIENT BHP--FLOWING GRADIENT BHP--FLOWING GRAD I EN'i- BHF'--S'f'AT IC GRRDIENT BHF'--FLOWING GRADIENT BHP--STATIC GRADIFNI' BHP--F'LOW INK- GRADIENT BHF'--STATIC GRADIEN'f' BHP--;i.']'ATZC GRADZEN 'F BHF'--FLOWING GRADIENT BHP--FI_OW I NG L, kRD l EN'i' BHF'--STAT lC GRADIENT BHF'--$1'ATIC GRAD IEN"F BHP--STATIC GRADIENT BHP--STATIC GRADIENT BHF'--STATIC GRADIENT BHF'--SI'AT lC GRADIENT BHF'--STAI'IC GRADIENT AND RETURN THE A'FTACHED COPY AS RECEIPT CAMCO CAMCO 0 T I S O'l'I $ CAMCO CAMCO CAMCO [; A M C'. 0 OTIS C '.':~ M C 0 CAt'CO CAMCO CAMCO CAMCO OTIS OTI£' OT I ~ OTI~ CAMCO CAMCO CAMCO OF DATA. RECEIVED BY HAVE A NICE DAY! SALLY HOFFECKER AT0-t529 TRANS ~8907~ APPROVED __~_,, ~ .... ~ · .. FEB 1 6 i583 Atasl.;a 0ii & 6is Cons. Commission Anchorage · . I~TR I BUT Z ON CENTRAL F CHEVRON-?- ' D & M EXTENSION EXPLORATION EXXON MARATHON MOBIL F'HILLIF'S PB WELL FILES R & D SAF'C STATE OF ALASKA TEXACO ., 9-.9 ..-t * THE CORRFCTED AF:'!~ FOR THIS BHP REF'ORT IS :'-0-¢'~ -'~ :~' '" ARCO ALASKA, INC. P.O. BOX ANCHORAGE, ALASKA DATE' 1-i9-89 REFERENCE' ARCO DIRECTIONAL DATA i2-3(9 i2-;~i-88 MWD DIRECTIONAL ~'URVEY JOB¢6'?'4 t4-J'7 9-25-88 MWD DIRECTIONAL $'URVEY JOB~6'54 4-38 i~-2i-88 MWD DIREC'rlONAL SURVEY JOB~659 4-S9 i 2-8-88 MWD DIRECTIONAL SURVEY JOB~669 i4-40 ti-2t-88 MWD DIRECTIONAL 3"URVEY JOB~664 PLEASE SIGN AND RETURN THE ATTACHED COPY A,~' ;:ECEIPT OF DA'FA, ~¢¢~m~ -JA 2 6 1 RECEIVED BY___ HAVE A NICE DAY! SALLY HOFFECKER AT0-i529 -' Naslm Oil & Gas Con=. Commbston Anchorage TRAMS $89, AF'F'ROVED ..... D I ~:l'R I BUI' I ON TELECO TELECO TELECO TELECO TELECO CENTRAL FILES CHEVRON D & M EXTENSION EXF'L. OF;,'ATI ON EXXON MARATHON MOBIL F'H II_L I F'.9 '"' PB WELL F'I[.E$ ( ''~ · ,:. COF'I E:~' ) R & D ~ SAPC · ~ STATE OF ALA&*KA TEXACO STATE OF ALASKA ~'~'- AL~_.,A el L AND GAS CONSERVATION COM MIS,..,) N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate__ Plugging __ Perforate ~ Pull tubing ~ Alter casing ~ Repair well ~ Pull tubing __ Other Complete 2. Name of Operator AR60 Alaska~ Inc, 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2363' FNL, 1636' FEL, Sec. 9, TION, R14E, UM At top of productive interval 2167' FNL, 844' FWL, Sec. 9, TION, R14E, UM At effective depth 2159' FNL, 829' FWL, Sec. 9~ TION, R14E, UM At total depth 2087' FNL, 698' FWL, Sec. 9, TION, R14E, UM 5. Type of Well: Development "" Exploratory m Stratigraphic m Service __ 6. Datum elevation (DF or KB) RKB 77 ' 7. Unit or Property name Prudhoe Bay Unit 8. Well number 14-37 9. Permit number/approval number 88-49/8-850 10. APl number 50-- 029-21810 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length measured 10009 ' MD 9205 'TVD 9638'MD 8866'TVD feet Plugs (measured) None feet feet Junk (measured) feet None Size Cemented Measured depth True vertical depth 80' 3443' 9594' 668' 20" 2150# Pol eset 110 'MD 110 'TVD 13-3/8" 2000 sx C$ I I I & 3478 'MD 3478'TVD 600 sx Class G - Top Job w/200 sx CS II 9-5/8" 880 sx Class G 9626'MD 8855'TVD 7" 300 sx Class G 9341'-10009'MD 8596 '-9205 'TVD Squeezed Liner Lap w/150 sx Class G 9540 ' -9557 'MD, 9596 ' -9628 'MD, 9630 ' -9646 'MD, 9760 '-9768 'MD true vertical 8776'-8792'TVD, 8827 '-8856'TVD, 8858'-8873'TVD, 8977 '-8985 'TVD Tubing (size, grade, and measured depth) 4-1/2" L-80, tbg w/tail @ 9426' Packers and SSSV (type and measured depth) AVA 'SC-SSV' SSSV (~ 2023' & Baker 'DB' pkr ¢ 9300' 13. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure RECEIVED JAN 1 7 ]9gO 0il & Gas Cons. C0 lssl0n chorage 14. N/A Prior to well operation Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Subsequent to operation 15. Attachments Copies of Logs and Surveys run '/' Gyro Daily Report of Well Operations ~ 16. status of well classification as: Oil ~ Gas~ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /. ~'~ Title RegionalDrilling Engineer Form lO-404 Rev 06/15/88 ~/' * Completion Well History (Dani) SW04/002 Date SUBMIT IN DUPLICATE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~ GAS J SUSPENDED ~ ABANDONED ~ SERVICE [] 2. Name of Operator 7. Permit Number ARCO A1 asea. Inc 88-49 3. Address 4. Location of well at surface 8. APl Number 50- 029-21810 2363' FNL, 1636' FEL, Sec. 9, TION, R14E, UM At Top Producing Interval 2167' FNL, 844' FWL, Sec. 9, TION, R14E, UM At Total Depth 2087' FNL, 698' FWL, Sec. 9, TION, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. RKB 77' J ADL 28312 12. Date Spudded 113. Date T.D. Reached 14. Date Comp~,~. or Aband. ! I J 09/11/88 I 09/28/88 (/' 12/20/88..*_- ....... ' 17. Total Depth (MD+TVD) 118. Plug Back Depth(MD+TVD) 19. Direction~l-SWC~rvey J I 20. Depth where SSSV set 10009 'MD/9205 'TVDI' 9638 'MD/8866 'TVD YES [] NO [] I 2023 ' feet MD 9. Unit or Lease Name Prudhoe Bay Unit, 10. Well Number 14-37 11. Field and Pool Prudhoe Bay Fi eld Prudhoe Bay 0il Pool 15. Water Depth, if offshore 116' No. of Completions N/A feet MSLI 1 I 21. Thickness of Permafrost 1900 ' (approx) 22. Type Electric or Other Logs Run D I L/BHCS/GR/SP, Z-Den/Cai/GR, CET/CBT/GR/CCL,GCT 23. CASING, LINER AND CEMENTING RECORD CASING SIZE WT. PER FT. GRADE HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 1 _~-_~/8" 91.5# 72 H-40 -80 9-5/8" 47.0# ! 7" 29.0# L-80 24. Perforations open to Production (MD+TVD of Top and Bottom and SETTING DEPTH MD TOP ! BOTTOM &Hrf I 110' &.~rf 1 9-~41 ' F10009 ' 30" 1.7-1../2" I 9-1/4" a-~/2" 25. 2!50# Po~. eset 2000 s× CS !!! z_ 600 sx r_ 880 sx Class G I interval, size and number) Perforated w/4 spf, 90° Phasing 9540'-9557'MD/8776'-8792'TVD 9596'-9628'MD/8827'-8856'TVD 9630'-9646'MD/8858'-8873'TVD 9760'-9768'MD/8977'-8985'TVD SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" 9426 ' 9300 ' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production Date of Test Hours Tested iMethod of Operation (Flowing, gas lift, etc,) OIL-BBL TEST PERIOD I~ I CALCULATED 24-HOUR RATE GAS-MCF WATER-BBL Flow Tubing Casing Pressure OIL-BBL GAS-MCF WATER-BBL Press. :28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. CHOKE SIZE ]GAS-OILRATIO OIL GRAVITY-APl (corr) None * NOTE: Drilled RR 10/3/88. Tubing run 12/20/88. Perforated well 12/18/88. REEEIVED .lAN 1 7 t§g.q Nasl~ Oil & Gas Cons. Commission ,, ~chorage Form 10-407 Rev. 7-1-80 WC5/073 CONTINUED ON REVERSE SIDE Submit in duplicate 29° ~, 30. GEOLOGIC MARKERS FORMATION TESTS , : ; NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadl erochi t 9595 ' 8826 ' N/A HOT 9836 ' 9047 ' 0WC 9899 ' 9104 ' 31. LIST OF ATTACHMENTS Addendum (dated 11/17/88) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~. ~JJ Title"egi°nal Drilling Engi~)~er '/~/~ 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 10-407WC5/073 hrE L L : ~o/~/~ /-4-37 ~n c~,/ce~,/¢R/cc OR/CCL £/9n~^, t f/9950' ' ~u-3400'. R~-9320' ~/1000 Psi & GCT f/9900' to surf~ Psi. RECEIVED JAN I 7 i5~ N~k~ [~il & Gas Cons. Commi~$10n ~'~'~ ~chomge ADDENDUM WELL: 10/31/88 12/18/88 14-37 Rn CET/CBT/GR/CCL f/9950'-9320' w/1000 psi & 9 psi. Rn GR/CCL f/9950'-3400'. Rn GCT f/9900' to surf. RU DA. Perf well f/9760'-9768' w/32 holes; 9630'-9646' w/64 holes; 9596'-9628' w/128 holes; and 9540'-9557' w/68 holes. Rn CCL to 9000'. RD DA. Drilling Supervi~/ ~ ARCO Oil and Gas Company ~, Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. ICounty. pa~R~Ho~,Opg Lease or I~IDL.' 28312 Title COMPLETE IState ~ DS 14-37 Well no, API: 50-029-21064 ARC& Operator Spudded or W.~.~'1' IDate 12/18/88 Date and depth Complete reco¥~---4~f~y~ as ot 8:00 a.m. 12/19/88 (4) TD: 10009 PB: 9965 SUPV: TJ/GG 12/20/88 ( 2 TD .' 10009 PB: 9965 SUPV: TJ/GG The above is corli~Ct / Signature /,~_ / /., / Drilling, Pages 86 and 87, AR3B-459-1-D I ARCO2~I; 0000 IHour 0'700 HRS [Prior status if a w.o. ~KiOK TO RIG WORK - THE WELL WAS PERF'D BY WL F/9760'-9768', 9630' -9646', 9596' -9628', 9540' -9557' W/4 SPF. RIH W/ PKR ON E-LINE 7"~10009' MW: 9.1 NaCl ACCEPTED RIG ~ 0700 HRS, 12/18/88. MONITOR WELL AND LOAD CASING WITH 33 BBLS OF 8.5 PPG SEAWATER. ND TREE AND NU BOP'S, TEST BOP'S. NO PERF FLANGE AND RU WESTERN ATLAS WIRELINE. RIH W/ 8.5" OD GR/JB TO 500', POH (ICE iN JB). RIH W/ 8.5" OD GR/JB TO 9330', POH. MU TAIL ASSY AND PKR AND RIH TO 9280', SETTING TOOL WOULD NOT FIRE - POH. MU NEW CCL AND FIRING HEAD AND RIH WITH PKR AND TAIL ASSY. DAILY:S149,462 CUM:$1,996,420 ETD:S1,996,420 EFC:$2,548,000 FREEZE PROTECTING 7"@10009' MW: 8.5 FSW RIH W/ PKR AND TAIL PIPE ASSY ON E-LINE. SET BAKER DB PERMANENT PACKER AT 9280' (WLM). RD DRESSER ATLAS E-LINE. MU AND RIH W/ 4-1/2# COMPLETION EQUIPMENT. STABBED INTO PACKER, SPACED OUT TUBING, PU AND DISPLACED WELL TO INHIBITED SEAWATER. STABBED BACK INTO PACKER AND LANDED TUBING. TESTED TUBING TO 3000 PSI, SSSV TO 2500 PSI AND PACKER TO 3000 PSI. PRESSURED TUBING TO 3200 PSI AND SHEARED THE SHEAR-OUT-SUB. ND BOP'S, NU TREE AND TESTED TO 5000 PSI. FREEZE PROTECTED WITH 180 BBLS OF INHIBITED DIESEL DOWN THE ANNULUS AND UP THE TUBING VIA ORIFICE/CHECK AT 3177'. (AVA 'SC-SSV' SSSV ~ 2023', BAKER 'DB' PKR ~ 9300', & TT ~ 9426. ) DAILY:S267,552 CUM:$2,263,972 ETD:S2,263,972 EFC:$2,548,000 INumber all daily well history forms consecutively ss they are prepared for each well. Page no, ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned. or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. ~,CO ALASKA INC. District NORTH SLOPE County or Parish ~DL: 28312 ILease or Unit COMPLETE ~Title API: 50-029-21064 iAccou~g cost center code State S 14-37 Field PRUDHOE BAY AS2165 IWell no. Auth. or W.O. no. .zLRCO Operator ACCEPT Spudded or W.O. begun 21.0000 Date and as of 8:00 a.m~/Z£/UU( mn'!OOO9 PB: 9965 SUPV:TJ/GG A.R.Co. W.I. ,Total number of wells (active or inactive) on this, 12/18/88 Jcost cer~ef'~o~iorut~,plugging and I aba n d o rllY~ Fo frf~i~ well ~Date IHour Prior status if a W.O. ! Complete record for each day reported .;6) RIG RELEASED 7"@10009' MW: 8.5 FSW UINI~;: DiSFLACiNG W/ UZ":3~;h, SET BPV, RELEASE RIG @ 0700 12/20/88. DAILY:S13,545 CUM:$2,277,517 ETD:S2,277,517 EFC:$2,548,000 Old TD New TD PB Depth Released rig Date Kind of r g Classifications (oil, gas, etc.) I Type completion (single, dual. etc.) Producing method 1 Official reservoir name(s) I Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pu'mp size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above islo .... t / / Signat u ~/~-~. /. sFe°; fp°;o~ e~rue, Peas r aMt ia°nnu ~ln, % ed ic~: r~ n~U~ i0°, n ' Drilling, Pages 86 and 87. AR3B-459-3-C INumber all daily well history forms consecutively I Page no. as they are prepared for each well. Dlvlllon of AtlsntlcRIchflaldCompany SUB. SURFACE DIRECTIONAL $URVEY I~i UIDANCE I'~'i ONTINUOUS I~OOL Company ARCO ALASKA, INC. II Well Name D_.S. 14-37(2363' FNL~1636' FEL,SEC 9,TION,R14E~UM) . Field/Location PRUDHOE, BAY) NORTH SLOPE, ALASK,A Jol~ Reference No. 73076 REYNOLDS Date 31-0CT-88 Computed SINES SCHLUMBERGER GCT OIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA INC. OS 14 - 37 PRUDHDE BAY NORTH SLOPE~ ALASKA SURVEY DATE: 31-0CT-88 ENGINEER: REYNOLDS METHODS OF COMPUTATION TOOL LOCATION: TANGENTI&L- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 86 DEG 38 MIN WEST COMPUTATION DATE: 27-DEC-88 PAGE ARCO ALASKA INC. DS 14 - 37 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: 31-0CT-88 KELLY BUSHING ELEVA'TION: 77.00 FT ENGINEER: REYNOLDS INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH OEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. ~ZIMUTH FEET PEG/lO0 FEET FEET FEET PEG MIN 0.00 0.00 -77.00 0 0 N 0 O E 100.00 100.05 23.05 0 12 S 74 20 E 200.00 200.05 123.05 0 4 N 41 47 E 300.00 300.05 223.05 0 4 S 73 22 E 400.00 400.05 323.05 0 19 S 19 35 E 500.00 500.05 423.05 0 31 S 4 19 W 600.00 600.04 523.04 0 17 S 17 Z W 700.00 700.04 623.04 0 10 S 61 47 W 800.00 800.04 723.04 0 Z N 45 35 W 900.00 900.04 923.04 0 3 N 86 34 E O.O0 O.O0 O.OO N 0.00 -0.23 0.17 0.07 S 0.23 -0.38 0.11 0.04 S 0.38 -0.47 0.21 0.03 S 0.47 -0.68 0.40 0.30 S 0.66 -0.78 0.16 1.00 S 0.72 -0.72 0.30 1.80 S 0.61 -0.51 0.09 2.10 S 0.39 -0.36 0.13 2.18 S 0.23 -0.39 0.09 2.15 S 0.26 0.00 N 0 0 E 0.24 S 71 46 E 0.38 S 84 31 E 0.47 S 86 58 E 0.73 S 65 49 E 1.24 S 35 52 E 1.90 S 18 52 E 2.14 S 10 27 E 2.20 S 6 1 E 2.17 S 6 59 E 1000.00 1000.04 923.04 1100.00 1100.04 1023.04 1200.00 1200.04 1123.04 1300.00 1300.04 1223.04 1400.00 1400.04 1323.04 1500.00 1500.03 1423.03 1600.00 1600.03 1523.03 1700.00 1TO0.OZ 1623.02 1800.00 1800.02 1723.02 1900.00 1900.01 1823.01 0 9 S 66 27 E 0 12 $ 45 55 E 018 S 31 10 E 0 21 S 21 35 E 0 24, S 14 24 E 0 33 S 25 26 E 0 37 S 39 4Fi E 0 35 S 50 54 E 0 30 S 62 46 E 0 23 N ~32 44 E -0.59 0.11 2.22 S 0.46 -0.87 0.11 2.39 S 0.73 -1.16 0.07 2.75 S 1.00 -1.45 0.14 3.26 S 1.26 -1.66 0.21 3.89 S 1.43 -1.97 0.21 4.67 S 1.69 -2.58 0.12 5.54 S 2.26 -3.39 0.18 6.30 S 3.03 -4.23 0.15 6.86 S 3.83 -4.96 0.13 7.02 S 4.56 2.27 S 11 48 E 2.50 S 16 53 E 2.93 S 20 1 E 3.50 S 21 8 E 4.14 S 20 13 E 4.97 S 19 56 E 5.99 S 22 12 E 6.99 S 25 39 E 7.86 S 29 11 E 8.37 S 32 58 E 2000.00 2000o01 1923.01 2100.00 2100.01 2023.01 ZZO0.O0 Z200.01 2123.01 2300.00 2300.00 2223.00 2400.00 2400.00 2323.00 2500.00 2500.00 2423.00 Z600.OO Z600.00 2523.00 2700.00 2699.99 2622.99 2800.00 2799.99 2722.99 Z900.O0 2899.99 282Z.99 0 20 N 72 2 E 0 24 N 64 42 E 0 27 S 78 26 E 0 26 S 38 7 E 0 22 S 19 50 E 0 24 S 26 54 E 0 29 S 28 41 E 0 24 S 26 43 E 0 12 S 7 49 W 0 8 S 84 54 E -5.59 0.22 6.86 S 5.20 E -6.13 0.10 6.56 S 5.76 E -6.81 0.47 6.43 S 6.45 E -7.48 0.15 6.84 S 7.09 E -7.85 0.12 7.48 S 7.43 E -8.15 0.07 8.09 S 7.69 E -8.49 0.10 8.78 S 7.99 E -8.92 0.51 9.57 S 8.38 E -9.13 0.28 10.01 S 8.56 E -9.25 0.15 10.07 S 8.67 E 8.61 S 37 8 E 8.73 S 41 16 E 9.10 S 45 4 E 9.85 S 46 0 E 10.54 S 44 ~+8 E 11.16 S 43 33 E 11.87 $ 42 17 E 12.71 S 41 12 E 13.17 S 40 30 E 13.29 $ 40 43 E 3000.00 2999.99 2322.99 3100.00 3099.99 3022.99 3200.00 3199.99 3122.99 3300.00 3299.99 3222.99 3400.00 3399.99 3322.99 3500.00 3499.99 3422.99 3600.00 3599.99 3522.99 3700.00 3699.87 3622.87 3800.00 3799.18 3722.18 010 S 42 5 E 0 7 S 52 25 W 0 4 N Zl 45 E 0 12 S 19 23 W 0 2 N $6 7 W 0 16 S 52 27 W 0 22 S 68 59 W 5 13 N 85 41W 8 2 N 79 41 W N ~1 20 W 3900.00 3897.83 3820.83 10 15 -9.50 0.10 10.20 S 8.92 E -9.54 0.61 10.44 S 8.95 E -9.46 0.11 10.35 S 8.87 E -9.53 0.42 10.51 S 8.93 E -9.37 0.19 10.59 S 8.76 E -9.29 0.28 10.80 S 8.68 E -8.90 0.53 10.98 S 8.27 E -4.97 4.92 11.06 S 4.33 E 6.62 3.38 9.03 S 7.16 W 22.87 1.16 6.43 S 23.29 W 13.55 S 41 10 E 13.75 S 40 36 E 13.63 S 40 35 E 13079 S 40 ZO E 13.74 S 39 36 E 13.86 S 3~ 45 E 13.74 S 35 59 E 11.87 S 21 24 E 11.52 S 38 24 W 24.16 S 74 33 W COMPUTATION DATE: 2T-DEC-88 PAGE Z ARCO ALASKA INC. DS 14 - 37 PRUDHDE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: 31-0CT-88 KELLY BUSHING ELEVATION: 77.00 FT ENGINEER: REYNOLDS INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH OEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HDRIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4000.00 3995.86 3918.86 12 52 4100.00 4092.63 4015.63 16 ZO 4200.00 4187.57 4110.57 19 57 4300.00 4281.15 4204.15 20 59 4400.00 4373.87 4296.87 23 10 4500.00 4465.29 4388.29 24 25 4600.00 4555.92 4478.92 25 57 4700.00 4645.19 4568.19 27 11 4800.00 4733.86 4656.86 27 58 4900.00 4821.81 4744.81 28 54 N 89 8 W 42.53 3.48 S 85 47 W 67.53 4.04 S 85 43 W 98.57 2.35 S 85 55 W 133.52 0.88 S 85 8 W 170.61 2.02 S 84 25 W 210.66 0.87 S 83 41 W 252.38 2.63 S 82 52 W 296.71 0.67 S 82 51 W 342.17 0.78 S 83 6 W 388.98 1.02 4.82 S 42.89 W 43.16 S 83 35 W 5.88 S 67.9'9 W 68.25 S 85 3 W 8.31 S 99.23 W 99.57 S 85 12 W 10.89 S 134.39 W 134.83 S 85 21 W 13.73 S 171.71 W 172.26 S 85 25 W 17.47 S 212.05 W 212.77 S 85 17 W 21.76 S 254.10 W 255.03 S 85 6 W 27.14 S 298.82 W 300.05 S 84 48 W 32.93 S 344.70 W 346.26 S 84 32 W 38.75 S 391.92 W 393.84 S 84 Z1 W 5000.00 4908.86 4831.86 30 6 5100.00 4994.87 4917.87 30 55 5200.00 5080.60 5003.60 31 6 5300.00 5166.14 5089.14 31 32 5400.00 5251.11 5174.11 31 58 5500.00 5335.89 5258.89 32 2 5600.00 5420.60 5343.60 32 12 5700.00 5505.37 5428.37 31 53 5800.00 5590.33 5513.33 31 45 5900.00 5675.49 5598.49 31 20 S 83 56 W 437.46 1.48 S 84 18 W 487.80 0.36 S 85 2¢ W 538.71 1.23 S 87 3 W 590.12 0.87 S 88 16 W 642.58 0.64 S 89 15 W 695.44 0.42 N 89 37 W 748.48 O.B1 N 88 53 W 801.48 0.31 N 88 23 W 854.19 0.34 N 98 0 W 906.58 0.73 44.33 S 460.82 W 443.04 S 84 15 W 49.58 S 491.55 W 494.05 S 84 14 W 54.29 S 562.82 W 545.53 S 84 17 W 57.56 S 594.52 W 597.30 S 84 28 W 59.72 S 647.20 W 649.94 S 84 43 W 60.81 S 700.21 W 702.84 S 85 2 W 61.05 S 753.35 W 755.82 $ 85 22 W 60.25 S 806.40 W 808.65 S 85 43 W 58.99 S 859.13 W 861.15 S 86 4 W 57.31 S 911.51 W 913.31 S 86 24 W 6000.00 5761.10 568~.10 30 44 6100.00 5847.36 5770.36 30 10 6200.00 5933.97 5856.97 29 47 6300.00 60Z0.53 5943.53 30 22 6400.00 6106.73 6029.73 30 47 6500.00 619Z.18 6115.18 31 39 6600.00 6276.94 6199.94 32 21 6700.00 6361.37 6284.37 32 13 6800.00 6446.28 6369.28 31 37 6900.00 6531.66 6454.66 31 10 N 98 Z W 958.25 N 87 45 W 1008.83 N 87 59 W 1058.81 N 88 ZO W 1108.86 N 87 52 W 1159.53 N 88 2 W 1211.45 N 87 49 W 1264.50 N ~6 57 W 1318.09 N 94 54 W 1370.90 N 82 25 W 1422.89 I .07 0.40 0.68 0.15 I .36 0.93 0.57 I .05 1.40 I .26 55.53 S 963.16 W 964.76 S 85 42 W 53.70 S :1013.72 W 1015.14 S 86 58 W 51.73 S 1063.67 W 1064.93 S 87 12 W 50.23 S 1113.72 W 1114.85 S 87 25 W 48.58 S 1164.38 W 1165.39 S 87 36 W 46.74 S 1216.28 W 1217.18 S 87 47 W } 44.87 S 1269.31 W 1270.11 S 87 58 W 42.52 S 1322.85 W 1323.54 S 83 9 W 38.87 S 1375.54 W 1376.09 S 88 22 W 33.16 S 1427.29 W 1427.67 S 83 40 W 7000.00 6617.39 6540.39 30 43 7100.00 6703.30 6626.30 31 9 7200.00 6788.53 6711.53 31 55 7300.00 6872.98 6795.98 32 46 7400.00 6956.77 6879.77 33 31 7500.00 7039.67 6962.67 34 29 7600.00 7121.69 7044.69 35 21 7700.00 7202.77 7125.77 36 7800.00 7283.46 7206.46 36 3 7900.00 7364.24 7287.24 35 47 N 90 14 W 1474.14 N 79 43 W 1524.95 N 79 47 W 1576.86 N 81 51 W 1630.13 N 82 13 W 1684.56 N 83 27 W 1740.34 N 84 0 W 1797.48 N 93 55 W 1355.94 N 85 17 W 1914.96 N 86 19 W 1973.91 1.19 0 .BI 1.18 0.81 0.94 1.32 1.00 0.93 0.92 1 25.36 S 1478.17 W 1478.38 S 89 1 W 16.26 S 1528.53 W 1528.62 S 89 23 W 6.87 S 1579.98 W 1590.00 S 8l 45 W 1.64 N 1632.84 W 1632.85 N 89 56 W 9.10 N 1686.93 W 1686.95 N 89 41 W 16.25 N 1742.38 W 1742.45 N 89 27 W 22.31 N 1799.27 W 1799.41 N 89 17 W 28.50 N 1857.46 W 1857.68 N 89 7 W 34.17 N 1916.25 W 1916.5~ N 88 58 W 38.51 N 1975.05 W 1975.43 N 8~ 52 W ARCO ALASKA INC. DS 14 - 37 PRUOHOE BAY NORTH SLOPEs ALASKA COMPUTATION DATE: 2'7-0EC-88 DATE OF SURVEY: 31-0CT-88 KELLY BUSHING ELEVATION: 77.00 F~ ENGINEER: REYNOLDS INTERPOLATEO VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR C30RDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET mEET OEG MIN 8000.00 7445.68 7368.68 35 29 8100.00 7526.89 7449.89 35 53 8200.00 7607.95 7530.95 35 39 8300.00 7689.46 7612.~6 34 59 8400.00 7771.76 7694.76 34 10 8500.00 7855.04 7778.04 32 57 8600.00 7939.52 7~62.52 31 48 8700.00 8025.14 7948.14 30 17 8800.00 811Z.11 8035.11 29 0 8900.00 8199.95 812Z.95 28 3 9000.00 8288.61 8211.61 27 6 9100.00 8377.99 8300.99 26 10 9200.00 8468.01 8391.01 25 25 9300.00 8558.50 8481.50 24 59 9400.00 8649.23 8572.Z3 24 48 9500.00 874.0.10 8663.10 24 46 9600.00 8830.93 8753.93 24 24 9700.00 8922.27 8845.27 23 49 9800.00 9013.71 8936.71 23 51 9900.00 9105.35 9028.35 23 19 10000.00 9197.18 9120.18 23 19 10009.00 9205.44 9128.44 23 19 N 96 35 W 2031.94 N 86 29 W 2090.29 N 86 54 W 2148.84 N $6 30 W 2206.77 N 85 20 W 2263.57 N 84 25 W 2318.89 N 82 46 W 2372.33 N 81 11 W 24,23.82 N 78 37 W 2472.82 N 77 28 W 2520.06 N 75 40 W 2565.61 N 73 33 W 2609.4.7 N 71 21 W 2651.69 N 68 43 W 2692.52 N 66 17 W 2732.24 N 63 3 W 2770.89 N 61 51 W 2808.97 N 61 53 W 2845.90 N 61 3 W 2882.56 N 60 36 W 2918.59 N 60 36 W 2954.16 N 60 36 W 2957.36 0.30 0.26 0.55 1.12 I .26 1.56 I .62 Z .13 1.26 1.08 1.08 I .27 1.49 1.50 1.60 1.29 0.91 0.43 0.74 0.00 0.00 0.00 4.1.98 N 2032.97 W 2033.40 N 88 4,9 W 45.5! N 2091.21 W 2091.71 N 88 45 W 4B.96 N 2149.66 W 2150.ZZ N 88 4.1 W 52.08 N 2207.51 W 2208.13 N 88 38 W 56.15 N Z264.17 W 2264.87 N 88 34 W 61.07 N 2319.30 W 2320.11 N 88 29 W 66.92 N 2372.48 W 2373.43 N 88 23 W 74.12 N 2423.64. W 2424.77 N 88 14 W 82.81 N 2472.22 W 2473.61 N 88 4 W 92.79 N 2518.95 W 2520.66 N 8'7 53 W 103.46 N 2563.96 W 2566.0~+ N 8'7 41 W 115.39 N 2607.19 W 2609.74 N 87 27 W 128.4? N 2648.71 W 2651.82 N 87 13 W 142.89 N 2688.77 W 2692.56 N 86 57 W 158.99 N 2727.61 W 2732.24 N 86 39 W 176.93 N 2765.28 W 2770.93 N 86 20 W 196.47 N 2802.27 W 2809.15 N 85 59 W 215.70 N 2838.13 W 2846.32 N 85 39 W 234.99 N 2873.73 W 2883.32 N 85 19 W 254.51 N 2908.67 W 2919.78 N 84 59 W 273.94 N 294.3.17 W 2955.89 N 84 40 W 275.69 N 294.6.27 W 17959.14. N 84 39 W ARCO ALASKA INC. DS 14 - 37 PRUDHOE B~Y NORTH SLOPE~ ALASKA COMPUTATION DATE.' 27-DEC-,38 PAGE DATE OF SURVEY: 31-0CT-88 KELLY BUSHING ELEVATION: 77.00 FT. ENGINEER: REYNOLDS INTERPOLATED VALUES FOR EVEN 1000 FEET DF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0.00 0.00 -77.00 0 0 1000.00 1000.04 923.04 0 9 ZO00.O0 2000.01 1923.01 0 20 3000.00 2999.99 2922.99 0 10 4000.00 3995.86 3918.86 12 52 5000.00 4908.86 4831.86 30 6 6000.00 5761.10 5684.10 30 44 7000.00 6617.39 6540.39 30 43 8000.00 T445.6~ 7368.68 35 29 9000.00 8288.61 8211.61 27 6 VERTICAL DOGLEG RECTANGULAR CDORDIN&TES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET OEG MIN 10000.00 9197.18 9120.18 23 19 10009.00 9205.44 9128.44 23 19 N 0 0 E 0.00 S 66 27 E -0o59 N 72 2 E -5.59 S 42 5 E -9.50 N ~9 8 W 42.53 S 8.3 5:5 W 43?.46 N 88 2 W 958.25 N BO 14 W 1474.14 N 86 35 W 2031.94 N 75 40 W 2565.61 0.00 0.11 0.22 0.10 3.48 I .48 1.07 1.19 0.30 1.08 0.00 N 0.00 E 0.00 N 0 0 E 2.22 S 0.46 E 2.27 S 11 48 E 6.86 S 5.20 E 8.61 S 37 8 E 10.20 S 8.92 E 13.55 S 41 10 F 4.82 S 42.89 W 43.16 S 83 35 W \ 44.33 S 440.82 W 443.04 S 84 15 W 55.53 S 963.16 W 964.76 S 86 42 W 25.36 S 1478.17 W 1478.38 S 89 1 W 41.98 N 2032.97 W 2033.40 N 88 49 W 103.46 N 2563.96 W 2566.04 N 87 41 W N 60 36 W 2954.16 N 60 36 W 2957.'36 0.00 0.00 273.94 N 2943.1'7 W 2955.89 N 84 40 W 275.69 N 2946.27 W 2959.14 N 84 39 W ARCO .ALASKA INC. DS 14 - 37 PRUOHOE BAY NORTH SLOPEr ALASKA COMPUTATION DATE: 27-DEC-88 DATE OF SURVEY: 31-0CT-8B KELLY BUSHING ELEVATION: 77.00 FT ENGINEER: REYNOLOS INTERPOLATED VALUEs FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG HIE DEG MIN 0.00 0.00 -77.00 0 0 N 0 0 m 76.95 77°00 0.00 0 12 S 71 0 ~ 176.95 177.00 100.00 0 4 N 34 43 5 276.95 277.00 200.00 0 3 N 79 40 E 376.95 377.00 300.00 0 15 S 29 4~ E 476.95 477.00 400.00 0 27 S 2 17 W 576.96 577.00 500.00 0 22 S 9 54 W 676.96 677.00 600.00 0 11 S 56 5 W 776.96 777.00 700.00 0 3 N 81 34 W 876.96 877.00 800.00 0 2 N 67 51 E 976.96 977.00 900.00 1076.96 1077.00 lO00.O0 1176.96 1177.00 1100.00 1276.96 1277.00 1200.00 1376.96 1377.00 1300.00 1476.97 1477.00 1400.00 1576.97 1577.00 1500.00 1676.98 1677.00 1600.00 1776.98 1777.00 1700.00 1876.99 1877.00 1800.00 0 9 S 69 24 E 011 S 52 0 17 S 34 50 E 0 21 S 24 18 E 0 22 S 13 45 E 0 30 S 22 12 E 037 S 37 0 37 S 48 2c) E 031 S 58 7 E 0 23 N 37 45 1976.99 1977.00 1900.00 Z076.99 2077.00 2000.00 2176.99 2177.00 2100.00 2277.00 2277.00 2200.00 2377.00 2377.00 2300.00 2477.00 2477.00 2400.00 2577.00 2577.00 2500.00 2677.01 2677.00 2600.00 2777.01 2777.00 2700.00 2877.01 2877.00 2800.00 0 22 N 73 30 E 0 23 N 60 24 E 0 25 N 88 7 E 0 25 S 43 25 E 0 23 S 22 15 E 0 23 S 27 20 E 0 27 S 23 52 E 0 30 S 23 31 E 0 13 S 8 59 E 0 7 N 82 SE 2977.01 Z977.00 2900.00 3077.01 3077.00 3000.00 3177.01 3177.00 3100.00 3277.01 3277.00 3200.00 3377.01 3377.00 3300.00 3477.01 3477.00 3400.00 3577.01 3577.00 3500.00 3677.06 3677.00 3600.00 3777.62 3777.00 3700.00 0 9 S 53 17 E 0 3 S 12 20 W 0 4 N 9 10 E 0 13 S 2 59 E 0 4 N 68 37 W 0 15 S 31 14 W 0 16 S 70 38 W 348 N 89 43 W 724 N 79 OW N 81 ¢ W 3878.84 3877.00 3800.00 10 2 VERTICAL DOGLEG R'ECTANGULAR COORDINATES HORIZ. DE°ARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST OIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET OEG MIN 0.00 0.00 0.00 N 0.00 E -0.14 0.16 0.05 S 0.14 E -0.36 0.03 0.06 S 0.36 E -0.45 0.20 0.02 S 0.45 i -0.63 0.33 0.19 S 0.62 E -0.78 0.37 0.80 S 0.74 E -0.74 0.48 1.6'7 S 0.64 E -0.57 0.44 2.07 S 0.45 E -0.37 0.47 2.19 S 0.24 E -0.37 0.06 2.16 S 0.25 E 0.00 N 0 0 E 0.15 S 71 40 E 0.37 S 80 35 E 0.45 S 86 56 E 0.65 S 72 27 E \ 1.09 S 42 40 E 1.79 S 21 0 E 2.I2 S 12 14 E 2.20 S 6 18 E 2.17 S 6 30 E -0.54 0.05 2.20 S 0.41 E -0.80 0.12 2.34 S 0.67 E -1.09 0.24 2.65 S 0.94 E -1.39 0.10 3.13 S 1.21 E -1.61 0.03 3.7¢ S 1.39 E -1.86 0.33 4.47 S 1.61 E -2.42 0.16 5.35 S 2.11 E -3.19 0.17 6.15 S 2.84 E -4.05 0.31 6.76 S 3.66 E -4.81 0.22 7.04 S 4.40 E 2.24 S 10 29 E 2.43 S 15 53 E 2.81 S 19 30 E 3.36 S 21 2 E 3.99 S 20 27 E 4.75 S 19 45 E 5.75 S 21 30 E 6.77 S 24 47 E 7.69 S 28 23 E 8.30 S 32 1 E -5.45 0.09 6.91 S 5.06 E -6.00 0.19 6.64 S 5.62 E -6.64 0.45 6.41 S 6.27 E -7.36 0.25 6.71 S 6.98 E -7.79 0.21 7.34 S 7.37 E -8.07 0.14 7.94 S 7.61 E -8.39 0.33 8.61 S 7.90 E -8.34 0.39 9.39 S 8.30 E -9.12 0.39 9.93 S 8.56 E -9.20 O.1T 10.08 S 8.62 E 8.56 S 36 12 E 8.69 S 40 14 E 8.97 S 44 21 E 9.68 S 45 6 E 10.40 S 45 8 E 11.00 S 43 47 E 11.69 S 42 32 E 12.54 S 41 27 E 13.10 S 40 45 E 13.25 S 40 32 E -9.45 0.22 10.15 S 8.87 E -9.56 0.17 10.39 S 8.97 E -9.45 0.18 10.38 S 8.86 E -9.53 0.26 10.42 S 8.94 E -9.39 0.30 10.60 S 8.78 E -9.37 0.74 10.73 S 8.75 E -9.01 0.54 10.92 S 8.39 E -6.80 7.31 11.12 S 6.16 E 3.66 2.46 9.53 S 4.23 W 19.15 1.21 7.01 S 19.60 W 13.48 S 41 9 E 13.72 S 40 48 E 13.65 S 40 28 E 13.73 S 40 36 E 13.76 S 39 38 E 13.~5 S 39 12 E 13.77 S 37 31 E 12.71 S 28 59 ~ 10.48 S 23 48 W 20.82 S 70 18 W ARCO ALASKA INC. DS 14 - 37 PRUDHOE BAY NORTH SLOPEr ALASKA COMPUTATION DATE: 27-OEC-B8 PAGE ~ DATE OF SURVEY: 31-0CT-88 KELLY BUSHING ELEVATION: 77.00 FY ENGINEER: REYNOLOS INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA OEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZ!MUTH DEPTH DEPTH DEPTH OEG MIN DEG MIN 3980.68 39'77.00 3900.00 12 16 4083.73 4077.00 4000.00 15 42 4188.78 4177.00 4100.00 19 36 4295.56 4277.00 4200.00 20 57 4403.41 4377.00 4300.00 23 14 4512.87 4477.00 4400.00 24 32 4623.53 4577.00 4500.00 26 24 4735.79 4677.00 4600.00 27 25 4848.94 4777.00 4700.00 28 24 4963.26 4877.00 4800.00 29 37 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET ~EET DEG MIN 5079.16 4977.00 4900.00 30 52 5195.79 5077.00 5000.00 31 6 5312.75 5177.00 5100.00 31 38 5430.53 5277.00 5200.00 31 59 5548.49 5377.00 5300.00 32 5 5666.58 5477.00 5400.00 31 58 5784.33 5577.00 5500.00 31 47 5901.76 5677.00 5600.00 31 20 6018.47 5777.00 5700.00 30 36 6134.28 5877.00 5800.00 30 4 N 87 53 W 38.32 3.40 S 86 9 W 63.06 3.96 S 85 40 W 94.85 2.77 S 85 54 W 131.95 0.82 S 85 6 W 171.95 1.87 S 84 21 W 215.94 0.95 S 83 24 W 262.67 1.90 S 82 47 W 312.85 0.70 S 82 58 W 364.91 0.98 S 83 36 W 419.42 1.39 S ~4 10 W 477.22 S 85 20 W 536.55 S 87 11 W 596.76 S 88 37 W 658.70 S 89 44 W 721.09 N ~9 I W 783.82 N 88 28 W 845.95 N 88 0 W 907.50 N 88 0 W 967.65 6249.60 5977.00 5900.00 30 3 6365.48 6077.00 6000.00 30 29 6482.19 6177.00 6100.00 31 31 6600.07 6277.00 6200.00 32 21 6718.49 6377.00 6300.00 32 6 6836.06 6477.00 6400.00 31 26 6952.94 6577.00 6500.00 30 57 7069.30 6677.00 6300.00 30 53 7186.42 6777.00 6700.00 31 49 N 87 42 W 1026.04 N 88 19 W 1083.46 N 88 3 W 1141.98 N 88 ~Z W 1202.15 N ~37 49 W 1264.54 N 86 40 W -1327.97 N 84 0 W 1389.76 N ~1 14 W 1450.13 N 79 41 W 1509.23 N 79 38 W 1569.74 I 7304.78 6877.00 6800.00 32 47' N 81 54 W 1632.72 4.93 S 38.68 W 38.99 S 82 44 W 5.55 S 63.49 W 63.76 S 85 0 W 8.02 S 95.48 W 95.82 S 85 11 W 10.78 S 1.32.81 W 133.25 S 85 21 W 13.84 S 173.06 W 173.61 S 85 25 W 17.99 S 217.37 W 218.11 S 85 16 W 22.95 S 264.47 W 265.46 S 85 2 W 29.20 S 315.11 W 316.46 S 84 42 W 35.79 S 367.63 W 369.37 S 84 26 W 42.36 S 422.63 W 4~-4.75 S 84 16 W 0.49 1.22 0.63 0.62 0.73 0.36 0.32 0.70 0.8Z 0.51 48.50 S 480.89 W 483.33 S 84 14 W 54.10 S 540.65 W 543.35 S 84 17 W 57.90 S 601.19 W 603.97 S 84 29 W 60.15 S 663.36 W 666.08 S 84 49 W 61.05 S 725.97 W 728.48 S 85 11 W 60.57 S 788.73 W 791.05 $ 85 36 W 59.22 S 850.88 W 852.94 S 86 1 W 57.28 S 912.42 W 914.22 S 86 24 W 55.21 S 972.56 W 974.12 S 86 45 W 53.00 S 1030.92 W 1032.28 S 87 3 W 1.13 0.61 0.63 0.57 1.48 1.53 1.23 0.95 0.96 0.71 50.95 S 1088.31 W 1089.51 S 87 19 W 49.22 S 1146.84 W 1147.90 S 87 32 W 47.06 S 1206.98 W 1207.90 S 87 46 W 44.87 S 1269.35 W 1270.14 S 87 58 W 42.00 S 1332.72 W 1333.38 S 8,8 11 W 37.05 S 1394.33 W 1394.82 S 88 28 W 29.23 S 1454.34 W 1454.6.3 S 8~ 50 W 19.08 S 1512.95 W 1513.07 S 89 16 W 8.17 S 1572.92 W 1572.9% S 89 42 W Z.O1 N 1635.41 W 1635.41 N 89 55 W 7424.29 6977.00 6900.00 33 44 7545.40 7077.00 7000.00 34 51 7668.11 7177.00 7100.00 35 58 7792.01 7277.00 7200.00 36 4 7915.72 7377.00 7300.00 35 37 8038.49 7477.00 7400.00 35 38 8161.88 7577.00 7500.00 35 49 8284.78 7677.00 7600.00 35 7 8406.33 7777.00 7700.00 34 6 8526.12 7877.00 7800.00 32 35 N 82 18 W 1697.95 N 83 55 W 1766.14 N 83 53 W 1837.19 N 85 9 W 1910.27 N 86 27 W 1983.09 N 86 31 W 2054.31 N 86 40 W 2126.58 N 86 41 W 2198.04 N 85 16 W 2267.12 N 94 7 W 2333.03 1.02 0.89 0.65 I .10 I .24 0.56 0.60 1.15 1.22 I .39 10.93 N 1700.24 W 1700.27 N 89 37 W 19.04 N 1768.06 W 1768.17 N 89 22 W 26.48 N 1838.79 W 1838.99 N 89 10 W 33.77 N 1911.58 W 1911.88 N 88 59 W 39.09 N 1984.21 W 1984.59 N 88 52 W 43.32 N 2055.30 W 2055.75 N 88 47 W 47.71 N 2127.44 W 2127.98 N 88 42 W 51.55 N 2198.80 W 2199.40 N 88 39 W 56.45 N 2267.71 W 2268.41 N 88 34 W 62.47 N 2333.38 W 2334.22 N 88 27 W ARCO ALASKA INC. DS 14 - 37 PRUDHOE BAY NORTH SLOPE, ALASKA COMPUTATION DATE: 27-DEC-,B8 PAGE DATE OF SURVEY: 31-0CT-88 KELLY BUSHING ELEVATION: 77.00 FT ENGINEER: REYNOLDS INTERPOLATED VALUES FOR EVEN 100 FEET OW SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH OEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 8643.96 7977.00 7900.00 31 12 8759.78 8077.00 8000.00 29 25 8873.95 8177.00 8100.00 28 18 8986.95 8277.00 8200.00 27 12 9098.90 8377.00 8300.00 26 11 9209.94 8477.00 8400.00 25 24 9320.41 8577.00 8500.00 24 56 9430.57 8677.00 8600.00 24 40 9540.66 8777.00 8700.00 24 49 9650.5! 8877.00 8800.00 23 57 9759.84 8977.00 8900.00 23 53 9869.12 9077.00 9000.00 23 27 10009.00 9205.44 9128.44 23 19 N 82 2 W 2395.24 N 79 32 W 2453.37 N 77 41 W 2507.89 N 75 55 W 2559.75 N 73 34 W 2608.99 N 71 B W 2655.78 N 68 14 W 2700.T0 N 65 15 W 2744.15 N 62 9 W 2786.49 N 61 42 W 2827.76 N 61 27 W 2867.86 N 60 43 W 2907.59 N 60 36 W 2957.36 I .67 1.81 I .02 I .21 1.27 I .25 0.80 2.32 1.01 0.90 0.53 1.04 0.00 70.00 N 2395.26 W 2396.28 N 88 19 W 79.08 N 2452.95 W 2454.23 N 88 9 W 90.15 N 2506.91 W 2508.53 N 87 56 W 102.02 N 2558.17 W 2560.20 N 87 42 W 115.26 N 2606.72 W 2609.27 N 87 28 W 129.85 N 2652.73 W 2655.90 N 87 146.05 N 2696.77 W 2700.72 N 86 54 W 164.26 N 2739.23 W 2744.15 N 86 34 W 184.81 N 2780.43 W 2786.57 N 86 11 W 206.25 N 2820.53 W 2828.06 N 85 49 W 227.15 N 2859.46 W 2868.47 N 85 27 W 248.50 N 2838.01 W 2908.64 N 85 5 W 275.69 N 2946.27 W 2959.14 N 84 39 W ARCO ALASKA DS 14 - 37 PRUDHOE BAY NORTH SLOPE, INC. ALASKA MARKER SAG SHUBLIK ZONE 4, TOP SADLEROCHIT PBTD HOT ZONE 3 LAST READING GET OWC ZONE Z TD COMPUTATION DATE: 27-DEC-88 INTERPOLATEO VALUES FOR CHOSEN SURFACE LOCATION = MEASURED OEPTH TVD BELOW KB FROM KB 9535.00 8771.87 9558.00 8792.74 9595.00 8826.38 9595.00 8826.38 9638.00 8865.58 9836.00 9046.65 9846.00 9055.81 9894.75 9100.53 9899.00 9104.43 9922.00 9'125.55 10009.00 9205.44 DATE OF SURVEY: KELLY BUSHING ELEVATION: ENGINEER: HORIZONS PAGE 31-0CT-88 77.00 Fi REYNOLDS RECTANGULAR COORDINATES SUB-SEA NORTH/SOUTH EAST/WEST 8694.87 183.70 N 2778.32 W 8715.74 188.22 N 2786.86 W 8749.38 195.50 N 2800.¢5 W 8749.38 195.50 N 2800.45 W 8788.58 203.84 N 2816.03 W 8969.65 242.04 N 2886.43 W 8978.81 243.99 N 2889.94 W 9023.53 253.49 N 2906.86 W 9027.43 254.31 N 2908.33 W 9048.55 258.78 N 2915.26 W 9128.44 275.69 N 2946.27 W 2363' FNL & 1636' FEL, SEC9, TIO , R14 ARCO ALASKA DS 14 - 37 PRUDHOE BAY NORTH SLOPE, INC. ALASKA MARKER SAG SHUBLIK ZONE 4 TOP SADLEROCHIT PBTD HOT ZONE 3 LAST READING GCT OWC ZONE Z TD COMPUTATION DATE: 2T-DEC-88 ~*~*~*~~ STRATIGRAPHIC SUMMARY SURFACE LOCATION = MEASURED DEPTH 'TVD BELOW KB FROM KB 9535.00 877.1.~? 9558.00 8792.74 9595.00 8826.38 9595.00 8826.38 9638.00 8865.58 9836.00 9046.65 9846.00 9055.81 9894.75 9100.53 9899.00 9104.43 9922.00 9125.55 10009.00 9205.44 KELLY 2363' FNL SUB-SEA 8694.87 8715.74 8749.38 8749.38 8788.58 8969.65 8978.81 9023.53 9027.43 9048.55 9128.44 DATE OF SURVEY: ~USHING ELEVATION: ENGINEER: PAGE ~ 31-0CT-88 77.00 Fff REYNOLDS 1636' FEL, SEC9, TIO , R14 RECTANGUL&R CODRDI NORTH/SOUTH EAST 183.70 N 2778 188.22 N 2786 195.50 N 2800 195.50 N 2800 203.84 N 2816 242.04 N 2886 243.99 N 2889 253.49 N 2906 254.3! N 2908 258.78 N 2916 275.69 N 2946 NATES /WEST .32 W .86 W .45 W .45 W .03 W .43 W .94 W .86 W .33 W .26 W .27 W FINAL WELL LOCATION AT TO: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 10009.00 9205.44 9128.44 HORTZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 2959.14 N 84 39 W S-CHLUMBEROER D I REC T I ONAL SURV E Y COMPANY ARCO ALASKA INC. WELL DS 14 - 37 FIELD PRUDHOE BAY COUNTRY RUN ONE DATE LOOOED ~1 - OCT - 88 REFERENCE ~ELL · (2363' D.S. 14-37 HORIZONTAL PROJECT[ON FNL, 1636' FEL, SEC 9, TION, R14E, UM) ~::~TM ...................... , ................ 4 ............................. ? .............................................................................. i ......................t ............................ ."Z:::.iiE; 3: :. Z,: : [ ................................................................................................. · - r · t .... ..... : ..... I .......... ......... i WELL' D.S. 14-37 !,2363' FNL, 1636' FEL, SEC 9, TION, R14E, UM) VERTICAL PROJECTION -SO0 0 0 SO0 !000 ]500 2000 2BO0 9000 3S00 274. PROJECTION ON YERTIC,:,L PL~,,iZ 2'74. - S4. $C,-',,...-C i,"~ ,..S.~'.']C,qL BEP'THS Fi0.:,:L _3.:,L_ :- I __. ~...CT -MEMORANDUM State of Alaska ~ALAsKA OIL A~D GAS CONSERVATION COMMISSION To: Lonnie C Smith /!~ ~ DATE: January 9, 1989 Commissioner F~LENO: D.BDF. 160 THRU: FROM: Sr Petroleum Engineer Bobby D Foster~~~ Petroleum Inspector TELEPHONE NO: SUBJECT: BOP Test AAI PBU DS 14-37 Permit #88-49 Prudhoe Oil Pool Sunday, December 18, 1988: The test began at 12:30 p.m. and was C°hCiudedat '4~-3~ p, ml .... As the attached BOP test report shows there were no failures. In s~ary, I witnessed the BOP test on Alaska United Rig WSR#I completing AAI' s DS 14-37. Attachment 02-001A (Rev. 8~85) 5/84 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E, Inspection Report General ltousekeeping ~.~- .Rig Reserve Pit ~//~ Mud. Systems Visual Location: See ~ T/~]I1)~'~ M 0 ~-~/,~'~ 7 ~asing Set 0 ~ ~/ ft. ' Location, General ~ Well Sign ~' ACC~LATOR SYST~ ~ Full Charge Pressure _ff~'~ psig Pressure After Closure/(~O _ psig _ Audio Pump incr. clos. pres. 200 psig -- min/~.sec. Trip Tank ~' Full Charge Pressur~ Attained: ~ .min ~ sec. Pit Gauge / H~ ~~~ .~ / ~ /~~ psig Flor Honitor ~" gontrols: Haster ~g ~ gas Detectors ~ RemOte ~.~ Blinds s~itch cover~~ _ ' / ' ~ Kelly and Floor Safety Valves . . Test Pressure "' Upper Kelly / ..~est Pressure .~'Z:U BOPE S tack Annular Preventer Pipe Rams · Blind Rams Choke Line Valves Il. C.R. Valve Kill Line Valves Check Valve Lower KellX Ball Type Inside BOP Choke Manifold~Test .o. Val. v?s c/' ' No, flanges ~ Adjustable Chokes / Hydrauically operated choke /' Test Pressure /' Test Pressure / Test Pressure Test Results; Failures ~ Test Time~ //P~- hrs. Repair or Replacement of failed equipment to be made within dayh and Inspector/ Commission. office notified. Distribution orig. - AO&GCC cc -.Operator cC - Supervisor ARCO ALASKA, INC. F'.O. BOX ANCHORAGE, ALASKA 995 ~ ~) DATE' t2-28-88 REFERENCE: ARCO CASED HOLE FINALS 2-i 6 t2-2t-88 COLLAR/PERF RUN i , ?-26 t2-t6-88 PRODUCTION RUN ~ , ?-2? ~ 2-~ 6-88 CNL RUN ~ , ?-29 ~2-i6-88 CNL RUN ~ , i 4-37 i 2-i 8-88 COLLAR RUN i , i 4-38 i 2-i9-88 COLLAR/PERF RUN t , i 4-39 i 2-i 9-88 CBT RUN i , t 4-~9 i 2-i 9-88 CET RUN i , PLEASE SIGN AND RETURN THE ATTACHED COF'Y AS RECEIPT OF DATA, .- RECEIVED BY HAVE A NICE DAY! SALLY HOFFECKER ATO-i527 TRAN$ ~88727 APPROVED R _ gn~hora~ DISTRIBUTION m 5' 5' 5' 5' 5' 5' 5' ATLA$ SCH $CH SCH ATLAS ATLAS SCH SCH CENTRAL FILES CHEVRON DAM EXTENSION EXPLORATION EXXON MARATHON MOBIL F'HILLIP$ F'B WELL FILES R & D SAPC STATE OF ALASKA TEXACO ARCO ALASKA, P.O. BOX ANCHORAGE, ALASKA 995~ DATE: t o-mm-88~ ~.~. REFERENCE: ARCO CASED HOLE FINALS 3-9 t t -t 3-88 COLLAR/PERF RUN 3-~9 ~t-t3-88 COLLAR/F'ERF RUN ~, 5' ~-'25 ~ ~ - ~ 9-88 COLLAR/F'ERF RUN ~-26 ~ 2-~ ?-88 COLLAR RUN 3-26 ~ 2-t6-88 VERTILOG RUN 5-~ ~-28-88 COLLAR/PERF RUN ~, 5' ?-~ ~ t 2-t ?-88 COLLAR/F'ERF RUN ?-~9 ~2-~7-88 CNL.GAMMA RUN 2, 5' 7-34 tt-tt-88 COLLAR/PERF' RUN t, 5" t2-t t2-t8-88 COLLAR RUN t, 5" t2-t5 t2-t4-88 MECH. PLUG SETTING RECORD RUN t, 5' t4-37 i2-i7-88 COLLAR/PERF RUN i , 5 PWDWt-i ii-9-88 CCL RUN t, 5' PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA. GEAR GEAR GEAR AI'LA~ ATLAS GEAR ATLAS ATLAS GEAR AI'LA~ $CH ATI_A~ GEAR RECEIVED BY HAVE A NICE DAY! SALLY HOFFECKER ATO-J529 TRAN$ ~88724 APPROVED Ancn0r~g~, DISTRIBUTION CENTRAL FILES CHEVRON DiM EXTENSION EXPLORATION EXXON MARATHON MOBIL PHILLIF'$ F'B WELL FILES R & D SAF'C STATE OF ALASKA TEXACO ARCO ALA£'KA, INC~ P., 0 ~ BOX ~ (:'; ;o} S 6 ;/.~ A i'.~. C: H C! R A g E, A L A S'K A DATE' ~ ~ -~ ,3-88 I-,.c.r::.!-,,""Nf:E' Ai:;~rtF~ CASED HOLt:: i::'INAL. S' :2-'3 i i-S-88 (:'::NL-C. Ai"iNA ::-2--4 i (-)-'24- S i'3 CCI_ · ? _ c.:, i ! - 4 -- .n ,::, f": N L '- (; A i"i M A 2--i :i-':', i' 4, - ..... a - ,:: ":,::, CNi .... -- f:;- A H i'iA 4 ..... i i (') -- 'i 4 -' E: 8 F' R 0 i') tJ C T .1:0 N F:' R 0 F' :i: L E 4 .... i i i -'"."---:;-]::'~ CNL-(.':-Af"iHA "; .... '". i i - ='' "" ':::',<:' C N t... -' C- A h ii A <*.. 'i '::' i ":"' '* '::: .... ,:::, c:, :[ N.J E C T I 0 N P F.'. 0 F' :[ ~ r:' ,.':'- ..... i 7 i ,':'~ .... '~ 2- E: S 'r N. i f..:; C "f' ]: f"J N P R (3 F' ]; i... -29 i i-4-88 (::.:NL-C-.ANHA .... 3; i i .... .,.:.:" --.:,"'"'"..:::, f':i',~i ....... .... L?'"AHNA · '-i :.?; i i .... 2-88 "'NL'-C..AMHA, .... 2 .'::, i i -- :::':'. - S S '¥' i...,.' B i N f'.; C: U 'T' ","' i.:: l:i'. .... ~'.;...; IL" ....- I "" .-' ,~ ,, ". ..., i ;""- ,i ,."5 '- 8 S F:' F'4,'.") t; I IC'.'T' T 0 ~-,i F' F;.: 0 F I L E "' (.-) Fi id M A i '/,..:: .... :}"¢ 'i (." -- i .'-"-i. - B 8 i::' I':;.: 0 I) U C 'I" ! [) N F:' t:(0 i:: ]: L.. E: ,S' U R V E Y "'~ ' .., --' F:'R ,.-.. '-" ~'.':, i ":"- i ,5 8 F: 0 D ~J C 'i" ]: 0 N F' F;: U F' ! L E 2 '-' i (i:' i ¢-- i ;:.:" '-' iii: 8 P :i: T 4 .... i 5 i ¢'-. i 5: -E: 8. i ri j Ii[ C' T ";: 0 M F:' I';:. 0 t::' i i_ E .,.t, .... ...:= 7 i ":;,, - 5 i --' 8 ::::: C. ii', 'r', 4 '-- 3 '7 i '3' -':5 i -- 8 :F', C E "F 4 .-' '58 I O---'3 i ---E: E: C ti: T ,:1- .-. :?: :.':.:-.': i ,::':, .- :.:4: 'i '--- 8 :::~ C E T '::---":' ~:' i ,:.:.:, -- 2 (-) -8 ::-': C:: C L_ --' (.'.;. A M H A ,...' ¢:o..~.' 6 -- '7 t (::' -- 2 2 --- 8 8 P J:;.'. 0 D U C i" :t: 0 ri. J"' R U F' :!: L. E 8--- 2 i (') .... ':,J: :': -E: 8 C: C; I._ '" '"'"' ... ---- , .:, ~-.:, ,, ~ ~-.J R A Y W t.., W ,:.-, '- i t ;?, 4 .Z '- E', :.:~ j'" .: i-:4 i.-, *- P !... E: A £ E ,S' 16 N A N D R E: T U R N T i--t E A T T A C i.-I E D C 0 P ¥ A S Fi E: C i::..i: F:' T F,:tJ N i., R U N i , I:,'. U N i , R UN i , I:;..' LJ i'..! RUN i R tJ N F:..' U N 'i I:~..' U N i , I:;..' I.JN t , R LJN i , F;:. U N i , RUN i, RI. JN i , RLJN i, RUN i: i-< tJ f'4 1, R U t.,!i, RUN i, F;:.L.I N i , I:;..' U N i , I:;.'.t.JN i , F< U M 'J , F;.: I_1N i, F;:. U Ni , I) A 'f' A., 5" .5." .5" t:2' ts .~. '.5" r:.. i1 ./ r" tl .~. A C: A r-i C L) A'¥'L A ,:.: A 'i' L A ,:-:.' C:Ar"IC u A TI_A;:: C A H C (3 C A M C I.'] ATL. A;~ A T L. A S' ,':4 'f L A 2.' AT'L. AS C A r,'i, (:: i] C: A M C' 0 CAMCO CAMCO CAMCO SCH SCH ,? C H C A M C 0 C A M C 0 C A t't C 0 C A id C 0 R E C I-':: :[ V E D B Y' ................................... HAVE A N'j:C::E DAY! 3' A L. L. Y H 0 F:' F: FZ C K iZ F..' A'T' ("O .... 'J 5:29 TRAN,?;' ~886'.~(.") ~ A F:' P F;.'. 0 V E :() ................................................... D :I: i: 'T' R :1: 'B i..j "1" :[ 0 i'"4. P H I L.. L.. ]: F' ,? F' ~', W E L L F' ! L t::Z S i::..' & D .ii. · ,,- ;:':: fa F:' C: ~' T A 'f' I_::.: C:; F;' r4 I... A ,:';' i<:. T E: ",:' ;:4 C 0 STATE OF ALASKA .... AL,-,,_,KA OIL AND GAS CONSERVATION COMMI~,,.,,ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend__ Alter casing __ Repair well Change approved program __ 2. Name of Operator Operation shutdown ~ Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Pull tubing __ Variance __ Perforate __ Other __ 5. Type of Well: Development Exploratory Stratigraphic 9951 0 . 03 60 Service 3. Address P. 0. Box 100360, Anchora.~em AK 4. Location of well at surface 2364.' FNL, 1636' FEL, Sec.9~ T10N~ R14-E, UN At top of producbve interval 6. Datum elevation (DF or KB) RKR 77 ' 7. Unit or Property name Prudhoe Bay Unit 8. Well number 14-37 9. Permit number 2200' FNL, At effective depth 2035 ' FNL, At total depth 2025' FNL, 850' FWL, Sec.9, TION, R14E, UM (Approx) 695'FWL, Sec.9, TION, R14E, UM (Approx) 680' FWL, Sec.9, TION, R14E, UM (Approx) 88-b. 9 10. APl number 50-- 029-21 810 11. Field/Pool Prudhoe Bay 0il Pool feet 12. Present well condition summary Total depth: measured true vertical 1 0009 ' MD feet 9197'TVD feet Plugs (measured) N o n e Effective depth: measured true vertical Casing Length Structural Conductor 80 ' Surface 3 443 ' Intermediate Production 9594 ' Liner 668 ' Perforation depth: measured true vertical 963 8 ' MD feet feet 91 57 ' TVD Size Junk (measured) None Cemented Measured depth True vertical depth 20" 2150# Poleset 1lO'MD 13-3/8" 2000 sx CS ill & 3478'MD 600 sx Class G - Top Job w/200 sx CS 9-5/8" 7" None None 110'TVD 3478'TVD 880 sx Class G 9626'MD 8847'TVD 300 sx Class G 9341'-lO009'MD/8589'-9197'TVD Squeezed Liner Lap w/150 sx Class G Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) N o n e ' ~':ch0rage 13. Attachments Well Hi story Description summary of proposal __ Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 115. Status of well classification as: 16. If proposal was verbally approved I Oil v/" Gas Suspended Name of approver Date approved Service 17. I hereby certify tha~.,t the/f~regoi ng is true and correct to the best of my knowledge. FOR COMMISSION USE ONLY ~ ~ - C°nditi°ns °f appr°val: N°tifyC°mmissi°n s° representatiVe may WitnesSplug integrity __ BOP Test Location clearance (Dani) SA4/0091Appr°val N°' r~,.. - ~ Mechanical Integrity Test__ Subsequent form required 10- ~Z~:~_ Approved by order of the Commissioner ORfGI~,]a~ SIGNED BY LONNIE C. $1VI!TH Approved Copy Returned ~ ///'"' / .~'"~':rJ; ~'~Commissioner Date Form 10-403 Rev 06/15/88 Subsequent Work Reported on Form No. SUBMIT IN TRIPLICATE ARCO Oil and Gas Company Well History- Initial Report- Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are slarted. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Field ARCO Alaska, Inc. icoun,y, ~t6~°~f,~P E Lease o[~)~t: 28312 Title DRILL PRUDHOE BAY ista~K DS 14 3~Well no. - I~ Iq-,3q ' Auth. or W.O7[]~2165 Operator ARCO Spudded or %~.~gun Date and depth as of 8:00 a.m. 09/12/88 ( TD: 650'( SUPV:CTD 09/13/88 ( TD: 1962'( 1 SUPV:CTD 09/14/88 ( TD: 3500'( 1 SUPV:CTD 09/15/88 ( TD: 3500'( SUPV:JCP 09/16/88 ( TD: 3706'( SUPV:JCP 09/17/88 ( 6 TD: 4715'( lC SUPV:JCP APl: 50-029-21810 I A"%%w. b000 IOata 09/11/88 [Hour 1730 HRs [Prior status If a W.O. Complete re~/l~)rRe~ch2~ repo,ed ) i5o) ) 12) ) 38) ) 0) 36) ) 09) DRILLING 20"g 110' MW: 8.7 VIS=220 RIG UP FLOOR & TAKE ON WATER. NO DIVERTER & MIX SPUD MUD. PU BHA & RIH. FUNCTION TEST DIVERTER. FILL HOLE & REPAIR LEAKS g BELL NIPPLE. SPUD WELL ~ 1730 HRS, 09/11/88. DRILL F/108'-438'. WIRELINE SURVEY ~ 419'. TRIP FOR BIT. DRILL F/ 438'-585'. CLEAN OUT FLOW LINE. DRILL F/ 585'-650'. DAILY:S102,133 CUM:$102,133 ETD=S102,133 EFC=$2,548,000 TRIP FOR BIT #4 20"~ 110' MW: 9.8 VIS:185 DRILL F/ 650'-720'. WIRELINE SURVEY 1/2 DEG. REPAIR CAVIUM PUMP. DRILL F/ 720'-1009'. WIRELINE SURVEY 0 DEG. DRILL F/ 1009'-1209'. TRIP FOR BIT #3. DRILL 1209'-1499'. WIRELINE SURVEY 1/2 DEG. DRILL F/ 1499'-1962'. TRIP FOR BIT #4. DAILY:S57,480 CUM:$159,613 ETD:S159,613 EFC:$2,548,000 CIRC AND CONDITION HOLE 20"@ 110' MW: 9.9 VIS: 77 FIN TRIP FOR BIT #4. DRILL & SURVEY F/ 1962'-3130'. CIRC & CLEAR FLOWLINE. DRILL F/ 3130'-3500'. CIRC HOLE CLEAN. SHORT TRIP TO HWDP. CIRC & COND. DAILY:S54,330 CUM:$213,943 ETD:S213,943 EFC:$2,548,000 NO 13-3/8 BOPE 13-3/8"@ 3478' MW: 9.9 VIS: 86 FIN CIR & COND. DROP SURVEY & PUMP PILL. POOH & LD BHA. RU CASING TOOLS. RUN 85 JTS 13-3/8" CSG TO 3478'. CIRC & COND. PUMP 100 BBLS WATER. PUMP 2000 SX CS III @ 12.2 PPG FOLLOWED BY 600 SX CLASS G ~ 15.8 PPG. DID NOT BUMP PLUG, NO CMT TO SURFACE. LD LANDING JT & PO DIVERTER. CLEAN PITS WHILE WAITING ON 1" TBG. PERFORM TOP JOB W/ 200 SX CS II @ 14.9 PPG. NIPPLE UP FMC GEN 4 PROTOTYPE NON-WELD WELDHEAD & TEST TO 1000 PSI. NIPPLE UP BOPE. DAILY:S285,612 CUM:$499,555 ETD:S499,555 EFC:$2,548,000 DRILLING 13-3/8"@ 3478' MW: 9.1 VIS: 33 FIN NU BOPE. TEST SAME TO 5000 PSI. MU BHA AND RIH. TEST CSG TO 2500 PSI. DRL FLOAT EQUIP AND 10' NEW FORM. LOT. CBU. DRLD TO 3600' KOP. POOH F/ BHA CHANGE. MU NEW BHA. TEST TELECO. FAILED. CHANGE TELECO. RIH AND DRLD TO 3706'. DAILY:S47,653 CUM:$547,208 ETD:S800,000 EFC:$2,295,208 DRILLING 13-3/8"@ 3478' MW: 9.2 VIS: 32 DRILL W/ 2 DEG BENTSUB & DYNADRILL TO 4469'. DROP SURVEY & POOH. LAY DOWN DYNADRILL & RIH W/ BIT ~7 & 3/4 DEG BENT HOUSING DYNADRILL. DRILL F/ 4469' TO 4715'. DAILY: $73,370 CUM: $620,578 ETD: $620,578 EFC: $2,548,000 Signature k~.~ For form prepa}ation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Title 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 all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lnlerlm" 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 Date and depth as of 8:00 a.m. ~County or Parish ARCO Alaska, Inc. I NORTH SLOPE ~Lease or Unit PRODHOE BAY I DS 14-37 ! Complete record for each day while drilling or workover in progress NABORS 28~- 09/18/88 ( TD: 5792'( 1 SUPV:JCP 09/19/88 ( TD: 6428'( SU?V=JCP 09/20/88 ( TD= 6804'( SUPV:JCP 09/21/88 ( 1 TD: 7230'( SUPV:JCP 09/22/88 ( 1 TD: 7692'( SUPV:CTD 09/23/88 ( 1, TD= 8170'( SUPV:CTD 09/24/88 ( TD: 8640'( SUPV:CTD 09/25/88 ( 1 TD= 9161'( SUPV:CTD ~) 177) ~) ;36) ~) t76) )) 126) .) t62) ~) 178) ~) 70) ) 21) The above ia correct ,. , For form preparahon and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 Istat~,K DRILLING 13-3/8"@ 3478' MW: 9.3 VIS= 39 DRILL F/ 4715'-5166'. DROP SURVEY AND PUMP PILL. POOH FOR BIT. SERVICE WEAR BUSHING. RIH W/ BIT #6. DRILL W/ DYNADRILL F/ 5166'-5792'. DAILY=S58,106 CUM=$678,684 ETD:S678,684 EFC=$2,548,000 DRILLING 13-3/8"@ 3478' MW= 9.3 VIS= 35 DRILL W/ DYNADRILL F/ 5792'-6298', LOST 600 PSI. DROP SURVEY & PUMP PILL. POOH. LD DYNADRILL, MOVE STABILIZERS. RIH W/ BHA #5 & BIT #9. WASH TO BOTTOM 6226'-6298'. DYNADRILL F/ 6298'-6426'. DAILY=S57,757 CUM=$736,441 ETD:S736,441 EFC=$2,548,000 DRILLING 13-3/8"@ 3478' MW= 9.3 VIS= 35 LOST 600 PSI PUMP PRESSURE. POOH LOOKING FOR WASHOUT, FOUND NONE. MU BIT #10 & RIH CHECKING ALL BREAKS. SLIP' & CUT DRILL LINE. FIN RIH. DYNA DRILL F/ 6428'-6804'. DAILY:S52,500 CUM:$788,941 ETD:S788,941 EFC=$2,548,000 DYNA DRILLING 13-3/8"@ 3478' MW= 9.5 VIS= 36 DYNA DRILL F/ 6804'-7058', MOTOR FAILED. DROP SURVEY & PUMP PILL. POOH & LD' DYNA DRILL - DUMP VALVE WASHED OUT. PU BHA #7 & BIT #11. TEST MOTOR & RIH. DYNA DRILL F/ 7058'-7230'. DAILY:S56,472 CUM:$845,413 ETD=S845,413 EFC=$2,548,000 TRIP FOR BIT#12 13-3/8"@ 3478' MW: 9.6 VIS= 41 DYNA DRILL F/ 7230'-7692' WITH 3/4 DEG BENT HOUSING MOTOR. CIRCULATE, MIX SLUG & DROP CHECK SHOT. TRIP FOR BIT #12. DAILY:S47,877 CUM:$893,290 ETD:S893,290 EFC=$2,548,000 DRILLING 13-3/8"8 3478' MW= 9.6 VIS= 38 FINISH TRIP FOR BIT #12. WASHED THROUGH BRIDGE AT 7200'. DRILL F/ 7692' - 8170'. DAILY:S53,593 CUM:$946,883 ETD:S946,883 EFC:$2,548,000 DRILLING 13-3/8"8 3478' MW: 9.8 VIS: 40 DRILL F/ 8170'-8252'. DROP SURVEY, PUMP PILL & POOH. CHANGE AIR BOOT ON FLOW LINE. CHANGE BHA & RIH. REAM 8150'-8252', TIGHT HOLE, STUCK PIPE, WORK PIPE FREE. DRILL 8252'-8640'. DAILY=$51,186 CUM:$998,069 ETD:S998,069 EFC=$2,548,000 DRILLING 13-3/8"8 3478' MW:10.0 VIS: 40 DRILL F/ 8640'-8788'. CIRC BOTTOMS UP. POOH & CHANGE BHA. RIH & REAM 73' TO BOTTOM, TIGHT HOLE. DRILL F/ 8788'-9161'. DAILY:S51,762 CUM:$1,049,831 ETD:S1,049,831 EFC:$2,548,000 JWell no. ARCO Oil and Gas Company Daily Well History--Interim Inslruclions: 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 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 deptll as of 8:00 a.m. ARCO Alaska, Inc. I IC°unty°r~H SLOPE I PRUDHOE BAY ILease or ~t 14-37 I Complete record [~A~aY2~e drilling o .... kover in progress 09/26/88 ( TD= 9587'( SUPV:CTD 09/27/88 ( TD: 9638'( SUPV:CTD 09/28/88 ( TD= 9700'( SUPV:CTD 09/29/88 ( TD:10009' ( SUPV:JP 09/30/88 ( ?D:10009'( SUPV:JCP 10/01/88 ( TD:10009 PB: SUPV:JCP 1~) 126) 1~) 51) ,) 62) ) 09) 1)) o) IStat~,.K IWell no. DRILLING 13-3/8"@ 3478' MW:10.1 VIS: 39 DRILL F/ 9161'-9525'. CIRC. POOH FOR BIT. SLIP & COT DRILL LINE. RIH, REAM 59' TO BOTTOM, TIGHT HOLE. DRILL F/ 9525'-9587'. DAILY:S45,841 CUM:$1,095,672 ETD:S1,095,672 EFC:$2,548,000 CIRCULATING 9 5/8 CSG 9-5/8"@ 9626' MW:10.1 VIS: 39 DRILL F/ 9587'-9638'. CIRCULATE BOTTOMS UP. SHORT TRIP 20 STDS. CIRC & COND FOR 9-5/8" CSG. POOH. PULL WEAR BUSHING & CHANGE RAMS TO 9-5/8", TEST BONNET SEALS. RU CSG TOOLS & RUN 104 JTS 9-5/8",47%, L-80, BTC-MOD AND 116 JTS 9-5/8", 47%, L-80, BTC TO 9626'. WASHED LAST 15' DOWN. CIRC & COND PRIOR TO CEMENTING. DAILY:S258,985 CUM:$1,354,657 ETD:S1,354,657 EFC:$2,548,000 DRILLING 9-5/8"@ 9626' MW: 9.0 VIS: 29 CIRC & COND. MIX & PUMP 130 SX CLASS G + 10% SAND, 8% GEL, 0.25% CD-31 @ 11.0 PPG. PUMP BATCH MIXED SLURRY OF 750 SX CLASS G + 1% BA-10, 0.2% CD-31, 0.4% FL-32, 0.3% A-2, 0.4% R-l, 1GHS FP-6L @ 15.8 PPG. DISPLACE W/ RIG PUMPS & BUMP PLUG. TEST CSG TO 3000 PSI. TEST PACKOFF TO 5000 PSI. CHANGE RAMS TO 5". RD CSG TOOLS. TEST BOPE, HYDRIL WOULD NOT TEST, REPLACE HYDRIL. TEST BOPE PU 8-1/2" BIT & BHA, RIH. TEST CSG TO 3000 PSI. DRILL F/ 9638'-9700'. DAILY:S106,747 CUM:$1,461,404 ETD:S1,461,404 EFC:$2,548,000 LOGGING 9-5/8"@ 9626' MW: 9.1 VIS: 38 DRILL TO 10009'. CIRC & COND. SHORT TRIP. CIRC & COND. POOH FOR LOGS. RU ATLAS WIRELINE ATTEMPT RUN %1 DIL/BHCS/GR/SP TOOL FAILED. CHANGE ROPE SOCKET. ATTEMPT RUN #2, TOOL FAILED. CHANGE OUT WIRELINE TRUCKS. ATTEMPT RUN #3 TOOL FAILED. CHANGE OUT TOOLS & ATTEMPT RUN 94. TOOLS FAILED. CHANGE OUT TOOLS, ATTEMPT RUN ~5. DAILY:S43,470 CUM:$1,504,874 ETD:S1,504,874 EFC:$2,548,000 RUNNING 7" LINER 7"@10009' MW: 9.1 VIS: 33 RUN Z DENSITY/CAL/GR F/ 10005'-9620', GR TO 7000'. RUN DIL/BHCS/GR/SP F/ 10005'-9620'. RIH W/ BIT. CIRC & COND MUD FOR LINER. POOH. RU CSG TOOLS & RUN 14 JTS 7", 29#, L-80, BTC. CIRC CAPACITY OF LINER. RIH W/ LINER ON DRILL PIPE. DAILY:S70,793 CUM:$1,575,667 ETD:S1,575,667 EFC:$2,548,000 RIH TO CLEAN OUT 7" 7"@10009' MW: 9.2 WBM FIN RIH W/ 7" LINER. CIRC & BATCH MIX CMT. PUMP 50 BBLS 10.0 PPG MCS-4. PUMP 300 SX CLASS G @ 15.8 PPG. BUMP PLUG W/ 3000 PSI, FULL RETURNS, & SET LINER HANGER. POOH W/ LINER RUNNING TOOL. RIH W/ 8-1/2" BIT TO 7784'. WOC. FIN RIH, TAG GREEN CMT @ 9309', TOL @ 9341'. CIRC OUT GREEN The above is correct For form pr~)paration and ~strib-ution see Procedures Manual Section 10, Drilling, Pages 86 and 87 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 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 string until completion. District Field ICounty or Parish ARCO Alaska, Inc. J NORTH SLOPE ~Lease or Unit PRUDHOE BAY I DS 14-37 Complete record for each day while drilling or workover in progress NABORS 28E CE~Ni. ~OOH RiH W/ 6" BiT, SLiP & CUT DRILL LINE. FIN RIH W/ 6" BIT. DAILY:S102,004 CUM:$1,677,671 ETD:S1,677,671 EFC:$2,548,000 Date and deptl~ as of 8:00 a.m. 10/02/88 ( 2 TD:10009 SUPV:JCP 1o/°3/88 ( 2 TD: 10009 PB: SUPV: JCP WOC 7"@10009' MW: 9.2 WBM FIN RIH, TAG LANDING COLLAR, NO CMT. TEST LINER L~, BROKE DOWN @ 2500 PSI & 2.5 BPM. DRILL LANDING COLLAR & WASH TO FLOAT COLLAR, NO CMT. CIRC. POOH. RIH W/ 7" RTTS & TEST SHOE TO 3000 PSI, LAP BROKE DOWN @ 2000 PSI. POOH. PU 16 JTS 3-1/2" DP & RIH. CIRC W/ ONE JT INSIDE OF LINER. HATCH MIX 150 SX CLASS G + 0.65% FL-25, 0.3% CD-31, 0.25% A-2 @ 15.8 PPG. SPOT CMT ON TOP OF LINER, SQUEEZED 20 BBLS INTO LAP W/ 2000 PSI. WOC. DAILY:S53,160 CUM:$1,730,831ETD:$1,730,831 EFC:$2,548,000 LD DRILL PIPE 7"@10009' MW: 9.0 NaC1 FIN WOC. POOH. RIH W/ 8-1/2" BIT TO TOL, NO CMT. CIRC BOTTOMS UP. POOH. RIH W/ 6" BIT, TAG HARD CMT 10' INSIDE LINER. TEST LINER LAP TO 3000 PSI. DRILL CMT F/ 9351'-9420'. RIH TO FLOAT COLLAR. RETEST LINER TO 3000 PSI. CIRC OUT HEAVY MUD. REVERSE 9.0 BRINE W/ C-193 INHIBITOR. RETEST LINER TO 3000 PSI FOR 30 MINUTES. POOH & LAY DOWN DRILL PIPE. DAILY:S73,978 CUM:$1,804,809 ETD:S1,804,809 EFC:$2,548,000 IWell no. The above is correct For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, reporl completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. IAccountlng cost center code .i.u~ ]County o~!~ ~z~Jz'~ I Stattt.K. District ~-u~.%,v ~~ ' - '-. I / ~"~ == Title Auth. or W.O. ~' *"~ Operat.or ~.--~v Spudded or ~ ~"gun Date and depth as of 8:00 a.m. TD:10009 PB:9965 SUPV:JCP Old TD Released rig Classifications (oil, gas, etc.) A.R.Co. ~.%.' vvvv iDate v~/~/oo I Complete re~~c~ reposed otalnumber of wells (active or inactive) on this I ost center prior to plugging and bandonment of this well I IHourI'~''~ ~'~'~ IPrlor atatu, if. w.o.' POOH. LDDP. ND BOPE. INSTALL DUMMY HGR. NU ADAPTER. TEST PACKOFFS TO 5000 PSI. CLEAN PITS. FREEZE PROTECT WELL. RIG RELEASED AT 2230 HRS, 10/03/88. DAILY:S42,149 CUM:$1,846,958 ETD:S1,846,958 EFC:$2,548,000 INew TD J PB Depth Date IKind of rig Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ARCO ALAS'KA, P~ 0, BOX ~ ,'..-'.)(.)S6~) ANCHORAGE: ALA.?KA 99.5~ (:..~ A 'i" L A 5' CENTRAl... I::It...E,?...' (CH) C I-'t E V R 0 N D & i"i F:' ,. MCF'HEI:i:TERZ ( OH ) MAF;:ATHON i"'i O B ]: L. "".,,. I::' H I L. L I F' 5' F:'B W 1:'" 1.. L I:: I L IL'",?? R & D :If. Z A F'C :ti'.,?"f'A 'i" E 0 i::' A I... A 3 K A 'l" i::.: X A C' 0 ARCO ALA~'KA, INC. P.O. BOX t00360 ANCHORAGE, ALAS'KA 995 t 0 DATE' t0-7-88 REFERENCE' ARCO CASED HOLE FINALS S-t2 ~i~"9-25-88 , .SPINNER SURVEY 4-2S 9-S0-88 PI;,'ODUCT I ON 4-28 i 0-i -88 F'RODUCT ION o.-'~ o.-~7-88 PRODUCTION PROFII_E t 2-~ 9 9-S~-88 COLLAR/PERF ~4-25 9-23-88 INJECTION PROFILE ~4 ,~¢ 9 29.-88 CN '-' ....." RA -.' .... - L -- - L, ~.~ t~ ~ ~ ~6 ~6 9 '~9 -. -~. -~8 COLLAR/'F'ER.F ~ 6-~ 6 9-~ 6-88 GAMMA RAY (F'RINTED A;~ "F'IELD," ACTUAI. I.Y A F'INAL) RUN ? 5" RUN ~ , ' 5" RUN ~ , 5' RUN ~, 5" F;.'.I.JN ~, ~'~'..." RUN '4, ..,'~'" RUN ~ , 5" RUt'S.~, .,. RUN i, 5" PI_EASE ,SIGN AND RETURN THE ATTACHED COF'Y A'S RECEIF'T OF DATA, O'i" 15' $CH 5'CF! CAMCO C: A M C 0 ~':~ 'i'L A J CAMCO ATI._A~ A t" k. A :~' CAMCO RFCEIVE:D BY ...................................................... I"tAVE A NICE DAY! $,.'AL. LY HOI::FECK ER A'I-O- i 529 TRANS/ ~:886i ¢, ~ APPROVED t~__ D I ~.' T R :[ B [J T l 0 N CENTRAL FII..E$ CHEVRON I) & M ~ EXTENSION EXF'LORAFION:" EXXON MARATHON MOBIL ~ PHILLIPS PB WELL FILES' R & D ~.'"'SAF'C -.. 5"I'ATE OF ALAS'KA '"'.,- TEXACO ARCO ALASKA, INC. P~ O, BOX i ANCHORAGE ~ ALASKA 995t DATE · ~ 0-7-88 R E F' E R E N C: E ' ARC(]) OPE!iN HOL. E F1NAI-..,.~ I)IFL- ....... GAMMA R[JN i, 2 "&'5" BIqCS ....... GAMMA RtJN i , ':2 "&5" COMPENSATED Z DEN,S'I'fY-[;AMMA (RAW) RUN i, 2"&5" COHPENSATED Z DENSITY/NE~JTF;,'ON F:'ORO R[JN i, F:'LI:EASE SI[;N AND RE'FURN TFIE ATTACHED COF:'Y A,S' RECEIP'i" OF:' Ii) ATA, A'f'L. AS ATI_A$ A'FLAY A"FI..AS RECEIVED BY ............................................................................ i-lAVE A NICE: DAY! ~'~L~I ~ I,,~ ,L..L.. r HOFFE,::. L::R OCT 1 o 1988 A 'i' (3 -- i .5:2 9 TR" .... ~.~o .... t..I N,.~ ~r .:. ~.~ ¢.':., 1 .,:. A P P P, 0 .... V Er t:, D I $'¥ R I B U'F I 0 N ¢: C E N'f' R A L. F:' I I... Iii: 3' · ".:" E:I"t E V I'i' LIN .II: D,...*- Pi IEN~ION I:ZXF'i..ORATION f~ E X X 0 N ~.,~ HAt:.'.A Tt.~r'~N_ . ~"~,.M 0 B I L. ARCO Alaska, Inc. Post Office B, 30360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 3, 1988 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: ion P1 at ~. Dear Mr. Chatterton' Enclosed are as-built location plats for the subject wells. questions, please call me at 263-4944. Sincerely, If you have any J. Gruber Associate Engineer JG'pk GRU13/11 Enclosure RECEIVED Alaska Oil & (]as Cons. ¢ommlsslorl Anchorage ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany Iio I~0 OI I~0 O~ 14o 05 04 05 ~0 06 I00 O~ OB 05~ 290 2B0 4 I $ I J T. 1/N, ' I ~' /ON. I , VICINItY MAP NO $CAL£ LOCATED WITHIN PROTRACTED SEC. 9,1:ION.. R. 14 E.,U.M. Id'37 Y-'5,95Z,9$B.~$ LAT.; 70°/4'/0.360'' X~674,865.286 LONG.=I48°35'I?.038'' 236~' ~N.L., 163~'Kg.L. ELgV.= 42.0' 14'38 14.35 Y= 5,937,910.~$ LAT.-' 70°14 X-' 674,8~'B. 91 LONG.;14B°$$'I6.680'' 24~1 'F.N.L., 1825'F.E.L. EL£V. = 4~.0 LAT.;?O°I4'OB.6$O " LONG.; 14 159~'F..E.L. ELEV. /4'40 Y;5,95Z, 675. Z6 LAT.: 70°14'0T. 4?~'' X: 6 74,954.20 LONG.;14B°$5 2$SG' F..N.L., 15?4' F..E.L. ELEV. = 42.7' NOTES 0 EX/STING WELL · CONDUCTOR AS-BUILT I. BASIS OF LOCATION I$ O.$. /4 CONDUCTORS ~0 8 21 AS BU/LTS PER VECO , INC. 2. ALL COORDINATES SHOWN ARE A.$.P. ZONE 4, NAD ~?' DATUM. MAYO I HEREBY PROPERLY LICENSED SURVEYING Alaska Oil & f}as Cons, Commissf, CERTIFY THAT I AM REGISTERED AND TO PRACTICE LAND IN THE STATE OF ALASKA AND THAT THIS PI. AT REPRESENTS AN AS-BUILT SURVEY MADE BY ME, AND THAT ALL DIMENSIONS AND OTHER DETAILS De $ cr /,olio n ARCO Alaska, Inc. DRILL SITE 14 CONDUCTORS 37, $8, $9 & 40 AS' BUILT LOCA TI ON o,. ~z.' J. B./! IC*. ~r .' 8. B. i oo. ~e .' ~ - ZZ . BB Owg. No.: CEA - 3700 - 004 ,' May 5, 1988 Telecopy: (907) 276-7542 Mr. T. P. Oostermeyer Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Prudhoe Bay Unit D.S. 14-37 ARCO Alaska, Inc. Permit No. 88-49 Sur. Loc. 2364'FNL, 1636'FEL, Sec. 9, T10N, R14E, UM. Btmhole Loc. 2190'FNL, 686'FWL, Sec. 9, T10N, R14E, UM. Dear Mr. Oostermeyer: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout' prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter, system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Ver~v~ truly/yoB~ r ~s ~. V. Chatta~to'n Chairman of Alaska Oil and Gas ~onservation ~o~ission BY ORDER OF THE COMMISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ,"" STATE OF ALASKA ~ ALASK.. OIL AND GAS CONSERVATION ',,.,OMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill ~, Redrill []1 lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] Deepen[]1 Service [] Developement Gas [] Single Zone,,~, Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 77'~ PAD 42'GLfeet Prudhoe Bay Field 3. Address 6. Property Designation Prudhoe Bay Oil Pool P.O. Box 1003,60, Anchorage, AK 99510-0360 ADL 28312v''' 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20AAC 25.O25) 2364'FNL, 1636'FEL,Sec. 9,TION,R14E,UM Prudhoe Ba~/ Unit Statewide At top of productive interval (~ 8909'TVD) 8. Well nu.mber Number 2200'FNL, 850'FWL,Sec. 9,TION,R14E,UM DS 14-37 #8088-26-27 At total depth 9. Approximate spud date Amount 2190'FNL, 686'FWL,Sec. 9,TlON,R14E,UM 05/11/88 $500,000 12. Distance to nearest 13. Distance t° nearest well 14. Number of acres in property 15. Proposed depth (MD and TVP) property line DS 14-17 120' 9971 'MD 686 ' ~ TD feet @ surface feet 2560 91 82 ' TVD feet 16. To be completed for deviated wells 17. Anticipated p/r(~sure (see 20 AAC 25.035 (e)(2)) Kickoff depth 3600 feet Maximum hole angle 31 0 Maximum surface 2895 psig At total depth (TVD) 3775 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.5~ H-40 Weld 80' 30' 30' 110' 110' 2000# Poleset 17-1/2w 13-3/8 68# K-55 BTC 20' 30' :30' 50' 50' 2500 sx CS Ill & 72# L-80 BTC :3450' 50' 50' 3500' 3500' 600 sx CS II 12-1/4" 9-5/8 47# L-80 BTC/Mo( 9562' 30' :~0' 9592' 8857' 500 sx Class G 8-1/2' 7"* 29# L-80 BTC 683' 9288' 9030' 9971' 9182' 300 sx Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. *Contingency 1 i nar Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured dep. th~¢ ~, True Vertical depth Structural Conductor Surface A~ Intermediate Production ~,3S~iS 0;! & Gt~s Co~s. 60mm~ss~Ol:l Liner Perforation depth: measured true vertical 20. Attachments Filin~ fee j~ Property plat [] BOP Sketch ~ Diverter Sketch,~ Drilling program ,j~ ,,, Drilling fluid program~. Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requi rements 21. I hereby certify that ~ foregoing is true and correct to the best of my knowledge~i¢~ Signed ~'~~, ~ Title Regional Drillin~l/' Enc, lineer Date ¢¢~ Commission Use Only (MDD) PD2/91 615 -2¢~ 50--O¢---'9 ~ Z~St 0 05 / 05 / 88 for other requirements Conditions of approval Samples required [] Yes ~ No Mud log required Lq Yes .1~ No Hydrogen sulfide measures [] Yes ~ No Directional survey required ~. Yes [] No Requiredwo~~~. ~M; ~ 5M; [] 10M; E3 15M Other: by order of Approved by~,,__~ ¢, ~k~;~¢~/~_~_,,~ Commissioner the commission Date Form 10-401 Rev. 12-1-85 Sub~ triplicate PBU DS 14-37 OPERATIONS SUMMARY 1) MIRU drilling rig. 2) NU 20" annular diverter and function test same. 3) Spud well and drill 17-1/2" hole to 3500'. 4) Set 13-3/8" casing and cement same. 5) Install 13-5/8" 5000 psi RSRRA BOPE stack and test rams to 5000 psi, annular to 3500 psi. 6) Drill float equipment and 10' of new hole. Perform leak off test. 7) Drill 12-1/4" hole to 3600'. Kick off well and build angle at 2.5°/ 100' to 30o58' at N86°37'E. Maintain angle and direction to 15'TVD above the Sadlerochit at 9592'MD/8857'TVD. 8) Set 9-5/8" casing and cement same. 9) Test casing to 3000 psi. Drill out and perform leak off test. 10) Drill 8-1/2" hole to TD of 9971'MD/9182'TVD. 11) Run electric logs as programmed. 12) Run and set 7" liner and cement same. 13) Clean out liner to PBTD. Test liner, liner lap and casing to 3000 psi for 30 minutes. 14) Circulate well to brine, freeze protect and release drilling rig. 15) Run CET/CBT/GR to evaluate cement bonding. Squeeze if necessary. Run gyro. 16) MIRU completion rig. RIH and set packer. Run 4-1/2" tubing with GLMs and 4-1/2" tailpipe. NU 4-1/2" tree. RD completion rig. 17) RU electric line, perforate well. Install SSSV. PD2/91a 4/26/88 NOTE: b) c) d) e) In accordance with Area Injection Order No. 4, excess non-hazardous fluids resulting from well operations and as necessary to control fluid level in reserve pit will be disposed of down the 9-5/8" x 13-3/8" annulus. The annulus will be left with a non-freezing fluid during any extended interruption in the disposal process. The annulus will be sealed with 300 sx of cement followed by Arctic pack upon the termina- tion of fluid disposal, Wells within 200' of the proposed well are: DS 14-17 120' @ surface to +2000' DS 14-6 156' @ 4780'/4730'TVD The drilling fluid program and fluid surface system will conform to the regulations set forth in 20AAC25.033. Maximum surface pressure is based upon BHP and a full column of gas to TD (0.10 psi/ft). Based upon previous logs on DS 14, no potential productive zones are anticipated above 4000'TVD. PD2/91a 4/26/88 1000 200( 300( 4000 5000 6000 7000 8000 10000 11000 0 1000 2000 3000 4000 5000 6000 ] '' ''' '' ......... ZO'CASING ~6''''''' 'r Illo ,, .................. i, .............. ARC ) ALASKA, INC. ) I~ALI;;; I IN I, lOOf~ Fl. SHL: 2364' FNL, 1836' F SEC. 9, '[1ON, R14E, U d THIz 2200' FNL, 860' F~ ~L, RI:I~: I~_ T1ON_ RIAF_ I - (OP TVD I ~ IO 2.5 7.5 I ~' ' T2.D ' '~ " ...... N II DI;G II MIN ~ ~lO0 F'r(?O T&RIET) AVEr&II &NILI ., ~ ~EII& lIN ,. K-lO T'~B -- 8807 ~B - 72O~' DI::p - , ....... I K..6 TVDI7422 MDI1919 DE P -- 1909 , , SAG RIVER TVD I ;772 MD I 0493 DEP I 2718 SHUBUK TVD- 87 )7 MD- 9622 DEP - 2733 , , 8 t91 MD - 980a DEP- 2776 TAIIGET TVD - 8l 1OB MD u 088I OEP - I-N)T TVD - 904; MD - 9807 D£P 1 2878 · - 1090 MD - 98 63 DEP - 29011 )~-1)192 M0-9,71 OEP-2961 RECE' .... . ~ Ab .~,., ~il & Gas ¢cns. Comm,~s,0~ ~-? tI r A.,c.o, , , , , , , , , i, , , , , , , , ,, , , , , , , , ,, , , , , , , , ,, , , , , , , , · I , , , , , , , , ,· , , , , , , , , 0 lO00 2000 3000 4000 5000 6000 7000 0 lO00 2000 3000 4000 5000 6000 7000 8000 9000 tO00 IlOC 7000 -6000 '~-. E - i,4 COOROINRTES -'"-. -5000 - 4b,. O - 3000 - 2000 1000 0 1000 (3') CD Z 0 _ · . . [3~. 1~}-3 ~ ...~p,,.., 9 0 -6000 -SO00 -4000 -3000 -2000 - 1000 0 1000 E - ~ OOOROINRTES 62 -6000 0 0 0 o W 0 rK Z 0 o E - N COOROINRTES' ' ...... -5000 -4000 -3000 -2000 -tO00 0 lO00 I I I II III I I II I II II I · I I ~ II I II I II I I II I III III I I I II III II I I I ~i I I II i i ii · ii I i i i ii 0.~ 14-37 ///279! /~296 '- ~~7~/;866 ,, , / / · /'~969 79 .,~ 710 /' 05 1 z~-6 _ ~278 I -- -- II · II .. ..- ~ ~,~;~ ...... ~' ~7607 ~ [3. 14-17 I I Ii I I II i i I , iiii i I I I I I I I I 1 I I I i I i I I I I i I I I I I I I I i I I I! I ! I ! III 1 I I I 1 I ~ I I -6000 -5000 -4000 -3000 -2000 - 1000 0 1000 E - N COORDINRTES 0 o 0 OZo DS 1 -400 -~00 -200 E - N COOROINFt"I'Eu -100 0 100 200 300 I I m ii J m m i,, m m I ' ,I I I I I I I I I I I, ~ I m i i m , I ~ m I I I I , I I , I I I m ~ I I m I ~ , I I I I I I I I I I m . , ~ 459 d~ , ~ ' , /5os8 121 / ' 318 ,,, : 3[67 0.S. 1 ~-17 i i i I i i i ii i i I i i i i i i i i i i i i i i i i I i ~ i i i i i i I I I i i i I I Ill i iI t863 -400 -300 -200 -I00 0 100 200 300 E - N COOROINF~I'ES TYPICAL MUD PIT SCHEMATIC 3~2 3 2 . BBLS BBLS TRIP TANKS SANDTRAP (30 BBLS) ISHAKER I DEGASSER (83 BBLS) DESILTER (97 BBLS) ISHAKER I I (97 BBLS) PILL PIT (36. BBLS) DESANDER (36 BBLS) SUCTION PIT (448 BBLS) MIX PIT (122 BBLS) DRAWING IS NOT TO SCALE NOTE: SYSTEM IS EQUIPPED WITH A DRILLING FLUID PIT LEVEL INDICATOR WITH BOTH VISUAL AND AUDIO WARNING DEVICES AND A FLUID FLOW SENSOR LOCATED IN THE IMMEDIATE AREA OF THE DRILLER'S CONSOLE. JG 7/24/87 Depth (TVD) DS 14-37 MUD PROGRAM Plas Yield Density Visc. Point Initial 1OM #/gal (CP) #/1 O0 ft2 Gel Gel 40-60 30+ 50+ Surf 8.8 Funnel to to 100- 13-3/8" 9.2 250 Csg Point 13-3/8" 8.8 Minimum 2 2 5 Csg Shoe to Possible to to to to 9.4 4 4 10 K-10 FL CC/30M 25 Oil % Sol i ds pH and Type of Mud Gel -Benex Spud Mud 25 to 10 3.5 to 6.5 Low so l i d s/ non-di spersed K-10 9.2 10 6 4 8 to TD to to to .to' to 9-5/8" 9.8 15 10 8 12 Csg Point 9-5/8" 8.8 10 6 4 8 Csg Shoe to to to to to to TD 9.2 15 10 8 12 8 to 4 2 to 5 4 to 8 10 to 4 2 4 to to 5 8 pH 9-10 Low sol ids/ non-di sper sed Low solids/ non-dispersed EQUIPMENT - DRILLING FLUID SYSTEM 1. Degasser 2. Shakers 3. Pit level indicator (with both visual and audio warning devices) 4. Drilling fluid flow sensor (with readout convenient to the driller's console) 5. Trip tank 6. Agitators 7. Mud cleaner and centrifuges PD2/91b SURFACE HOLE DIVERTER SYSTEM SCHEMATIC ARCO ALASKA, INC. FILL-UP LINE RISER FLOWLINE 20" 2000 PSI DIVERTER 10" BALL VALVE 10" BALL VALVE I I I CONDUCTOR NOTE: ONLY ONE VALVE OPENS AUTOMATICALLY WHEN THE DIVERTER CLOSES. THE SECOND VALVE WILL REMAIN CLOSED UNLESS CONDITIONS REQUIRE THE USE OF THE SECOND VENT LINE. THE SECOND VENT LINE VALVE CAN BE OPENED USING CONTROLS LOCATED AT THE ACCUMULATOR. THIS IS A VARIANCE FROM 20AAC25.035 10" VENT LINES I I I I WELL I I '- RIG MODULES NOTE: 100' FROM ANY IGNITION SOURCE ALL TURNS 90 DEGREE TARGET TEES RESERVE PIT JG 7/27/87 13-5/8" 5000 PSI BOP STACK DIAGRAM ACCUMLILATOR CAPACITY TEST l REYENTER~ I PI PE RAHS ¢! I BLINDRAHS DRI LLI NG SPOOL I I · ART IPlG HEAD ALL BOP EQUIPMENT 5000 PSI RATED 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON IADC REPORT. THE ACCEPTABLE LOWER LIMIT 15 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. . . . 10. 11 12 13. 14. 15. 16. 17. 18. 13-5/8" BOP STACK TEST FILL BOP STACK AND MANIFOLD WITH A NON-FREEZING LIQUID, CHECK THAT ALL HOL~ DOWN SCREWS ARE FULLY RETRACTED, MARK RUNNING JOINT WITH PREDETERMINED PLUG SEATING DEPTH. RUN TEST PLUG ONDRILLPIPE AND SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS. CLOSE ANNULAR PREVENTER AND UPSTREAM VALVES. FUNCTIONALLY TEST CHOKES. 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, PRESSURE TO 3000 PSI AND HOLD FOR A MINIMUM OF3MINUTES. BLEED PRESSURE TO. ZERO, OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR AT LEAST 3MINUTES. BLEED PRESSURE TO ZERO. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES AND OPEN CHOKES. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR AT LEAST 3MINUTES. 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. TEST REMAINING UNTESTED MANIFOLD VALVES (IF ANY) WITH 5000 PSI UPSTREAM OF VALVE AND ZERO PRESSURE DOWN- STREAM. BLEED PRESSURE TO ZERO. OPEN BOTTOM 5ET OF PIPE RAMS. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BL!ND RAM5 AND TEST TO 5000 P51 FOP AT LEAST 3 MINUTES. 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. TEST STANDPIPE VALVES TO 5000 PSI. TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI. CHECK OPERATION OF DEGASSER. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. JG 8- 26- 85 Fee (2) Loc , s, lzl (2 thru 8) (8) (3) mdrnin ~ 3~Z/8~5 (9 thru 13) (10 and 13) (4) Casg f'm-$& (14 thru 22) (5) BOPE (23 thru 28) (29 thru 31) , ~,,.~,o Lease & Well No. ~Q YES NO Is the permit fee attached ........................................... ~7 /4/ REMARKS 2. Is well to be located in a defined pool ............................. ~ , ,, 3. Is well located proper distance from property line .................. ~ 4. Is well located proper distance from other wells .................... ~ · 5. Is sufficient undedicated acreage available in this pool ............ ~ 6. Is well to be deviated and is wellbore plat included ................ ~F , 7. Is operator the only affected party ................................. ~? 8. Can permit be approved before fifteen-day wait ...................... ~ e 10. 11. 12. 13. Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... '~ Is administrative approval needed ................................... ~ Is the lease number appropriate ... .................................. ~' Does the well have a unique name and number ......................... ~ 14. Is conductor string provided ........................................ 15. Will surface casing protect fresh wa=er zones ....................... 16. Is enough cement used to circulate on conductor and surface ......... 17. Will cement tie in surface and intermediate or production strings ... 18. Will cement cover all known productive horizons ..................... 19. Will'all casing give adequate safety in collapse, tension and burst.. 20. Is this well to be kicked off from an existing wellbore ............. 21. Is old wellbore abandonment procedure included on 10-403 ............ 22 Is adequate wellbore separation proposed · · ·eeeeeeeeeeeeeeeeeeeeeeeeee® 23. Is a diverter system required ....................................... _ 24. Is the drilling fluid program schematic and list of equipment adequate ~ 25. Are necessary diagrams and descriptions'of diverter and BOPE attached. ~ 26. Does BOPE have sufficient pressure rating - Test to ~-~mO psig .. ~ 27. Does the choke manifold comply w/AMI RP-53 (May 84) .................. 28. Is the presence of H2S gas probable ................................. For exploratory and Stratigraphic wells: 29. Are data presented on potential overpressure zones? ................. ~ 30 Are seismic analysis data presented on shallow gas zones ............ 3i~ If an offshore loc., are survey results of seabed conditions pre~,,'i, , ,, 32 Additional requirements ' o ~o Geology: En gineerin~: WWB ~ LCS BEW ,, rev: 02/17/88 6.011 INITIAL GEO. UNIT ION/OFF POOL CLASS STATUS AREA NO. SHORE Additional Remarks: /W,~ Am' ~;-~ ;~, 12o' o~ 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. * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : ARCO ALASKA INC. WELL NAME : DS 14-37 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292181000 REFERENCE NO : 98538 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-0CT-1998 16:31 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/10/24 ORIGIN : FLIC REEL NAME : 98538 CONTINUATION # : PREVIOUS REEL : COGENT : ARCO ALASKA, DS 14-37, PRUDHOE BAY, API# 50-029-21810-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/10/24 ORIGIN : FLIC TAPE NAME : 98538 CONTINUATION # : 1 PREVIOUS TAPE : COF~ENT : ARCO ALASKA, DS 14-37, PRUDHOE BAY, API# 50-029-21810-00 TAPE HEADER Prudhoe Bay CASED HOLE WIRELINE LOGS WELL NAME: DS 14-37 API NUMBER: 500292181000 OPERATOR: Arco Alaska Inc. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 24-0CT-98 JOB NUMBER: 98538 LOGGING ENGINEER: G. Johnson OPERATOR WITNESS: C SHUMWAY SURFACE LOCATION SECTION: 9 TOWNSHIP: iON RANGE: 14E FNL: 2364 FSL: FEL: 1635 FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: 74.00 DERRICK FLOOR: 73.00 GROUND LEVEL: 42.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 8. 500 7. 000 10009.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-0CT-1998 16:31 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: 1988 LOGGING COMPANY: WESTERN ATLAS BASELINE DEPTH 88888 0 9739 5 9732 5 9721 5 9720 5 9717 5 9716.0 9715.0 9713.0 9706.5 9703.0 9702.5 9701.0 9698.0 9696.0 9695.0 9693.0 9687.5 9685.5 9683.5 9676.5 9675.5 9668.0 9666.5 9655.0 9651.5 9647.5 9642.0 9639.0 9626.0 9600.0 9594.5 9591.5 9584.0 9583.0 9582.5 9579.5 9576.5 9571.5 9568.5 9566.5 9566.0 9564.0 9557.5 9556.0 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH RST 88889.0 88890.5 9721.5 9718.0 9716.0 9706.5 9703.0 9697.5 9688.5 9686.0 9677.5 9668.5 9656.5 9653.0 9642.0 9598.5 9595.5 9592.0 9585.0 9583.0 9580.0 9571.5 9568.0 9566.0 9557.5 9742.0 9734.0 9723.5 9717.5 9715.5 9706.0 9702.5 9700.5 9697.0 9695.0 9686.5 9678.0 9668.5 9649.5 9641.5 9628.5 9595.5 9585.0 9576.0 9571.5 9568.0 9565.5 9557.5 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-0CT-1998 16:31 9555.0 9554.0 9545.0 9544.0 9539.0 9538.5 9537.0 9536.5 9539.0 9535.5 9536.5 9529.0 9529.0 9514.0 9513.5 9486.5 9486.0 9477.5 9477.0 100.0 99.5 101.0 $ REMARKS: CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE RST DATA AQUIRED ON ARCO ALASKA'S DS 14-37 WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #1 AND THE BASE GAM~A RAY, ALSO BASE PASS #1 SIGMA AND THE BASE GAMMA RAY, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: O. 5000 FILE SUPmL~Y LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9740.0 9467.5 RST 9752.5 9469.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-0CT-1998 16:31 PAGE: REMARKS: THIS FILE CONTAINS CASED HOLE RST BASE PASS #1. THERE ARE NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 96 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 10 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 6047505 O0 000 O0 0 1 1 1 4 68 0000000000 NBAC RST CPS 6047505 O0 000 O0 0 1 1 1 4 68 0000000000 FBAC RST CPS 6047505 O0 000 O0 0 1 1 1 4 68 0000000000 SBNA FIL CU 6047505 O0 000 O0 0 1 1 1 4 68 0000000000 SFNA FIL CU 6047505 O0 000 O0 0 1 1 1 4 68 0000000000 SBFA FIL CU 6047505 O0 000 O0 0 1 1 1 4 68 0000000000 SFFA FIL CU 6047505 O0 000 O0 0 1 1 1 4 68 0000000000 TRAT FIL 6047505 O0 000 O0 0 1 1 1 4 68 0000000000 IRAT FIL 6047505 O0 000 O0 0 1 1 1 4 68 0000000000 CIRNFIL 6047505 O0 000 O0 0 1 1 1 4 68 0000000000 CIRF FIL 6047505 O0 000 O0 0 1 1 1 4 68 0000000000 BSALRST PPK 6047505 O0 000 O0 0 1 1 1 4 68 0000000000 SIBF RST CU 6047505 O0 000 O0 0 1 1 1 4 68 0000000000 TPHI RST PU-S 6047505 O0 000 O0 0 1 1 1 4 68 0000000000 SFFC RST CU 6047505 O0 000 O0 0 1 1 1 4 68 0000000000 SFNC RST CU 6047505 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-0CT-1998 16:31 PAGE: 5 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) SIGM RST CU 6047505 O0 000 O0 0 1 1 1 DSIG RST CU 6047505 O0 000 O0 0 1 1 1 FBEF RST UA 6047505 O0 000 O0 0 1 1 1 CRRARST 6047505 O0 000 O0 0 1 1 1 GRCH RST GAPI 6047505 O0 000 O0 0 1 1 1 TENS RST LB 6047505 O0 000 O0 0 1 1 1 CCL RST V 6047505 O0 000 O0 0 1 1 1 GR SDN GAPI 6047505 O0 000 O0 0 1 1 1 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 ** DATA ** DEPT. 9775.000 NBAC. RST -999 250 FBAC. RST -999.250 SBNA.FIL -999.250 SFNA.FIL -999.250 SBFA.FIL -999 250 SFFA.FIL -999.250 TRAT. FIL -999.250 IRAT. FIL -999.250 CIRN. FIL -999 250 CIRF. FIL -999.250 BSAL.RST -999.250 SIBF. RST -999.250 TPHI.RST -999 250 SFFC. RST -999.250 SFNC.RST -999.250 SIGM. RST -999.250 DSIG.RST -999 250 FBEF. RST -999.250 CRRA.RST -999.250 GRCH. RST -999.250 TENS.RST -999 250 CCL.RST -999.250 GR.SDN 22.214 DEPT. 9440.000 NBAC. RST -999.250 FBAC.RST -999 250 SBNA.FIL -999.250 SFNA.FIL -999.250 SBFA.FIL -999.250 SFFA.FIL -999 250 TRAT. FIL -999.250 IRAT. FIL -999.250 CIRN. FIL -999.250 CIRF. FIL -999 250 BSAL.RST -999.250 SIBF. RST -999.250 TPHI.RST -999.250 SFFC.RST -999 250 SFNC. RST -999.250 SIGM. RST -999.250 DSIG.RST -999.250 FBEF. RST -999 250 CRRA.RST -999.250 GRCH. RST -999.250 TENS.RST -999.250 CCL.RST -999 250 GR.SDN 97.560 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-0CT-1998 16:31 PAGE: FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: O. 5000 FILE SUF~VIARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9739.5 9468.0 RST 9753.0 9468.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 9741.5 9739.5 9733.0 9721.5 9721.0 9720.0 9717.0 9715.5 9714.5 9713.0 9704.0 9702.5 9701.0 9700.0 9698.0 9696.5 9695.5 9692.5 9687.5 9685.5 9684.0 9680.5 9676.0 9674.5 9668.0 9666.5 9659.0 9656.5 9651.5 9649.5 9647.5 9642.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST 88888.5 88891.0 9721.5 9718.0 9716.0 9703.0 9700.0 9697.5 9689.0 9686.0 9684.5 9676.0 9668.5 9658.0 9653.0 9648.5 9642.0 9744.5 9742.0 9734.5 9723.0 9721.0 9717.5 9715.5 9706.0 9702.5 9700.5 9697.0 9695.0 9686.5 9682.5 9678.0 9668.5 9660.5 9658.0 9651.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-0CT-1998 16:31 PAGE: 9639.0 9638.5 9641.5 9635.0 9634.5 9633.0 9632.5 9628.0 9630.5 9624 . 5 9623.5 9620.5 9619.5 9618.0 9617.0 9613.0 9615.5 9611.5 9610.0 9610.0 9612.0 9604.0 9602.5 9600.5 9599.0 9597.5 9601.5 9594.5 9595.5 9591.5 9592.0 9595.5 9590.0 9593.5 9589.0 9589.5 9586.5 9589.0 9584.0 9585.0 9582.5 9583.0 9585.0 9577.0 9576.5 9576.0 9576.5 9571.5 9571.5 9566.5 9568.0 9566.0 9566.0 9564.5 9565.5 9561.5 9561.5 9560.0 9561 . 0 9558.0 9557.5 9556.0 9557.5 9553.5 9554.0 9543.0 9543.5 9539.0 9538.5 9537.0 9539.0 9535.5 9536.5 9529.0 9529.0 9520.0 9518.5 9517.5 9517.5 9514.0 9513.5 9508.5 9507.0 9502.5 9502.5 9493.0 9494.0 9486.5 9486.0 9481.5 9481.5 100.0 100.0 100.0 $ REMARKS: THIS FILE CONTAINS CASED HOLE RST BASE PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #2 AND GRCH BASE PASS #1, ALSO SIGMA BASE PASS #2 AND SIGMA BASE PASS #1, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 24~0CT-i998 16:31 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 i1 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 6047505 O0 000 O0 0 2 1 1 4 68 0000000000 NBAC RST CPS 6047505 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC RST CPS 6047505 O0 000 O0 0 2 1 1 4 68 0000000000 SBNA FIL CU 6047505 O0 000 O0 0 2 1 1 4 68 0000000000 SFNA FIL CU 6047505 O0 000 O0 0 2 1 1 4 68 0000000000 SBFA FIL CU 6047505 O0 000 O0 0 2 1 1 4 68 0000000000 SFFA FIL CU 6047505 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT FIL 6047505 O0 000 O0 0 2 1 1 4 68 0000000000 IRAT FIL 6047505 O0 000 O0 0 2 1 1 4 68 0000000000 CIRNFIL 6047505 O0 000 O0 0 2 1 1 4 68 0000000000 CIRF FIL 6047505 O0 000 O0 0 2 1 1 4 68 0000000000 BSALRST PPK 6047505 O0 000 O0 0 2 1 1 4 68 0000000000 SIBF RST CU 6047505 O0 000 O0 0 2 1 1 4 68 0000000000 TPHI RST PU-S 6047505 O0 000 O0 0 2 1 1 4 68 0000000000 SFFC RST CU 6047505 O0 000 O0 0 2 1 1 4 68 0000000000 SFNC RST CU 6047505 O0 000 O0 0 2 1 1 4 68 0000000000 SIGM RST CU 6047505 O0 000 O0 0 2 1 1 4 68 0000000000 DSIG RST CU 6047505 O0 000 O0 0 2 1 1 4 68 0000000000 FBEF RST UA 6047505 O0 000 O0 0 2 1 1 4 68 0000000000 CRRARST 6047505 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH RST GAPI 6047505 O0 000 O0 0 2 1 1 4 68 0000000000 TENS RST LB 6047505 O0 000 O0 0 2 1 1 4 68 0000000000 CCL RST V 6047505 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-0CT-1998 16:31 PAGE: ** DATA ** DEPT. 9753. 000 NBAC.RST 2546. 854 FBAC.RST 4857. 882 SBNA. FIL SFNA.FIL 30.604 SBFA.FIL 43.371 SFFA.FIL 27.018 TRAT. FIL IRAT. FIL O. 435 CIRN. FIL O. 636 CIRF. FIL 1 . 475 BSAL. RST SIBF. RST 18. 675 TPHI.RST 19. 398 SFFC.RST 26. 144 SFNC.RST SIGM. RST 24. 788 DSIG.RST O. 839 FBEF. RST 58. 513 CRRA.RST GRCH. RST -999.250 TENS.RST 1240. 000 CCL.RST O. 007 DEPT. 9468.000 NBAC. RST 2080.677 FBAC.RST 3573.084 SBNA.FIL SFNA.FIL 35.038 SBFA.FIL 56.238 SFFA.FIL 38.876 TRAT. FIL IRAT. FIL 0.490 CIRN. FIL 0.561 CIRF. FIL 0.757 BSAL.RST SIBF. RST 43.275 TPHI.RST 52.383 SFFC.RST 35.389 SFNC.RST SIGM. RST 35.352 DSIG.RST -1.982 FBEF.RST 56.496 CRRA.RST GRCH.RST 64.048 TENS.RST 1203.000 CCL.RST 0.094 47. 755 O. 975 -10.285 29.235 2. 165 60.550 1.494 59.597 32.567 1.999 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION · O01CO1 DATE : 98/10/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE · FLIC VERSION · O01CO1 DATE : 98/10/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-0CT-1998 16:31 PAGE: 10 GRCH 9740.0 9473.0 RST 9753.0 9471 . 5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 9739.0 9727.5 9723.5 9717.0 9715.5 9712.5 971 O. 5 9710.0 9703.5 9702.0 9700.5 9699.5 9697 0 9693 5 9693 0 9685 0 9683 5 9681 0 9679 0 9676.5 9667.0 9666.5 9663.5 9660.0 9656.0 9650.5 9647.0 9644.0 9640.5 9639.0 9638.5 9634.5 9632.5 963 O. 5 9626.0 9624.0 9621.5 9621.0 9616.5 961 O. 5 9609.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST 88889.0 88891 . 0 9718.0 9711.5 9703.0 9700.0 9695.5 9686.0 9677.0 9668.5 9661.5 9652.5 9648.0 9644.0 9640.5 9638.5 9634.5 9632.5 9625.5 9623.5 9620.0 9615.5 9610.0 9742.0 9730.0 9725.5 9717.5 9715.5 9713.0 9706.0 9702.5 9699.5 9695.0 9686.5 9683.0 9681.0 9678.5 9668.5 9665.5 9658.0 9642.0 9633.0 9624.5 9615.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-0CT-1998 16:31 PAGE: 11 9603.5 9602.5 9600.5 9599.0 9597.5 9601.5 9594.5 9595.5 9590.5 9592.0 9589.0 9593.5 9586.5 9590.0 9579.0 9581.0 9577.0 9576.0 9571.5 9571.5 9572.5 9565.5 9565.5 9568.0 9563.5 9565.5 9559.5 9562.0 9558.0 9558.0 9555.5 9557.5 9552.5 9554.0 9551.5 9550.5 9543.0 9541.5 9538.5 9538.5 9536.5 9536.5 9539.0 9535.0 9536.5 9534.5 9535.0 9528.5 9529.0 9502.0 9502.5 9503.0 9490.0 9491.0 9480.5 9480.0 100.0 101.0 99.5 $ REMARKS: THIS FILE CONTAINS CASED HOLE RST BASE PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #3 AND GRCH BASE PASS #1, ALSO SIGMA BASE PASS #3 AND SIGMA BASE PASS #1, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 O. 5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-0CT-1998 16:31 PAGE: 12 TYPE REPR CODE VALUE 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) FT 6047505 O0 000 O0 0 3 1 1 4 68 0000000000 DEPT NBAC RST CPS 6047505 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC RST CPS 6047505 O0 000 O0 0 3 1 1 4 68 0000000000 SBNA FIL CU 6047505 O0 000 O0 0 3 1 1 4 68 0000000000 SFNA FIL CU 6047505 O0 000 O0 0 3 1 1 4 68 0000000000 SBFA FIL CU 6047505 O0 000 O0 0 3 1 1 4 68 0000000000 SFFA FIL CU 6047505 O0 000 O0 0 3 1 1 4 68 0000000000 TRAT FIL 6047505 O0 000 O0 0 3 1 1 4 68 0000000000 IRAT FIL 6047505 O0 000 O0 0 3 1 1 4 68 0000000000 CIRNFIL 6047505 O0 000 O0 0 3 1 1 4 68 0000000000 CIRF FIL 6047505 O0 000 O0 0 3 1 1 4 68 0000000000 BSALRST PPK 6047505 O0 000 O0 0 3 1 1 4 68 0000000000 SIBF RST CU 6047505 O0 000 O0 0 3 1 1 4 68 0000000000 TPHI RST PU-S 6047505 O0 000 O0 0 3 1 1 4 68 0000000000 SFFC RST CU 6047505 O0 000 O0 0 3 1 1 4 68 0000000000 SFNC RST CU 6047505 O0 000 O0 0 3 1 1 4 68 0000000000 SIGM RST CU 6047505 O0 000 O0 0 3 1 1 4 68 0000000000 DSIG RST CU 6047505 O0 000 O0 0 3 1 1 4 68 0000000000 FBEF RST UA 6047505 O0 000 O0 0 3 1 1 4 68 0000000000 CRRARST 6047505 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH RST GAPI 6047505 O0 000 O0 0 3 1 1 4 68 0000000000 TENS RST LB 6047505 O0 000 O0 0 3 1 1 4 68 0000000000 CCL RST V 6047505 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 9753.000 NBAC. RST 2400.902 FBAC.RST 4172.104 SBNA.FIL SFNA.FIL 28.228 SBFA.FIL 37.256 SFFA.FIL 23.169 TRAT. FIL IRAT. FIL 0.431 CIRN. FIL 0.752 CIRF. FIL 1.988 BSAL.RST SIBF. RST 22.374 TPHI.RST 17.084 SFFC. RST 21.473 SFNC. RST SIGM. RST 20.956 DSIG.RST 1.317 FBEF. RST 58.936 CRRA.RST GRCH. RST -999.250 TENS.RST 1259.000 CCL.RST -0.013 48.128 0.909 0.633 25.224 2.215 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-0CT-1998 16:31 PAGE: 13 DEPT. 9471.500 NBAC.RST SFNA.FIL 36.010 SBFA.FIL IRAT. FIL 0.486 CIRN. FIL SIBF. RST 44.072 TPHI.RST SIGM. RST 34.291 DSIG.RST GRCH. RST -999.250 TENS.RST 2168.449 FBAC.RST 55.442 SFFA.FIL 0.567 CIRF. FIL 52.265 SFFC.RST -2.055 FBEF. RST 1219.000 CCL.RST 3494.571 SBNA.FIL 37.830 TRAT. FIL 0.791 BSAL.RST 34.236 SFNC.RST 56.627 CRRA.RST -0.015 64. 506 1. 483 61. 764 33. 617 2. 008 ** EArD OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE . 98/10/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE . 98/10/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUMBER: 4 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT O. 5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS 1, 2, 3, RST $ RE~iARKS: THIS FILE CONTAINS THE ARITHMETIC AVERAGE OF BASE PASSES 1,2, & 3. THE DATA WAS CLIPPED AND DEPTH SHIFTED BEFORE THE AVERAGE WAS CALCULATED. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-0CT-1998 16:31 PAGE: 14 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 84 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 6047505 O0 000 O0 0 4 1 1 4 68 0000000000 NBAC RST CPS 6047505 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC RST CPS 6047505 O0 000 O0 0 4 1 1 4 68 0000000000 SBNA RSAV CU 6047505 O0 000 O0 0 4 1 I 4 68 0000000000 SFNA RSAV CU 6047505 O0 000 O0 0 4 1 1 4 68 0000000000 SBFA RSAV CU 6047505 O0 000 O0 0 4 1 1 4 68 0000000000 SFFA RSAV CU 6047505 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT RSAV 6047505 O0 000 O0 0 4 1 1 4 68 0000000000 IRAT RSAV 6047505 O0 000 O0 0 4 1 1 4 68 0000000000 CIRNRSAV 6047505 O0 000 O0 0 4 1 1 4 68 0000000000 CIRF RSAV 6047505 O0 000 O0 0 4 1 1 4 68 0000000000 BSALRSAV PPK 6047505 O0 000 O0 0 4 1 1 4 68 0000000000 SIBF RSAV CU 6047505 O0 000 O0 0 4 1 i 4 68 0000000000 TPHI RSAV PU-S 6047505 O0 000 O0 0 4 1 1 4 68 0000000000 SFFC RSAV CU 6047505 O0 000 O0 0 4 1 1 4 68 0000000000 SFNC RSAV CU 6047505 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM RSAV CU 6047505 O0 000 O0 0 4 1 i 4 68 0000000000 DSIG RSAV CU 6047505 O0 000 O0 0 4 1 1 4 68 0000000000 FBEF RSAV UA 6047505 O0 000 O0 0 4 1 1 4 68 0000000000 CRRARSAV 6047505 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH RST GAPI 6047505 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-0CT-1998 16:31 PAGE: 15 ** DATA ** DEPT. 9752.500 NBAC.RST 2133. 053 FBAC.RST SFNA. RSAV 29. 376 SBFA. RSAV 41 . 221 SFFA. RSAV IRAT. RSAV O. 432 CIRN. RSAV O. 707 CIRF. RSAV SIBF. RSAV 20.260 TPHI.RSAV 17.571 SFFC.RSAV SIGM. RSAV 24. 219 DSIG. RSAV O. 901 FBEF. RSAV GRCH. RST - 999 . 250 DEPT. 9467. 500 NBAC. RST -999. 250 FBAC. RST SFNA. RSAV -999. 250 SBFA. RSAV -999 . 250 SFFA. RSAV IRAT. RSAV - 999 . 250 CIRN. RSAV - 999 . 250 CIRF. RSAV SIBF. RSAV - 999. 250 TPHI. RSAV - 999. 250 SFFC. RSAV SIGM. RSAV -999. 250 DSIG. RSAV -999. 250 FBEF. RSAV GRCH. RST 46. 441 4189. 493 SBNA. RSAV 26. 401 TRAT. RSAV 1 . 624 BSAL. RSAV 25.267 SFNC. RSAV 58.376 CRRA. RSAV - 999. 250 SBNA. RSAV - 999. 250 TRAT. RSAV -999.250 BSAL.RSAV -999. 250 SFNC. RSAV - 999. 250 CRRA. RSAV 49. 020 O. 941 -5.594 27.006 2.183 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/24' MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMFiARY VENDOR TOOL CODE START DEPTH STOP DEPTH RST 9778.0 9416.5 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-0CT-1998 16:31 PAGE: 16 LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 08-0CT-98 8Cl-205 1855 08-0CT-98 9770.0 9766.0 9468.0 9750.0 3600.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GA~k~A RAY RST RESERVOIR SATURATION $ TOOL NUMBER ........... CGRS-A RST-A BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.500 10009.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : CRUDE NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUN~f RATE HIGH SCALE (CPS)'. 6 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN): REMARKS: CORRELATED TO CET DATED 10/31/88 PUMPED 234 BBLS CRUDE INTO TUBING LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-0CT-1998 16:31 PAGE: 17 THEN MADE 3 RST PASSES AT 60 FPMWHILE PUMPING AT 2 BPM. THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 3 68 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 CS PS1F/HR 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 TENS PSI LB 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 NPHVPS1 V 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 NPDE PS1 V 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 NSCE PS1 V 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 CRRA PS1 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 NSCR PS1 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 AQTMPS1 S 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 CHV PSi V 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 CPSV PS1 V 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 CP2V PSi V 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 C~2V PS1 V 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 RCFR PS1 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 RCLC PS1 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 RCRC PS1 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-0CT-1998 16:31 PAGE: 18 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) RCAKPS1 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 RTDF PS1 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 FPHVPS1 V 6047505 O0 000 O0 0 5 1 i 4 68 0000000000 FPDE PS1 V 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 FSCE PS1 V 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 FSCR PS1 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 AQTF PS1 S 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 SF6P PS1 PSIG 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 HVPV PS1 V 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 BMCU PS1 UA 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 GDCU PS1 MA 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 EXCU PS1 UA 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 NBEF PS1 UA 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 FBEF PS1 UA 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 NPGF PS1 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 FPGF PSI 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 BSTR PS1 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 BSPR PS1 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 MARC PS1 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 XHV PS1 V 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 XPSV PS1 V 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 XP2V PS1 V 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 X~2V PS1 V 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 RXFR PS1 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 RXLC PS1 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 RXRC PS1 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 RXAKPS1 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 SHCU PS1 MA 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 BSAL PS1 PPK 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 BSAL SIG PPK 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 CIRNPS1 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 CIRF PS1 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 CIRNFIL 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 CIRF FIL 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 DSIG PS1 CU 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC PS1 CPS 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 IRAT PS1 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 IRAT FIL 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 NBAC PS1 CPS 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 SFNA PS1 CU 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 SFFA PS1 CU 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 SBNA PS1 CU 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 SBFA PS1 CU 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 SFNA SIG CU 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 SFFA SIG CU 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 SBNA SIG CU 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 SBFA SIG CU 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 SFNA FIL CU 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 SFFA FIL CU 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 SBNA FIL CU 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 SBFA FIL CU 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-0CTo1998 16:31 PAGE: 19 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) SIBF PS1 CU 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 SFNC PS1 CU 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 SFFC PS1 CU 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM PS1 CU 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 SIBF SIG CU 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM SIG CU 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT PS1 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT SIG 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT FIL 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 GR PS1 GAPI 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 RDIX PS1 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 CRNI PSi KHZ 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 CRFI PS1 KHZ 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 CTM PSi DEGC 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 XTM PS1 DEGC 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 TAV PS1 KV 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 FICU PS1 AMP 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 CACU PS1 AMP 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 BUST PS1 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 BUSP PS1 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 RSXS PS1 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI PS1 PU 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI SIG PU 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 CCLC PS1 V 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 RSCS PS1 6047505 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 9775.000 CS.PS1 2450.388 TENS. PSi 1013.000 NPHV. PS1 NPDE. PS1 1475.145 NSCE. PS1 2.307 CRRA.PS1 2.231 NSCR.PS1 AQTM. PS1 0.661 CHV. PS1 203.035 CPSV. PS1 5.069 CP2V. PS1 CM2V. PS1 -12.093 RCFR.PS1 0.000 RCLC. PS1 0.000 RCRC. PS1 RCAK. PS1 0.000 RTDF. PS1 0.000 FPHV. PS1 1540.529 FPDE. PS1 FSCE. PS1 1.878 FSCR.PS1 -0.117 AQTF. PS1 0.661 SF6P. PS1 HVPV. PS1 163.086 BMCU. PS1 31.347 GDCU. PS1 61.323 EXCU. PS1 NBEF. PS1 26.398 FBEF. PS1 58.888 NPGF. PS1 1.011 FPGF. PS1 BSTR.PS1 54.214 BSPR.PS1 1.114 MARC. PSi 0.000 XHV. PS1 XPSV. PS1 5.079 XP2V. PS1 12.188 X~2V. PS1 -12.368 RXFR.PS1 RXLC. PS1 0.000 RXRC. PS1 0.000 RXAK. PS1 0.000 SHCU. PS1 BSAL.PS1 -999.250 BSAL.SIG -999.250 CIRN. PS1 -999.250 CIRF. PS1 CIRN. FIL -999.250 CIRF. FIL -999.250 DSIG. PS1 -999.250 FBAC. PS1 IRAT. PS1 -999.250 IRAT. FIL -999.250 NBAC. PS1 -999.250 SFNA.PS1 SFFA.PSi -999.250 SBNA.PS1 -999.250 SBFA.PS1 -999.250 SFNA.SIG SFFA.SIG -999.250 SBNA.SIG -999.250 SBFA.SIG -999.250 SFNA.FIL SFFA.FIL -999.250 SBNA.FIL -999.250 SBFA.FIL -999.250 SIBF. PS1 SFNC. PS1 -999.250 SFFC. PS1 -999.250 SIGM. PS1 -999.250 SIBF. SIG SIGM. SIG -999.250 TRAT. PS1 -999.250 TRAT. SIG -999.250 TRAT. FIL GR.PS1 262.444 RDIX. PS1 85149.000 CRNI.PS1 450.721 CRFI.PS1 CTM. PS1 105.469 XTM. PS1 104.981 TAV. PS1 94.888 FICU. PS1 1511.231 0.235 12.041 0.000 1507.951 158.261 4.734 0.996 200.370 0.000 45.528 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 202.045 2.314 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-0CT-1998 16:31 PAGE: 20 CACU. PSl 2. 485 BUST. PS1 TPHI.PS1 -999.250 TPHI.SIG DEPT. 9440. 000 CS. PS1 NPDE. PS1 1473. 771 NSCE. PS1 AQTM. PS1 O . 661 CHV. PS1 CM2V. PS1 -12. 152 RCFR. PS1 RCAK. PS1 O. 000 RTDF. PSI FSCE. PS1 1 . 642 FSCR. PS1 HVPV. PS1 163 . 696 BMCU. PS1 NBEF. PS1 27.818 FBEF. PS1 BSTR. PS1 103. 263 BSPR. PS1 XP5V. PS1 5.074 XP2V. PS1 RXLC. PS1 O. 000 RXRC. PS1 BSAL. PS1 58.377 BSAL. SIG CIRN. FIL O. 565 CIRF. FIL IRAT. PS1 O. 482 IRAT. FIL SFFA. PS1 3 6. 043 SBNA. PS1 SFFA. SIG 1 . 324 SBNA. SIG SFFA. FIL 36.319 SBNA. FIL SFNC. PS1 32. 632 SFFC. PS1 SIGM. SIG 0 . 988 TRAT. PS1 GR.PS1 47.845 RDIX. PS1 CTM. PS1 104. 981 XTM. PS1 CACU. PS1 2. 500 BUST. PS1 TPHI.PS1 52.123 TPHI.SIG 3.000 BUSP. PS1 -999.250 CCLC. PS1 3 665.863 TENS. PS1 2.136 CRRA. PS1 202. 308 CPSV. PS1 O. 000 RCLC. PS1 0.000 FPHV. PS1 -0.109 AQTF. PS1 32.263 GDCU. PS1 56.231 NPGF. PS1 1.230 MARC. PSi 12.175 XM2V. PS1 0.000 RXAK. PS1 3.219 CIRN. PS1 0.801 DSIG.PS1 0.480 NBAC. PS1 53.220 SBFA.PS1 3.950 SBFA.SIG 55.788 SBFA.FIL 32.667 SIGM. PS1 1.460 TRAT. SIG 90071.000 CRNI.PS1 104.981 TAV. PS1 3.000 BUSP. PS1 2.322 CCLC. PS1 3.000 0.000 1216.000 2.021 5.069 0.000 1542.970 0.661 59.602 0.999 0.000 -12.343 0.000 0.561 -0.985 1987.108 58.992 5.475 56.459 32.773 0.047 446.872 94.996 3.000 -0.539 RSXS.PS1 RSCS. PS1 NPHV. PS1 NSCR. PS1 CP2 V. PS1 RCRC. PS1 FPDE. PSl SF6P. PS1 EXCU. PS1 FPGF. PSI XHV. PS1 RXFR . PS1 SHCU. PS1 CIRF. PS1 FBAC. PS1 SFNA. PS1 SFNA. SIG SFNA. FIL SIBF. PS1 SIBF. SIG TRA T. FIL CRFI. PS1 FICU. PS1 RSXS. PS1 RSCS. PS1 8878.000 8459.000 1503.907 -0.376 11.997 0.000 1506.425 159.028 4.932 1.002 200.582 0.000 47.519 0.813 3303.077 35.549 1.019 35.092 42.827 1.181 1.470 221.072 2.275 8878.0OO 8459.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-0CT-1998 16:31 PAGE: 21 FILE NUMBER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH RST 9779.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): STOP DEPTH 9418.0 08-0CT-98 8Cl-205 1855 08-0CT-98 9770.0 9766.0 9468.0 9750.0 3600.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~A RAY RST RESERVOIR SATURATION $ TOOL NUMBER CGRS-A RST-A BOREHOLE AN~ CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.500 10009.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : CRUDE NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-0CT-1998 16:31 PAGE: 22 BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 6 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN): REMARKS: CORRELATED TO CET DATED 10/31/88 PUMPED 234 BBLS CRUDE INTO TUBING THEN MADE 3 RST PASSES AT 60 FPM WHILE PUMPING AT 2 BPM. THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 CS PS2 F/HR 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS2 LB 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 NPHVPS2 V 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 NPDE PS2 V 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-0CT-1998 16:31 PAGE: 23 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) NSCE PS2 V 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 CRRA PS2 6047505 O0 000 O0 0 6 I 1 4 68 0000000000 NSCR PS2 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 AQTMPS2 S 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 CHV PS2 V 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 CPSV PS2 V 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 CP2V PS2 V 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 CM2V PS2 V 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 RCFR PS2 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 RCLC PS2 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 RCRC PS2 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 RCAKPS2 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 RTDF PS2 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 FPHVPS2 V 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 FPDE PS2 V 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 FSCE PS2 V 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 FSCR PS2 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 AQTF PS2 S 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 SF6P PS2 PSIG 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 HVPV PS2 V 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 BMCU PS2 UA 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 GDCU PS2 MA 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 EXCU PS2 UA 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 NBEF PS2 UA 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 FBEF PS2 UA 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 NPGF PS2 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 FPGF PS2 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 BSTR PS2 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 BSPR PS2 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 MARC PS2 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 XHV PS2 V 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 XPSV PS2 V 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 XP2V PS2 V 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 X~2V PS2 V 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 RXFR PS2 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 RXLC PS2 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 RXRC PS2 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 ~PS2 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 SHCU PS2 MA 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 BSAL PS2 PPK 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 BSAL SIG PPK 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 CIRNPS2 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 CIRF PS2 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 CIRNFIL 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 CIRF FIL 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 DSIG PS2 CU 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 FBAC PS2 CPS 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 IRAT PS2 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 IRAT FIL 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 NBAC PS2 CPS 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 SFNA PS2 CU 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-0CT-1998 16:31 PAGE: 24 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CI.~SS MOD NrJMB Sglx!P ELTO4 CODE (HEX) SFFA PS2 CU 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 SBNA PS2 CU 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 SBFA PS2 CU 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 SFNA SIG CU 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 SFFA SIG CU 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 SBNA SIG CU 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 SBFA SIG CU 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 SFNA FIL CU 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 SFFA FIL CU 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 SBNA FIL CU 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 SBFA FIL CU 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 SIBF PS2 CU 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 SFNC PS2 CU 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 SFFC PS2 CU 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM PS2 CU 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 SIBF SIG CU 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM SIG CU 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT PS2 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT SIG 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT FIL 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS2 GAPI 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 RDIX PS2 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 CRNI PS2 KHZ 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 CRFI PS2 KHZ 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 CTM PS2 DEGC 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 XTM PS2 DEGC 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 TAV PS2 KV 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 FICU PS2 AMP 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 CACU PS2 AMP 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 BUST PS2 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 BUSP PS2 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 RSXS PS2 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI PS2 PU 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI SIG PU 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 CCLC PS2 V 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 RSCS PS2 6047505 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 9775.000 CS. PS2 4398.821 TENS.PS2 973.000 NPHV. PS2 NPDE. PS2 1471.063 NSCE. PS2 2.199 CRRA.PS2 2.185 NSCR.PS2 AQTM. PS2 0.661 CHV. PS2 202.792 CPSV. PS2 5.079 CP2V. PS2 CM2V. PS2 -12.113 RCFR.PS2 0.000 RCLC. PS2 0.000 RCRC. PS2 RCAK. PS2 0.000 RTDF. PS2 0.000 FPHV. PS2 1550.294 FPDE. PS2 FSCE. PS2 1.715 FSCR.PS2 0.070 AQTF. PS2 0.661 SF6P. PS2 HVPV. PS2 163.574 BMCU. PS2 30.761 GDCU. PS2 60.012 EXCU. PS2 NBEF. PS2 26.801 FBEF. PS2 58.565 NPGF. PS2 1.008 FPGF. PS2 BSTR.PS2 50.315 BSPR.PS2 1.130 MARC. PS2 0.000 XHV. PS2 XPSV. PS2 5.079 XP2V. PS2 12.188 XM2V. PS2 -12.328 RXFR.PS2 1516.114 -0.040 12.085 0.000 1506.997 160.052 5.129 O. 996 200. 612 0.000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-0CT-1998 16:31 PAGE: 25 RXLC. PS2 0.000 RXRC. PS2 BSAL.PS2 -999.250 BSAL.SIG CIRN. FIL -999.250 CIRF. FIL IRAT. PS2 -999.250 IRAT. FIL SFFA.PS2 -999.250 SBNA.PS2 SFFA.SIG -999.250 SBNA.SIG SFFA.FIL -999.250 SBNA.FIL SFNC.PS2 -999.250 SFFC. PS2 SIGM. SIG -999.250 TRAT. PS2 GR . PS2 174 . 962 RDIX. PS2 CTM. PS2 105.469 XTM. PS2 CACU. PS2 2. 500 BUST. PS2 TPHI.PS2 -999.250 TPHI.SIG 0 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 92012 000 104 004 3 000 -999 250 RXAK. PS2 CIRN. PS2 DSIG.PS2 NBAC.PS2 SBFA.PS2 SBFA.SIG SBFA.FIL SIGM. PS2 TRAT. SIG CRNI.PS2 TAV. PS2 BUSP.PS2 CCLC. PS2 0.000 SHCU. PS2 -999.250 CIRF. PS2 -999.250 FBAC. PS2 -999.250 SFNA.PS2 -999.250 SFNA.SIG -999.250 SFNA.FIL -999.250 SIBF. PS2 -999.250 SIBF. SIG -999.250 TRAT. FIL 448.199 CRFI.PS2 95.175 FICU. PS2 3.000 RSXS. PS2 -0.004 RSCS.PS2 46.503 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 205.113 2.207 8878.000 8463.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: O. 5000 FILE SUAgAARY VENDOR TOOL CODE START DEPTH STOP DEPTH RST 9779.5 9420.5 $ LOG HEADER DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-0CT-1998 16:31 PAGE: 26 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 08-0CT-98 8Cl -205 1855 08-0CT-98 9770.0 9766.0 9468.0 9750.0 3600.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY RST RESERVOIR SATURATION $ TOOL NUMBER CGRS-A RST-A BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.500 10009.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : CRUDE NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 6 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN): REMARKS: CORRELATED TO CET DATED 10/31/88 PUMPED 234 BBLS CRUDE INTO TUBING THEN MADE 3 RST PASSES AT 60 FPM WHILE PUMPING AT 2 BPM. LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-0CT-1998 16:31 PAGE: 27 THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #3. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 CS PS3 F/HR 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS3 LB 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 NPHVPS3 V 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 NPDE PS3 V 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 NSCE PS3 V 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 CRRA PS3 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 NSCR PS3 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 AQTMPS3 S 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 CHV PS3 V 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 CPSV PS3 V 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 CP2V PS3 V 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 CM2V PS3 V 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 RCFR PS3 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 RCLC PS3 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 RCRC PS3 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 RCAKPS3 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 RTDF PS3 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-0CT-1998 16:31 PAGE: 28 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE C~SS MOD NUMB SAMP ELE~ CODE (HEX) FPHVPS3 V 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 FPDE PS3 V 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 FSCE PS3 V 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 FSCR PS3 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 AQTF PS3 S 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 SF6P PS3 PSIG 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 HVPV PS3 V 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 BMCU PS3 UA 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 GDCU PS3 MA 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 EXCU PS3 UA 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 NBEF PS3 UA 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 FBEF PS3 UA 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 NPGF PS3 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 FPGF PS3 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 BSTR PS3 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 BSPR PS3 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 MARC PS3 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 XHV PS3 V 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 XPSV PS3 V 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 XP2V PS3 V 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 ~2V PS3 V 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 RXFR PS3 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 RXLC PS3 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 RXRC PS3 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 RXAKPS3 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 SHCU PS3 MA 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 BSAL PS3 PPK 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 BSAL SIG PPK 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 CIRNPS3 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 CIRF PS3 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 CIRNFIL 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 CIRF FIL 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 DSIG PS3 CU 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 FBAC PS3 CPS 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 IRAT PS3 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 IRAT FIL 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 NBAC PS3 CPS 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 SFNA PS3 CU 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 SFFA PS3 CU 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 SBNA PS3 CU 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 SBFA PS3 CU 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 SFNA SIG CU 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 SFFA SIG CU 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 SBNA SIG CU 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 SBFA SIG CU 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 SFNA FIL CU 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 SFFA FIL CU 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 SBNA FIL CU 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 SBFA FIL CU 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 SIBF PS3 CU 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 SFNC PS3 CU 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-0CT-1998 16:31 PAGE: 29 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CI.~SS MOD NUMB S~P EL~Vl CODE (HEX) SFFC PS3 CU 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM PS3 CU 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 SIBF SIG CU 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM SIG CU 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT PS3 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT SIG 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT FIL 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS3 GAPI 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 RDIX PS3 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 CRNI PS3 KHZ 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 CRFI PS3 KHZ 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 CTM PS3 DEGC 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 XTM PS3 DEGC 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 TAV PS3 KV 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 FICU PS3 AMP 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 CACU PS3 AMP 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 BUST PS3 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 BUSP PS3 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 RSXS PS3 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI PS3 PU 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI SIG PU 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 CCLC PS3 V 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 RSCS PS3 6047505 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 9775.000 CS.PS3 3345.723 TENS.PS3 997.000 NPHV. PS3 NPDE. PS3 1473.733 NSCE. PS3 2.230 CRRA.PS3 2.267 NSCR.PS3 AQTM. PS3 0.661 CHV. PS3 202.792 CPSV. PS3 5.069 CP2V. PS3 CM2V. PS3 -12.093 RCFR.PS3 0.000 RCLC. PS3 0.000 RCRC. PS3 RCAK. PS3 0.000 RTDF. PS3 0.000 FPHV. PS3 1545.411 FPDE. PS3 FSCE. PS3 1.716 FSCR.PS3 -0.206 AQTF. PS3 0.661 SF6P. PS3 HVPV. PS3 163.574 BMCU. PS3 31.640 GDCU. PS3 60.012 EXCU. PS3 NBEF. PS3 26.723 FBEF. PS3 60.573 NPGF. PS3 1.000 FPGF. PS3 BSTR.PS3 53.437 BSPR.PS3 1.047 MARC. PS3 0.000 XHV. PS3 XP5V. PS3 5.069 XP2V. PS3 12.158 XM2V. PS3 -12.368 RXFR.PS3 RXLC. PS3 0.000 RXRC. PS3 0.000 RXAK. PS3 0.000 SHCU. PS3 BSAL.PS3 -999.250 BSAL.SIG -999.250 CIRN. PS3 -999.250 CIRF. PS3 CIRN. FIL -999.250 CIRF. FIL -999.250 DSIG.PS3 -999.250 FBAC. PS3 IRAT. PS3 -999.250 IRAT. FIL -999.250 NBAC. PS3 -999.250 SFNA.PS3 SFFA.PS3 -999.250 SBNA.PS3 -999.250 SBFA.PS3 -999.250 SFNA.SIG SFFA.SIG -999.250 SBNA.SIG -999.250 SBFA.SIG -999.250 SFNA.FIL SFFA.FIL -999.250 SBNA.FIL -999.250 SBFA.FIL -999.250 SIBF. PS3 SFNC. PS3 -999.250 SFFC. PS3 -999.250 SIGM. PS3 -999.250 SIBF. SIG SIGM. SIG -999.250 TRAT. PS3 -999.250 TRAT. SIG -999.250 TRAT. FIL GR.PS3 114.398 RDIX. PS3 99069.000 CRNI.PS3 453.419 CRFI.PS3 CTM. PS3 105.957 XTM. PS3 104.492 TAV. PS3 94.888 FICU. PS3 CACU. PS3 2.485 BUST. PS3 3.000 BUSP. PS3 3.000 RSXS. PS3 TPHI.PS3 -999.250 TPHI.SIG -999.250 CCLC. PS3 0.010 RSCS. PS3 1506.349 0.429 12.026 0.000 1506.768 160.564 5.129 0.998 200.612 0.000 45.528 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 200.032 2.266 8878.000 8463.000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-0CT-1998 16:31 PAGE: 3O ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/10/24 ORIGIN : FLIC TAPE NAME : 98538 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA, DS 14-37, PRUDHOE BAY, API# 50-029-21810-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/10/24 ORIGIN : FLIC REEL NAME : 98538 CONTINUATION # : PREVIOUS REEL : CO~4MENT : ARCO ALASKA, DS 14-37, PRUDHOE BAY, API# 50-029-21810-00 ** REEL HEADER ** REEL NAME : DATE : ...... ORIGIN : FSYS SERVICE NAME: BITLIS REEL CONTINUATION NUMBER: 01 PREVIOUS REEL NAME : COMMENTS: DRESSER ATLAS LIS CUSTOMER TAPE --- CREATED BY SDS PROGRAM R 2.0 LENGTH: 132 BYTES ** TAPE HEADER ** TAPE NAME : DATE : ORIGIN : FSYS SERVICE NAME: OI/B-M TAPE CONTINUATION NUMBER: 01 PREVIOUS TAPE NAME : COMMENTS: LENGTH: 132 BYTES -- ** FILE HEADER # I ** FILE NAME: DI/B-M.001 SERVICE NAME: VERSION # : 1 DATE: 85/11/'20 MAX RECORD LENGTH: 1024 BYTES FILE TYPE: LO PREVIOUS FILE NAME: . ** INFORMATION R=CORDS~ ** MNEM CONTENTS APIN : 50-02g-21~10-00 CN : ARCO ALASKA, INC. WN : D.S. 14-37 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA LCC : 150.00 UNITS ** FORMAT ** ~NTRY BLOCKS TYPE ENTRY DESCRIPTION 8 9 11 0 I DEPTHS DECREASE 60.0 FRAME SPACING .lIN FRAME SPACING UNITS 19 MAXIMUM FRAMES/RECORD TERMINATOR -0.500 LEVEL SPACING DATUM SPECIFICATION BLOCKS CURVE NAME REPR CODE SIZE SAMPLE UNITS ' : · ' ' ' :' "~'~'" ~'i '' CURVE NAME REPR CODE SIZE SAMPLE UNITS -~" CILD 68 GR 68 T2R2 68 TlR2 68 AC 68 RILM 68 · - ** fORMAT ** 4 I 'MMHo SP 68 4 1 MV 4 I API CAL 68 4 I IN 4 I US T2R1 68 4 1 US 4 I US TlR1 68 4 1 US 4 I US/F RFOC 68 4 1 OHMM 4 1 OHMM RILD 68 4 1 OHMM ENTRY BLOCKS TYPE ENTRY 4 1 8 60.0 9 .lIN 11 19 0 -0.500 DESCRIPTION DEPTHS DECREASE FRAME SPACING FRAME SPACING UNITS MAXIMUM FRAMES/RECORD TERMINATOR LEVEL SPACING . DATUM SPECIF .L . ICATION BLOCKS i CURVE . REDR NAME CODE SIZE SAMPLE UNITS ILD 68 4 1 MMHO R '68 4 1 API 2R2 68 4 1 US 1R2 68 4 I US C 68 4 1 US/F ILM 68 4 I OHMM * DATA ** CURVE REPR NAME CODE SIZE SAMPLE SP 68 4 1 CAL 68 4 1 T2R1 68 4 1 TlR1 68 4 1 RFOC 68 4 1 RILO 68 4 I DEPTH 10014.000 FT 3052.2730 M . ~.~.. CILD 419.047 SP T2R2 630.250 T2R1 , . AC 44.152 RFOC -71.607 630.563 6.373 GR TlR2 RILM DEPTH 10000.000 FT 3048.0060 M CILD 419.681 SP T2R2 630.250 T2R1 AC 44.152 RFOC -71 .186 630.563 5.979 DEPTH 9900.000 FT 3017.5260 M i CILD 327.218 SP T2R2 445.000 TZR1 AC 79.520 RFOC -73.714 596.750 16.780 GR TlR2 RILM GR TlR2 RILM DEPTH 9800.000 FT 2987.0460 M CILD T2R2 AC DEPTH CILD T2R2 AC 162.540 SP 484.750 T2R1 92.877 RFOC -72.654 668.250 17.611 9700.000 FT 2956.5660 M 83.410 SP 463.000 T2R1 84.506 RFOC -48.358 627.188 25.232 GR TlR2 RILM GR TlR2 RILM .00 0 FT 2926.0860 M · . 24.964 630.125 3.034 24.964 630.125 3.032 22.385 601.063 3.596 23.823 671.750 7.294 25.327 629.000 14.053 CAL TlR1 RILD CAL TlR1 RILD CAL TlR1 RILD CAL TlR1 RILD CAL TlR1 RILD UNITS MV IN US US OHMM OHMM -2.00@ 453.813 2.386 -2.000 z, 53.813 2.383 -1 .993 447.313 3.056 -1.514 494.938 6.152 -0.531 465.063 11.989 CILD 224.846 SP -15.858 T2R2 331.000 T2R1 443.188 AC 56.066 RFOC 0.384 GR TlR2 RILM DEPTH 9550.500 FT 2910.9980 M CILD. 224.846 SP -15.858 T2R2 331.875 T2R1 443.563 dC 56.151 RFOC 0.384 GR TlR2 RILM STARTING DEPTH =10014.000 FT ENOING DEPTH = 9550.500 FT 3052.2730 M 2910.9980 M ** FILE TRAILER ** FILE NAME: DI/B-M.001 SERVICE NAME: VERSION # : 1 DATE: 85/11/ MAXIMUM LENGTH: 1024 FILE TYPE: LO NEXT FILE NAME: ** FILE HEADER # 2 ** FILE NAME: DI/B-R.O02 SERVICE NAME: VERSION # : 1 DATE: 85/11/20 MAX RECORD LENGTH: FILE TYPE: LO PREVIOUS FILE NAME: 1024 BYTES ** INFORMATION RECORDS ** 28.747 447.563 10000.000 54.459 448.750 10000.000 CAL TlR1 RILD CAL TlR1 RILD -1.602 337.375 4.447 -2.283 335.813 ' 4.447 MNEM CONTENTS ------~m APIN : 50-029-21810-00 CN : ARCO ALASKA, INC. WN : D.S. 14-37 FN : PRUOHOE BAY COUN : NORTH SLOPE STAT : ALASKA LCC : 150.00 ** FORMAT ** UNITS ENTRY BLOCKS TYPE ENTRY DESCRIPTION mmmm mmmmm 4 I DEPTHS DECREASE 8 60.0 FRAME SPACING 9 .lIN FRAME SPACING UNITS 11 19 MAXIMUM FRAMES/RECORD 0 TERMINATOR -0.500 LEVEL SPACING DATUM SPECIFICATION BLOCKS CURVE REPR NAME CODE SIZE SAMPLE mmm-- mmmmmm UNITS CURVE NAME mmmmm-- REPR CODE mmmm SIZE SAMPLE UNITS ClLD 68 GR 68 T2R2 68 TlR2 68 AC 68 RILM 68 4 I MMHO 4 I AP1 4 I US 4 I US 4 I US/F 4 I OHMM ** F~RMAT ** Sp 68 4 1 CAL 68 4 1 T2R1 68 4 1 TlR1 68 4 1 RFOC 68 4 1 RILD 68 4 1 MV IN US US OHMM OHMM TYPE 4 8 9 11 0 ENTRY ENTRY 1 60.0 .lIN 19 -0.500 BLOCKS DESCRIPTION DEPTHS DECREASE FRAME SPACING FRAME SPACING UNITS MAXIMUM FRAMES/RECORD TERMINATOR LEVEL SPACZNG DATUM SPECIFICATION BLOCKS CURVE REPR .............. NAME CODE SIZE SAMPLE UNITS CILD 68 4 I MMHO GR 68 4 I API T2R2 68 4 I US TlR2 68 4 1 US AC 68 '4 I US/F RILM 68 4 I OHMM ** DATA ** DEPTH 10017.000 FT 3053.1880 M CILD 416.404 SP -83.562 T2R2 628.875 T2R1 629. 563 AC 43.980 RFOC 6.398 DEPTH 10000.000 FT 3048.00b0 M CILD 416.916 SP -33.478 T2R2 628.875 T2R1 --629.563 AC 43.980 R,=OC 6.239 DEPTH 9900.000 FT 3017.5260 M CILD 335.740 SP -84.625 T2R2 446.188 T2R1 596.563 AC 79.203 RFOC 16.497 DEPTM 9800.000 FT 2987.0460 M CILD 164.375 SP -89.805 T2R2 484.750 T2R1 667.688 AC 92.917 RFOC 16.885 DEPTH CILD T2R2 AC 9700.000 FT 2956.5660 M 83.Z35 SP -63.862 461 .625 T2R1 624.750 85.230 RFOC 25.596 DE PTH 9600 .000 FT 2926.0860 M . / CURVE -_ REPR NAME CODE lmm~ SP 68 CAL 68 T2R1 68 TlR1 68 RFOC 68 RILO 68 SIZE 4 4 4 4 4 4 GR 25.638 TlR2 628.625 RILM 3.064 GR 25.638 TlR2 628.025 RILM 3.060 GR 25.062 TlR2 601.063 RILM 3.510 GR 24.568 TlR2 673.000 RILM 7.102 GR 26.000 TlR2 626.188 RILM 14.119 SAMPLE 1 1 1 1 1 1 CAL TlR1 RILD CAL TlR1 RILD CAL TlR1 RILD CAL TlR1 RILD CAL TlR1 RILD UNITS MV IN US US OHMM OHMM -2.000 453.375 2.402 -2.000 453.375 2.399 -1 .996 448.938 2.975 -0.326 492.938 6.084 -1.288 464.500 12.014 CILO 261.316 SP -27.569 GR T2R2 327.563 T2R1 442.375 T1 R2 AC 55.427 RFOC 0.339 RILM DEPTH 9553.500 FT 2911.9130 M CI~L~. 261.316 SP -27.569 GR T2R2' 328.750 T2R1 441.188 TlR2 AC 55.979 RFOC 0.339 RILM STARTING DEPTH =10017.000 FT 3053.1880 M ENDING DEPTH = 9553.500 FT 2911.9130 M ** FILE TRAILER ** FILE NAME: OI/B-R.002 SERVICE NAME: VERSION # : 1 DATE: ~5/11/ MAXIMUM LENGTH: FILE TYPE: LO NEXT FILE NAME: 1024 ** FILE HEADER # 3 ** FILE NAME: ZDL-M .003 SERVICE NAME:' VERSION ~ : 1 DATE: 85/11/20 MAX RECORO LENGTH: 1024 BYTES FILE TYPE: LO PREVIOUS FILE NAME: . ** INFORMATION RECORDS ** 29.320 448.000 10000.000 43.039 445.750 10000.000 CAL TlR1 RILO CAL TlR1 RILD -0.826 334.875 3.827 -2.004 334.250 3.827 MNEM CONTENTS APIN : 50-029-21810-00 CN : ARCO ALASKA, INC. WN : D.S. 14-37 FN : PRUOHOE BAY COUN : NORTH SLOPE STAT : ALASK~ LCC : 150.00 ** FORMAT ** UNITS ENTRY BLOCKS TYPE ENTRY OESCRIPTION 4 1. DEPTHS DECREASE 8 60.0 FRAME SPACING 9 .lIN FRAME SPACING UNITS 11 12 MAXIMUM FRAMES/RECORD 0 TERMINATOR -0.500 LEVEL SPACING OATUM SPECIFICATION BLOCKS CURVE NAME REPR COOE SIZE SAMPLE UNITS CURVE NAME REPR CODE SIZE SAMPLE UNITS GR 68 4 I API SSD 68 4 1 CPS HR02 68 4 I CPS SHR 68 4 1 DIM SSN 68 4 I CPS TEMP 68 4 I DEGF TTEN 68 4 I LBF ZDE~~ 68 4 I G/C3 PE 68 4 I BARN CNC 68 4 I PU CAL HRD1 SFT2 LSN RB CHT SPD ZCOR CN PORZ. 68 68 68 68 68 68 68 68 68 68 IN CPS DIM CPS DEG LBF F/MN G/C3 PU PU ** FORMAT ** ENTRY BLOCKS TYPE ENTRY DESCRIPTION ____ 4 I DEPTHS DECREASE 8 60.0 FRAME SPACING 9 .lIN FRAME SPACING UNITS 11 12 MAXIMUM FRAMES/RECORD 0 TERMINATOR -0.500 LEVEL SPACING DATUM SPECIFICATION BLOCKS CURVE REPR NAME CODE SIZE SAMPLE UNITS GR 68 4 I API SSD 68 4 I CPS HRD2 68 4 I CPS SHR 68 4 1 DIM SSN 68 4 1 CPS TEMP 68 4 1 DEGF TTEN 68 4 I LBF ZDEN 68 4 I G/C3 PE 68 4 I BARN CNC 68 4 I PU CURVE NAME CAL HRD1 SFT2 LSN RB CHT SPD ZCOR CN PORZ REPR CODE 68 68 68 68 68 68 68 68 68 68 SIZE 4 4 4 4 4 4 4 4 SAMPLE 1 1 1 1 1 1 1 1 1 1 UNITS IN CPS DIM CmS DEG LBF F/MN G/C3 PU PU ** DATA ** DEPTH 10019.000 FT 3053.7970 M GR 36.171 CAL 8.514 HRD2 1025.897 SFT2 600.940 SSN 265.973 RB -1.853 TTEN 2598.340 SPD 18.998 PE 3.000 CN 15.000 SSD SHR TEMP ZDEN CNC 9025.102 0.520 ~.500 2.500 19.000 HRD1 LSN CHT ZCOR PORZ · _ 775.922 96.990 11117.690 0.000 9.091 DEPTH 10000.000 FT 3048.0060 M GR 36.171 C&L 8.526 HRD2 1288.527 SFT2 805.164 SSN 265.346 R6 -1.853 TTEN 3796.533 SPD 19.648 PE 3.397 CN 21.412 SSD SHR TEMP ZDEN CNC 8879.324 0.555 4.500 2.739 25.412 HRD1 LSN CHT ZCOR PORZ 959.052 96.999 11117.690 0.192 -5.408 DEPTH 9900.000 FT 3017.5260 M GR 22.713 CAL 8 HRD2 1781.431 SFT2 1231 SSN 307.958 RB -1 TTEN 3950.830 SPD 20 PE I .601 CN 16 .514 SSD 9101.281 .455 SHR 0.654 .853 TEMP 4.500 .168 Z~DEN 2.328 .446 CNC 20.446 HRD1 LSN CHT ZCOR PORZ 1~,10.321 133.012 11117.690 0.053 19.533 DEPTH 9800.000 FT GR 22.424 HRD2 2002.757 SSN 261.780 TTEN 3723.919 PE 2.873 2987. 0460 M CAL 8.514 SFT2 1380.067 RB -1.853 SPO 20.107 CN 23.888 DEPTH 9700.000 FT 2956.5660 M SSD SHR TEMP ZDEN CNC GR 24.087 HRD2 1507.364 SSN- 275.337 TTEN 3684.072 PE 1.747 DEPTH 9600.000 FT CAL SFT2 RB SPD CN . . 8.627 1032.973 -1.853 20.386 18.703 2926. 0860 M SSO SHR TEMP ZDEN CNC GR 24.825 CAL HRD2 632.937 SFT2 SSN 186.669 RB TTEN 3842.616 SPD PE 19.221 CN DEPTH 9555.500 FT 8.627 202.980 -1.853 19.998 24.536 2912.5220 M SSD SHR TEMP Z~EN CNC GR 84.641 CAL HRD2 632.937 SFT2 SSN 215.978 RB TTEN 3842.616 SPD PE 19.204 CN 8.627 SSD 202.980 SHR -1.853 TEMP 19.998 ZDEN 20.494 CNC STARTING DEPTH :10019.000 FT ENDING DEPTH : 9555.500 FT 3053.7970 M 2912.5220 M 9500.895 0.684 4.500 2.291 27.888 8276.672 0.723 4.500 2.275 22.703 2737.726 0.210 4.500 2.082 28.536 · _ 2737.726 0.210 4.500 2.080 24.494 HRD1 LSN CHT ZCOR PORZ HRD1 LSN CHT ZCOR PORZ HRD1 LSN CHT ZCOR PORZ HR91 LSN CHT ZCOR PORZ 1608.862 83.428 11117.690 0.027 21 .768 1204.1B8 86.848 11117.690 0.029 22.721 382.962 55.835 11117.690 -0.730 34.413 382.962 80.992 11117.690 -0.731 34.539 ** FILE TRAILER ** FILE NAME: ZDL-M .003 SERVICE NAME: VERSION # : 1 DATE: 85/11/ MAXIMUM LENGTH: 1024 FILE TYPE: LO NEXT FILE NAME: .. ** FILE HEADER # 4 ** FILE NAME: ZDL-R .004 SERVICE NAME: VERSION # : 1 DATE: 85/11/20 MAX RECORD LENGTH: FILE TYPE: LO PREVIOUS FILE NAME: 1024 BYTES ** INFORMATION RECORDS ** MNEM CONTENTS /~PIN : 50-029-21810-00 CN' : ARCO ALASKA~ I-NC. WN : D.S. 14-37 FN : PRUDHOE BAY COUN : NORTH SLOPE UNITS :;!., S T A T : · LCC : ALASKA 150.00 ** FORMAT ** ENTRY BLOCKS TYPE ENTRY 4 1 8 60.0 9 .lIN 11 12 0 -0.500 DESCRIPTION DEPTHS DECREASE FRAME SPACING FRAME SPACING UNITS MAXIMUM FRAMES/RECORD TERMINATOR LEVEL SPACING DATUM SPECIFICATION BLOCKS CURVE REPR NAME CODE SIZE SAMP ... 68 ' 4 - 68 '- 4 68 4 68 68 _ 4 MP 68 4 TTEN 68 4 ZOEN 68 4 PE 68 4 CNC 68 4 .... GR .... S S ..... HR :..:;........, SS . TE O D2 R N · "'--TYPE · . : . 8 /. 9 .~. 0 ** FORMAT ** DATUM LE UNITS I API 1 CPS I CPS 1 DIM I CPS I OEGF I LBF I G/C3 I BARN I PU ENTRY BLOCKS ENTRY 1 6O.O .lIN 12 -0.500 DESCRIPTION DEPTHS DECREASE FRAME SPACING FRAME SPACING UNITS MAXIMUM FRAMES/RECORD TERMINATOR LEVEL SPACING SPECIFICATION BLOCKS CURVE REPR NAME CODE SIZE GR 68 4 SSD 68 4 HRD2 68 4 SHR 68 4 SSN 68 4 TEMP 68 4 TTEN 68 4 ZDEN 68 4 PE 68 4 CNC 68 4 SAMP CURVE NAME CAL HRD1 SFT2 LSN RB CHT SPD ZCOR CN PORZ CURVE LE UNITS NAME I API CAL I CPS HRD1 I CPS SFT2 I DIM LSN I CPS RB I DEGF CHT I LBF SPD I G/C3 ZCOR 1 BARN CN I PU PORZ : :'" ** DATA ** .,', .;.... DEPTH 10020.000 FT 3054.1020 M "':" '. "':-'::" ' ' ' ' '-' ,..~:i,i?:~q~'~: ! -7 ' ' ' · '.': · ' :'~ ::;i~':': ;;':' ~;': '" i REPR CODE 68 68 68 68 68 68 68 68 68 68 REPR CODE 68 68 68 68 68 68 68 68 68 68 SIZE 4 4 4 4 4 4 4 4 4 4 SAMPLE 1 1 1 1 1 1 1 1 1 1 SIZE 4 4 4 4 4 4 4 4 4 4 SAMPLE 1 1 1 1 1 1 1 1 1 1 UNITS IN CPS DIM CPS DEG LBF F/MN G/C3 PU PU UNITS IN CPS DIM CPS DEG LBF F/MN G/C3 PU PU GR 34,001 CAL 8,514 HRD2 1079,892 SFT2 634,937 SSN 272,973 RB -1.853 TTEN 2488,551 SPD 20.998 PE 3,000 CN 15,000 SSD ': SHR TEMP ZOEN CNC DEPTH 10000,000 FT 3048,0060 M GR 34,001 CAL 8,514 HR02 1255,047 SFT2 833,467 SSN 267,653 RB -1,853 TTEN 3713,906 SPD 19.998 PE 3,344 CN 24,977 SSD SHR TEMP ZDEN CNC' OEPTH 9900,000 FT 3017,5260 M GR 19,469 CAL 8.542 HRD2 1842,372 SFT2 1264.658 SSN 300,550 RB -1 ,853 TTEN 4223,785 SPD 19.998 PE I ,980 CN 16.809 SSD SHR TEMP ZDEN CNC DEPTH 9500,000 FT 2987,0460 M -------- GR 21.695 CAL 8.512 HRD2 1984.915 SFT2 1404,781 SSN 238,807 RB -1,853 TTEN 3747,495 SPD 20.198 PE 3,003 CN 21.900 SSD SHR TEMP ZDEN CNC DEPTH 9700.000 FT 2956.5660 M GR 28.0~5 CAL 8.627 HRD2 1557.570 SFT2 1068.355 SSN 272.755 RB -1,853 TTEN 5019,211 SPO 19.998 PE 2.528 CN 19.512 SSD SHR TEMP ZDEN CNC DEPTH 9600.000 FT 2926.0860 M GR 27,311 CAL 8.514 HRD2 287.160 SFT2 81,057 SSN 183,385 RB -1,853 TTEN 3910,470 SPO 19,998 PE 15.896 CN 27,916 SSD SHR TEMP ZDEN CNC DEPTH 9540.500 FT 2907,9500 M GR 26.043 CAL HRD2 487.951 SFT2 SSN 151.985 RB TTEN 3976,803 SPO PE 23.971 CN 8.627 SSD 133.986 SHR -1.853 TEMP 19,998 ZOEN 38.037 CNC STARTING DEPTH :10020,000 FT ENDING DEPTH : 9540,500 FT 3054,1020 M 2907,9500 M 8930.109 0,530 4,500 2,500 19,000 8890,574 0,578 4.500 2,742 28.977 9027,703 0.662 4,500 2,314 20.809 9538.031 0.678 4.500 2.282 25.900 9174,871 0.623 4.500 2.438 23,512 2225.500 0,157 4,500 2.126 31 .916 2864.713 0.160 4,500 2,337 42.037 HRD1 LSN CHT ZCOR PORZ HRD1 LSN CHT ZCOR PORZ HRD1 LSN CHT ZCOR PORZ HRD1 LSN CHT ZCOR PORZ HRD1 LSN CHT ZCOR PORZ HRD1 LSN CHT ZCOR PORZ HRD1 LSN CHT ZCOR PORZ 771.923 89.991 11117,690 0,000 9.091 1009.617 96.633 11117,690 0,193 -5,558 1440,722 133.282 11117,690 0.027 20.368 1588,826 86.694 11117.690 O.02g 22,313 1220.541 88.589 11117.690 0,076 12,823 142,0.31 56.539 11117,690 -0.709 31,765 261.974 37.996 11117,690 -0,608 18.976 ** FILE TRAILER ** FILE NAME: ZDL-R .004 SERVICE NAME: VERSION # : 1 D.~TE: 85111/ MAXIMUM LENGTH: 1024 FILE TYPE: LO · , .. . · - NEXT FILE NAME: ** FILE HEADER # 5 ** FILE NAME: CH CN .005 SERVICE NAME: VERSION # : 1 DATE:' 85/11/20 MAX RECORD LENGTH: 1024 BYTES FILE TYPE: LO PREVIOUS FILE NAME: . .. · .. :':?;'~!i~'~ ** INFORMATION RECORDS ** MNEM CONTENTS APIN : 50-0Z9-21810-00 CN : ARCO ALASKA, INC. WN : P.S. 14-37 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA LCC : 150;00-' UNITS ** FORMAT ** ENTRY BLOCKS TYPE ENTRY DESCRIPTION mmm-- 4 8 9 11 0 I DEPTHS DECREASE 60.0 FRAME SPACING .lIN FRAME SPACING UNITS 12 MAXIMUM FRAMES/RECORD TERMINATOR -0.500 LEVEL SPACING DATUM SPECIFICATION BLOCKS CURVE REPR NAME CODE SIZE SAMPLE UNITS GR SSD HRD2 SHR SSN TEMP TTEN ZDEN CNC 68 4 1 API 68 4 I CPS 68 4 I CPS 68 4 I DIM 68 4 I CPS 68 4 I DEGF 68 4 I LBF 68 4 I G/C3 68 4 I BARN 68 4 1 PU ** FORMAT ** CURVE NAME REPR CODE SIZE SAMPLE UNITS mmmm mmmm CAL 68 4 I IN HR01 68 4 I CPS SFT2 68 4 1 DIM LSN 68 4 1 CPS RB 68 4 I PEG CHT 68 4 I LBF SPD 68 4 I F/MN ZCOR 68 4 I G/C3 CN 68 4 I PU PORZ: 68 4 1 PU iO ENTRY BLOCKS TYPE ENTRY DESCRIPTION 4 I DEPTHS DECREASE 8 60.0 FRAME SPACING 9 .lIN FRAME SPACING UNITS 11 12 MAXIMUM FRAMES/RECORD .. 0 , TERMINATOR -0,500 LEVEL SPACING DATUM SPECIFICATION BLOCKS ii CURVE REPR NAME CODE SIZE SAMPLE UNITS GR 68 4 I API SSD 68 4 I CPS HRD2 68 4 I CPS SHR 68 4 I DIM SSN 68 4 I CPS TEMP 68 4 I DEGF TTEN 68 4 I LBF ZDEN 68 4 I G/C3 PE 68 4 I BARN CNC 68 4 I PU CURVE NAME CAL HRD1 SFT2 LSN RB CHT SPD ZCOR CN PORZ REPR CODE SIZE 68 4 68 4 68 4 68 4 68 4 68 4 68 4 68 4 68 4 68 4 SAMPLE 1 1 1 1 1 1 1 1 1 1 UNITS CPS DIM CPS DEG ,LBF F/MN G/C3 PU PU ** DATA ** DE GR HR SS TT PE PTH 9600.000 FT 2926.0860 M N EN 67.279 ~CAL 238.442' --SFT2 182.663 RS 3749.215 SPD 16.671 CN 0.467 95,540 -1 ,853 28,468 31,298 SSD SHR TEMP ZDEN CNC 2078,369 HRD1 0,165 LSN 4,500 CHT 2,105 ZCOR 35.298 PORZ 162.301 51.971 11117.690 -0.716 33,043' DEPTH 9500.000 FT 2895.6060 M GR 64.544 HRD2 432.454 SSN 134,441 TTEN 3726.541 PE 17,804 CAL SFT2 RB SPD CN 0.468 132,228 -1.853 27.997 66,986 DEPTH 9400.000 FT 2865,1260 M GR 62,234 CAL 0.468 HRD2 454.928 SFT2 124,874 SSN 130.124 RB -1,853 TTEN 3680.373 SPO 27.997 PE 17.473 CN 58.128 DEPTH 9300.000 FT 2834.6460 M mmm~mmmm~mmmmmmmmm~mmmmm GR 62.814 CAL 0.468 HRD2 906,871 SFT2 306.516 SSN 122.637 RB -1.853 TTEN 3696.722 SPD 27.997 PE 17,166 CN 64.171 SSD SHR TEMP ZDEN CNC SSD SHR TEMP ZDEN CNC SSD SHR TEMP ZDEN CNC 2347.865 HRD1 0.160 LSN 4.500 CHT 2.365 ZCOR 70.986 PORZ 2287.562 HR01 0,177 LSN 4.500 CHT 2.009 ZCOR 62.128 PORZ 3375.304 HRD1 0.193 LSN 4,500 CHT 1 .979 ZCOR 68.171 PORZ 253.666 27.743 11117.690 -0.614 17.301 262.152 25.379 11117.690 -0.616 38.846 549,714 24.693 11117.690 -0.621 40.653 H EPTH 9200.000 FT 2804.1660 M R 61.178 CAL RD2 929,126 SFT2 SN 121.319 RB TEN 3606.845 SPD E 16.816 CN 0.468 312.268 -1.853 28,027 80.183 DEPTH GR HRD2 SSN 9100.000 FT 2773. 6860 M 59.215 CAL 338.029 SFT2 132,845 RB SSD SHR TEMP ZDEN CNC 0,468 SSD 107,945 SHR -1 ,853 TEMP 3580.956 HRD1 0,189 LSN 4,500 CHT I .964 ZCOR 84.183 PORZ 1704.847 HRD1 0.197 LSN 4.500 CHT 606,510 23,980 11117.690 -0.604 41.589 195.834 23.077 11117.690 TTEN 3590.263 SPD 28,488 PE I 8.847 CN 59,506 DEPTH 9000,000 FT 2743.2060 M GR 58.808 CAL 0.468 HRD2 845.905 SFT2 285.373 SSN '~ 126.399 RB -1.853 TTEN 3530.482 SPO 28.870 PE 16.447 CN 68.819 · . · ZOEN CNG SSD SHR TEMP ZDEN CNC 2.o43 63.506 3363.034 0,192 4.500 2.007 72.819 ZCOR PORZ HRD1 LSN CHT Z-COR PORZ '0.625 36,759 537.452 25,817 11117.690 -0.643 38.984 i2 DEPTH 8900.000 FT 2712.7260 M GR 58,843 CAL 0,468 HR02 919.691 SFT2 324,481 SSN 124.681 RB -1.853 TTEN 3462,867 SPD 28,997 PE 15.861 CN 59.165 SSD SHR TEMP ZDEN CNC 3558.281 0,193 4.500 1.986 63.165 HRD1 LSN CHT ZCOR PORZ 605.933 22.762 11117,690 -0.633 40.232 DEPTH 8800.000 FT 2682.2450 M GR 62.791 CAL 0,468 HR02 813.426 SFT2 262.469 SSN 125.254 RB -1.853 TTEN 3397.661 SPD 29.167 PE 19,121 CN 57,487 SSD SHR TEMP ZDEN CNC 3259.111 0,177 4.500 2.066 61.487 HRD1 LSN CHT ZCOR PORZ 489.798 24.410 11117.690 ...... -0.615 35.397 DEPTH 8700.000 FT 2651.7650 M GR 121 .505 CAL 0,468 HRD2 617.159 SFT2 198.182 SSN 132,309 RB -1.853 TTEN 3331.082 SPD 28.997 PE 19.152 CN 54.808 SSD SHR TEMP ZDEN CNC 2693.013 0.171 4.500 2.262 58.8O8 HRD1 LSN CHT ZCOR PORZ 387,005 27.794 11117.690 -0.647 23,514 DEPTH 8600.000 FT 2621,2850 M GR 111.405 CAL 0,468 MRD2 317.131 SFT2 98,840 SSN 130.971 RB -1,853 TTEN 3295. 387 SPD 28,997 PE 18.181 CN 67.512 SSD SHR TEMP ZDEN CNC 1749.151 0.170 4.500 2.041 71.512 HRD1 LSN CHT ZCOR PORZ 220.054 22.351 11117.690 -0,617 36.887 DEPTH 8500.000 FT 2590.8050 M GR 50,713 CAL 0.468 HRD2 806,898 SFT2 267.770 SSN 139,512 RB -1.853 TTEN 3244,511 SPO 29.330 PE 20.369 CN 55,731 SSD SHR TEMP ZDEN CNC 3326.368 0,193 4.500 2.074 59.731 HRD1 LSN CHT ZCOR PORZ 476.558 30.888 11117.690 -0.629 34.912 DEPTH 8400.000 ET 2560.3250 M mmmm~mmmmmm~mmmmmmmmmmmmmmmmm~ GR 75.855 CAL 0,468 HRD2 830.973 SFT2 265,208 SSN 143.857 RB -1.853 TTEN 3227.440 SPD 29,694 PE 19,937 CN 49.936 SSD SHR TEMP ZDEN CNC 3411.017 0,206 4,50O 2.196 53,936 HRD1 LSN CHT ZCOR PORZ 508,575 34,059 11117.690 -0.721 27.519 DEPTH 8300.000 FT 2529.8450 M GR 101,874 CAL 0.468 HRD2 606,833 SFT2 206.764 SSN 129,136 RB -1.853 TTEN 3164.057 SPD 29.477 PE 15,965 CN ..., 53,028 SSD SHR TEMP ZDEN CNC 2521.983 0,166 4.500 1.999 57.028 HRD1 LSN CHT ZCOR PORZ - 395.755 24.400 11117.690 -0.633 39.443 DEPTH 8200,O00'FT 2499,3650 M i3 GR 94,054 CAL 0,468 HRD2 '730,357 SFT2 244,064 SSN 147,758 R~ -1,853 TTEN 3111,432 SPO 29.403 PE ~: 14,692 CN 51.698 DEPTH 8100,000 FT 2468,8850 M GR 105,059 CAL 0,468 HRD2 726,278 SFT2 240,149 SSN 135,538 RB -1,853 TTEN 3073.725 SPD 29,233 PE 20,885 CN 44.611 SSD SHR TEMP ZDEN CNC SSD SHR TEMP ZDEN CNC 2950,009 0,177 4,500 2,234 55,698 3284,667 0,208 4,500 2,124 48,611 HROl LSN CHT ZCOR PORZ HRD1 LSN CHT ZCOR PORZ 451 .434 37,780 11117,690 -0.615 25,213 483,489 32,633 11117,690 -0,599 31,865 DEPTH 8000,000 FT 2438,4050 M GR 64,427 CAL 0,468 HR02 787,328 SFT2 265,420 SSN 129,819 RB -1,853 TTEN 3063,793 SPD 29,747 PE ...... 15,642 CN ....... 55,016 DEPTH 7900.000 FT 2407,9250 M SSD SHR TEMP ZDEN CNC GR 65,602 CAL 0,439 HRO2 617,338 SFT2 211,178 SSN 142.934 RB -1,853 TTEN 3024.308 SPD 29.997 PE 17.339 CN 62.353 SSD SHR TEMP ZDEN CNC 3180.699 0,169 4,500 2,178 59,016 3105,935 0,177 4.500 2,158 66,35'3 HRD1 LSN CHT ZCOR PORZ _ HRD1 LSN CHT ZCOR PORZ 476,813 25.055 11117,690 -0,768 28.609 393,400 34,751 11117,690 -0,619 29.814 DEPTH 7800.000 FT 2377.4450 M GR 49,332 CAL 0.468 HRD2 591 ,416 SFT2 197,937 SSN 143,896 RB -t .853 TTEN 2973,041 SPD 29.997 PE 15,037 CN 43,01 2 SSD SHR TEMP ZDEN CNC 2959,382 0,207 4.500 2,236 47.012 HRD1 LSN CHT ZCOR PORZ 357,041 30,835 11117.690 -0,666 25.096 DEPTH 7700,000 FT 2346,9650 M GR 46,293 CAL 0,468 HRD2 768,164 SFT2 ' 260,925 SSN 132,150 RB -1,853 TTEN 2965,1 26 SPD 29,997 PE 18,763 CN 42,126 SSD SHR -' TEMP ZDEN CNC 3190.752 0,172 4,500 2,051 46,126 HRD1 LSN CHT ZCOR PORZ 481.440 30,554 11117,690 -0,664 36,301 DEPTH 7600.000 FT 2316,4850 M GR 50,158 CAL 0,465 HRD2 798,534 SFT2 277,752 SSN 134,742 RB -1 .853 TTEN 291 6,679 SPD 29,997 PE 15,326 CN 51,310 SSD SHR TEMP ZDEN CNC 3323,794 0,193 4,500 2,086 55.310 HRD1 LSN CHT ZCOR PORZ 499,098 27,744 11117,690 -0,582 34,165 DEPTH 7500,000 FT 2286,0050 M . GR 43,649 CAL 0,468 HRD2 731,942 SFT2 241,375 SSN 133.603 RB -1,853 TTEN 2895,503 SPD 30,997 PE 16,346 CN 46,033 ., " ..' DEPTH 7400,000 FT 2255,5250 M . - . , SSD SHR TEMP ZDEN CNC 3147,904 0.217 4.500 2,042 50,033 HRD1 LSN CHT ZCOR PORZ 480.332 26,557 11117,690 -0.677 36,848 DEP~:H 7300.0 GR 47. HR02 804. SSN 1 TTEN 28 PE GR 46.476 CAL 0.468 SSD HRD2 637.797 SFT2 221.753 SHR SSN 141.295 RB -1.853 TEMP TTEN 2867.648 SPD 33.826 ZDEN PE 19.124 CN 60.083 CNC 00 MT 2225.0440 M 623 CAL 0.468 SSO 370 SFT2 287.211 SHR 28.898 R8 -1.853 TEMP 55.005 SPD 45.995 ZDEN 13.942 CN 45.407 CNC DEPTH 7200.000 FT 2194.5640 M GR 65.750 CAL 0.468 SSD HR02 959.314 SFT2 330.613 SHR SSN 126.247 RB -1.853 TEMP TTEN 2784.070 SPD 45.789 ZDEN PE 16.549 CN 77.357 CNC --'-OEPTH 7100.000 FT 2164.0840 M GR 55.113 CAL : 0.468 SSO HR02 937. 299 SFT2 348.249 SHR SSN 128.021 R8 -1 .853 TEMP TTEN 27?9.1 22 SPD 45.667 ZDEN PE 18.182 CN 51.030 CNC DEPTH 7000.000 FT 2133.6040 M GR 55.434 CAL 0.468 SSD HR02 897.1 09 SFT2 291 .382 SHR SSN 126.639 RB -1.853 TEMP TTEN 2760.779 SPD 47.031 ZDEN PE 14.048 CN 69.421 CNC DEPTH 6952.500 FT 2119.1260 M GR 70.471 C~L 0.468 SSD HRO2 943.906 SFT2 - 331.967 SHR SSN 127.987 RB -1.853 TEMP TTEN 2769.123 SPD 46.995 ZDEN PE 16.162 CN 97.863 CNC STARTING DEPTH = 9624.000 FT 2933.4010 M ENDING DEPTH = 6952.500 FT 2119.1260 M 2972.220 0.193 4.500 2.132 64.083 3234.619 0.187 4.500 1 .961 49.407 3470.401 0.182 4.5O0 2.003 81.357 3586.805 0.191 4.500 2.016 55.030 3349.504 0.215 4.500 1.948 73.421 3149.685 0.220 4.500 1.931 101.863 HR01 LSN CHT ZCOR PORZ HR01 LSN CHT ZCOR PORZ HROl LSN CHT ZCOR PORZ HROl LSN CHT ZCOR PORZ HRD1 LSN CHT ZCOR PORZ HRD1 LSN CHT ZCOR PORZ 423.875 31.845 11117.690 -0.637 31.389 559.600 27.761 11117.690 -0.690 41.755 557.902 24.908 11117.690 -0.615 39.192 574.205 24.633 11117.690' -0.611 38.443 570.816 29.236 11117.690 -0.681 42.515 549.945 20.998 11117.690 -0.711 43.593 I4 ** FILE TRAILER ** FILE NAME: CH CN .005 SERVICE NAME: VERSION # : 1 DATE: 85/11/ MAXIMUM LENGTH: 1024 FILE TYPE: LO NEXT FILE NAME: ** TAPE TRAILER ** TAPE NAME: SERVICE NAME: CH CN DATE. ORIGIN OF DATA: FSYS .......... - - ' . - ' - ,~.~".~-.:.-'.-. :.-i '-? - ~:" TAP~ CON,TINU. ATIoN # : 01 NEXT' TAPE NAME: "COMMENTS: ** REEL TRAILER ** REEL NAME: SER-VICE NAME: BITLIS DATE . ORIGIN OF DATA: FSY, S REEL CONTINUATION # : 01 NEXT REEL NAME: COMMENTS: DRESSER ATLAS LIS CUSTOMER TAPE --- CREATED BY SDS PROGRAM R 2.0 REEL HEADER - ;rAPE HEADER- FILE HEADER - INFORMATION - FORMAT - DATA - TAE~LE DUMP - FILE TRAILER - TAPE TRAILER - REEL TRAILER - 1 5 5 10 702 5 5 1 1 TOTAL RECORDS: 736
