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Home My WebLink About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y Jody Colombie at 11:10 am, Dec 22, 2020 'LJLWDOO\VLJQHGE\%R<RUN '1FQ %R<RUNF 86R +,OFRUS $ODVND//&RX $ODVND1RUWK 6ORSHHPDLO E\RUN#KLOFRUSFRP 'DWH %R<RUN DSR-12/22/2020 10-404 MGR22DEC2020 X DLB12/22/2020 <HV Q5HTXLUHG" &RPP 1/21/21 dts 1/21/2021 JLC 1/21/2021 RBDMS HEW 1/26/2021 tĞůůtŽƌŬWƌŽŐŶŽƐŝƐ tĞůůEĂŵĞ͗WGI-05 W/EƵŵďĞƌ͗ϱϬͲϬϮϵͲϮϮϬϭϱͲϬϬ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗'ĂƐ/ŶũĞĐƚŽƌ >ĞŐ͗ ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗&ĞďϭƐƚ͕ϮϬϮϭ ZŝŐ͗Eͬ ZĞŐ͘ƉƉƌŽǀĂů ZĞƋ͛Ě͍ϭϬͲϰϬϯ ĂƚĞ ZĞŐ͘ƉƉƌŽǀĂů ZĞĐĞŝǀĞĚ͗ ZĞŐƵůĂƚŽƌǇŽŶƚĂĐƚ͗ĂƌƌŝĞ :ĂŶŽǁƐŬŝ WĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϭϵϬͲϬϮϱϬ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗ĂǀĞũŽƌŬ KĨĨŝĐĞ͗ϵϬϳͲϱϲϰͲϰϲϳϮ Ğůů͗ϵϬϳͲϰϰϬͲϬϯϯϭ ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗ZǇĂŶdŚŽŵƉƐŽŶ KĨĨŝĐĞ͗ϵϬϳͲϱϲϰͲϱϮϴϬ Ğůů͗ϵϬϳͲϯϬϭͲϭϮϰϬ 'ĂƐ/ŶũĞĐƚŝŽŶZĂƚĞ͗Ϯϱϵ͕ϱϲϭDƐĐĨͬĂǇ /ŶũĞĐƚŝŽŶWƌĞƐƐƵƌĞ͗ϯ͕ϲϲϮƉƐŝ ZĞƐĞƌǀŽŝƌWƌĞƐƐƵƌĞ;ƐƚŝŵĂƚĞͿ͗ϯϱϬϬƉƐŝ WƌŽŐƌĂŵKďũĞĐƚŝǀĞ;ƐͿ͗ t'/ͲϬϱŝƐĂŐĂƐĐĂƉŝŶũĞĐƚŝŽŶǁĞůůƚŚĂƚŚĂƐĚĞŵŽŶƐƚƌĂƚĞĚĂĚĞĐƌĞĂƐĞŝŶŝŶũĞĐƚŝǀŝƚǇ͘dŚĞǁĞůůŚĂƐŶŽƚďĞĞŶǁĂƚĞƌ ǁĂƐŚĞĚƐŝŶĐĞϮϬϭϰ͘tĂƚĞƌǁĂƐŚĞƐĂƌĞĚĞƐŝŐŶĞĚƚŽĚŝƐƐŽůǀĞƐĂůƚƐĂŶĚĂƐƉŚĂůƚĞŶĞƐŝŶƚŚĞƚƵďŝŶŐĂŶĚĨŽƌŵĂƚŝŽŶ͘ dŚĞŽďũĞĐƚŝǀĞŝƐƚŽƉĞƌĨŽƌŵĂƚƵďŝŶŐǁĂƚĞƌǁĂƐŚƚŽŝŶĐƌĞĂƐĞŝŶũĞĐƚŝǀŝƚǇĂŶĚƉĞƌĨŽƌŵĂŐĞŶĞƌĂůŵĂŝŶƚĞŶĂŶĐĞŽŶ 'ĂƐ/ŶũĞĐƚŝŽŶtĞůůƐ͘ WƌŽƉŽƐĞĚWƌŽŐƌĂŵ͗ WƵŵƉĚŝĞƐĞůĨŽůůŽǁĞĚďǇ&ƌĞƐŚtĂƚĞƌĂŶĚ^ƵƌĨĂĐƚĂŶƚĂƐƉĞƌĂƚƚĂĐŚĞĚƉƵŵƉŝŶŐ ƚĞŵƉůĂƚĞ͘ tĞůůtŽƌŬWƌŽŐŶŽƐŝƐ +LOFRUS1RUWK6ORSH//& • MEMORANDUM *tate of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Thursday,April 12,2018 P.I.Supervisor IVI 4 f i Z I1' SUBJECT: Mechanical Integrity Tests l BP EXPLORATION(ALASKA)INC. WGI-05 FROM: Guy Cook PRUDHOE BAY UNIT WGI-05 Petroleum Inspector Src: Inspector Reviewed By:r P.I.Supry J � NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT WGI-05 API Well Number 50-029-22015-00-00 Inspector Name: Guy Cook Permit Number: 190-025-0 Inspection Date: 4/11/2018 ✓ Insp Num: mitGDC180411140357 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well WGI-05 - Type Inj r G TVD 7791 Tubing 3423 - 3421 , 3422 - 3426- ---- - ---__ ----- ---- ---- PTD 1900250 - Type Test SPT-Test psi 1948 - IA 169 2500 - 2404 , 2387 - BBL Pumped: 2.7 BBL Returned: 2.3 OA 6 - 8 - 9 - 10 - Interval 4YRTST P/F P d Notes: A triplex pump was used for testing with a bleed tank. ✓ SCANNER Thursday,April 12,2018 Page 1 of 1 �'��\\I//77,:: THE STATE I, IF SF w ' r p t7 � �€ a \ / G j 333 West Seventh Avenue GOVERNOR SEAN PARNELI_ Anchorage, Alaska 99501-3572 Main: 907 279 1433 ® ALAS f' `a/: 907.27i 75A'2 SEAMED JUL 2 2 2014, Javier Farinez GPB GDE Lead PE 2' BP Exploration (Alaska), Inc. 0 P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU WGI-05 Sundry Number: 314-215 Dear Mr. Farinez: 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, /9.)9..e„ Cat y P,oerster �/�,, Chair DATED this �V day of April, 2014. Encl. RECEIVED STATE OF ALASKA APR 0 3 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other. Water Wash L• 2.Operator Name: 4.Current Well Class: 5.Permit to Drill umber. BP Exploration(Alaska),Inc. Exploratory ❑ Development ❑ 190-025-0• 3.Address: 6.API Number. Stratigraphic ❑ Service 0 P.O.Box 196612,Anchorage,AK 99519-6612 50-029-22015-00-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? PBU WGI-05 Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0028302 • PRUDHOE BAY, PRUDHOE OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 8728 . 8728 1 8686 8686 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"91.5#H-40 39-119 39-119 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production None None None None None None Liner 879 7"29#L-80 7849-8728 7848.81-8727.76 8160 7020 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(It): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: 7"Baker FB-1 Packer Packers and SSSV MD(ft)and ND(ft): 7800,7799.81 7"Camco A-1 SSSV 2187',2187' 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program D BOP Sketch ❑ Exploratory ❑ Development ❑ Service ❑� • 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ 0 , WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Javier Farinez Email Javier.Farinez@BP.Com Printed Name arinez Title GPB GDE Lead PE Signature .411•10i� Phone 564-5043 Date � L/ //cr Prepared by Garry Catron 564-4424 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. S\LA.,— 2\S Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: 1A RBDMS 3 MAY 1 0 2014 Spacing Exception Required? Yes ❑ No d Subsequent Form Required: APPROVED BY Approved by: , --)41,(„.-1t.14---- COMMISSIONER THE COMMISSION Date: +40 —/4 °1144 Form 10-403 Revised 10/2012 p o TiltiAitlid for 12 mo rom the da a of appro aI. Submit Form and Attachments' D icate �lF '/ / /iq- f �'r. Perforation Attachment ADL0028302 Well Date Perf Code MD Top MD Base TVD Top TVD Base WGI-05 6/4/90 APF 8184 8220 8184 8220 WGI-05 6/4/90 PER _ 8274 8306 8274 8306 WGI-05 6/4/90 PER 8319 8346 8319 8346 WGI-05 6/4/90 PER 8348 8476 8348 8476 WGI-05 6/4/90 PER 8484 8518 8484 8518 WGI-05 6/4/90 PER 8522 8542 8522 _ 8542 WGI-05 6/4/90 PER 8554 8613 8554 8613 WGI-05 6/4/90 PER 8620 8633 8620 8633 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF Op O a - 0 0 0 0 Ln 0 0 0 0 0 mY I owoao19aococcoC0 0 = J J J J Y J J J J J a) Q O 0 0 0 0 0 0 0 0 0 0 0 N 1, Cq 1-CO C1- O O N &) to (P CO o O p .„ (Ni rLOCO U N o 0 0 0 0 0 0 0 0 0 0 0 a) u) I- r- CONu) vvrnva) r- 00 CO - O N N CO N- CO m CO CO CO 00 tO CO N- N- o N- CO a) N m M c N 'Cr CO (A - U) N- CO N Q N00r, oCAN- NN- N- N C2 O ~ 0) %)- Coy) N- O CA N- N OC) N N Q M N M 000 0) CY) ti N N CO M N E o F CD v-03 m C07 CSO N "Cr C) LO ti COCY) Is- N UJ O Q ' NaoNaoCC) CANNNNN 2 o a Q HO) CoV) Nvo01- NLNCV Q CO N N Cr) CO o CO N N N CO0CO CO CO O Y O O CO = Z J J CO CO CO J Nrs_ J 00 J *k (ACO COCOCCDN N N Co 00 N N (A cc) M : : C Co O N to CA CA N- N Co r O0 C CO N N CO N- CO M (C N W W W g )I- QQQ •ai0 W W W W W Up0_ O_ cLwu_ u_ ZZZZZ Z W W W- Z Ce CO CO CO m 0O 0ZZZJ (I) (1) I- 1- 1- H TREE" 6-3/8"CAMERON [WELLHEAD OR= CAMERON A ER ER WGI-05 St,. .TY NOTES:WELL REQUIRES A SSSV. !#C KB.ELEV= 61' BF.ELEV= ? KOP= Max Angle= 1 @ 8300' Datum MD= N/A Datum TVD= 8800'SS 13-3/8"CSG,68#, L-80(01/02/04), ID=12.415" -{ 99' 9-5/8"CSG,47#,NT-95(01/08/04), ID=8.681" -I 741' 2214' - 7-5/8"X 7"XO, ID=6.28" 9-5/8"CSG,47#,L-80(01/08/04), ID=8.681" -I 2030' 2226' H 7"CAMCO DB NIP, ID=6.00" , 7"TBG-TCII,26#,L-80, .0383 bpf,ID=6.28" H 2237' 223T 7"X 7-5/8" XO, ID=6.28" 13-3/8"CSG,68#,L-80, ID=12.415" -{ 3494' I I Minimum ID =4.455" @ 7848' 5-1/2" HES XN NIPPLE 7757' -17-5/8"X 7"XO, ID=6.28" 7-5/8"TBG-IPC,29.7#,L-80, .0459 bpf,ID=6.88" -I 7757' • II 69' H 7"HES R NIP,ID=5.963" 7790' 17"K-22 ANCHOR SEAL ASSY, ID=6.00" 7791' -19-5/8"X 7"SAB-3 HYRO-SET PKR,ID=6.00" 7"TBG-TC-II,26#,L-80,.0383 bpf,ID=6.28" -I 7806' .177 7806' --7"X 5-1/2" XO,ID=4.86" 7817' -15-1/2"HES X NIP, ID=4.56" TOP OF 7"LNR -I 7849' ' I El 7848' -5-1/2"HES XN NIP, ID=4.455" 5-1/2"TBG-TC-II,17#,L-80, .0232 bpf,ID=4.89" JH 7870' - / 7870' H 5-1/2"TUBING TAIL W/MULE SHOE 9-5/8"CSG,47#,L-80, ID=8.681" H 8164' kNa PERFORATION SUMMARY REF LOG:SWS CET ON 03/06/90 ANGLE AT TOP PERF: 1 @ 8184' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 8184-8220 0 06/04/90 3-3/8" 4 8274-8306 0 06/04/90 3-3/8" 4 8319-8346 0 06/04/90 3-3/8" 4 8348-8476 0 06/04/90 3-3/8" 4 8484-8518 0 06/04/90 3-3/8" 4 8522-8542 0 06/04/90 3-3/8" 4 8554-8613 0 06/04/90 3-3/8" 4 8620-8633 0 06/04/90 8650' CTM -I FILL(01/25/04) PBTD 8686' .�.�.�.�.�.�.�.�. ��W. 7"LNR,29#,L-80,.0371 bpf,ID=6.184" H 8728' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03/02/90 ORIGINAL COMPLETION WELL: WGI-05 01/16/04 SRB/TLH RWO PERMIT No: 1900250 05/31/06 DTM WELLHEAD CORRECTION API No: 50-029-22015-00 08/07/07 DSM/SV TREE C/O SEC 11,T11 N,R14E, 1077.09'FEL&1102.97'FNL 09/30/09 CJN/SV R NIP CORR 02/11/11 MB/JMD ADDED SSSV SAFETY NOTE BP Exploration (Alaska) ALASKA WtLL ACTIVITY STATEMENT OF REQUIREMENTS (V1.3,DBR,LHD,EAZ 01/15/14) General Information Well Name: WGI-05 Well Type: Injector API Number: 500292201500 Well Activity Classification: Conventional 4 Activity Description: Water Wash Cost Code/AFE: APBINJEC Field/Reservoir: PRUDHOE IVISHAK 12 Month Avg IOR,bopd: Job Type: Water Wash Estimated Cost, $M: AWGRS Job Scope: PARAFFIN/ASPHALTENE REMOVAL Other regulatory requirements? Sundry Form 10-403 Required? yea Sundry Form 10-404 Required? Yes Primary Secondary Engineer: Javier Farinez Contact numbers: 907-564-5043 907-947-5722 Well Intervention Engineer: Contact numbers: Lead Engineer: Javier Farinez Contact numbers: 907-564-5043 907-947-5722 Date Created: March 25,2014 Revisions(date,who,what changed): Current Well Status Information Recent WT or Inj Rate&Pressure 3/24/2014 N/A N/A 265.MMscfpd N/A N/A N/A 3,610 psi Current Status: Operable If inoperable or under evaluation, why? N/A Recent H2S (date,ppm) N/A 0 prn Maximum Deviation(angle and depth) 1° 8,300'MD Datum depth,ft TVDss 8,800'TVDss Minimum ID and Depth 4.455"@ 7,848' Reservoir pressure(date,psig) N/A 3,700 psi Reservoir temperature,F 134°F Shut in wellhead pressure 2,820 psi Known mechanical integrity problems(specifics) None Last downhole operation(date,operation) 4/21/2010.Integirty Test Most recent TD tag,(date,depth,toolstring OD) 4/20/2010.TAGGED HARD BTM®8,648'MD W/3.70"CENT Comments,well history, Improve infectivity by dissolving salts and possibly asphaltenes in the tubing and formation. Diesel/Xylene washes have been used L,/ background information,etc: successfully in the past on the NGINVGI/AGI gas injectors to improve infectivity. Well Intervention Details Suspected Well Problem: Oragnic deposition Specific Intervention or Well Objectives: 1 Increase well injectevity by cleaning the tubing and perforations 2 3 Key risks,critical issues: Mitigation plan: 1 2 3 Summary Step Service Line Activity 1 F Pump Water Wash as per schedule form 2 3 Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 1 2 3 Performance Expectations(may be NA if no change anticipated due to the intervention) Expected Production Rates: BOPD MMSCFD BWPD FTP(psi): Choke setting: Post job POP instructions: Bring back well to injection Attachments- include in separate excel worksheets Required attachments: Current wellbore schematic As needed:Perf form,logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,wellhead info,etc Approvals Management Approval: Date: Wells Approval: Date: , • • a -} F C p � E n r �� j SEAN PARNELL, GOVERNOR ' LI! 1 LI LA ' 11 k it ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 CANCELLATION ADMINISTRATIVE APPROVAL NO. AIO 4E.031 Mr. Doug Cismoski, P.E., Wells Intervention Manager Attention: Well Integrity Engineer, PRB -20 BP Exploration (Alaska) Inc. 1 `O' . GC P.O. Box 196612 �ED 10 ff Anchorage, AK 99519 -6612 RE: Cancellation of Administrative Approval AIO 4E.031 (Well PBU WGI -05)� Dear Mr. Cismoski: Pursuant to BP Exploration (Alaska) Inc. (BPXA)'s request dated December 16, 2010, the Alaska Oil and Gas Conservation Commission (Commission) hereby cancels Administrative Approval AIO 4E.031, which allows continued gas injection in Prudhoe Bay Unit ( "PBU ") well WGI -05. This well exhibited inner annulus repressurization that could be safely managed with periodic pressure bleeds and BPXA did not at the time propose repairing the well to eliminate the problem. The Commission determined that gas injection could safely continue in the well, but subject to a number of restrictive conditions set out in the administrative approval. The well successfully passed an MIT -IA on April 21, 2010 and following setting and successful testing of the sub - surface safety valve, no IA repressurization has been evident since. Consequently, Administrative Approval AIO 4E.031 no longer applies to operation of this well. Instead, injection into PBU WGI -05 will be governed by provisions of the underlying AIO No. 4E. sKA oll G DONE at Anchorage, Alaska and dated January 3, 2011. t5; 7 41k C S' 74:7 The Alaska Oil and Gas • nservation Commission x;u.! ; 4 f.0%10' 1 14)/ z gri& I. t, r „ / „, - Daniel T. Seamount, Jr. T 4 . Nor .an. Cathy ' . Foerster Commissioner, Chair Comm i• er Commissioner • • bp BP Ezploraton (Alaska) inc. 0 Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196812 Anchorage, Alaska 99519 -8612 vFn December 16, 2010 DEG Mr. Daniel Seamount, Chairman Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Prudhoe Bay Unit Well WGI -05 (PTD #1900250) Application for Cancellation of AIO Administrative Approval 4E.031 Dear Mr. Seamount, BP Exploration (Alaska) Inc. requests cancellation of Administrative Approval number 4E.031 dated June 9, 2008. The administrative approval was for continued gas injection into Well WGI-05 with slow tubing by inner annulus communication. A subsurface safety valve was re -set April 21, 2010 after a successful AOGCC witnessed mechanical integrity test was completed. Since the subsurface safety valve was set there has been no further evidence of tubing by inner annulus communication. Therefor., it is requested to cancel Administrative Approval number 4E.031 for gas injection. A plot of wellhead pressures has been included for reference. If you require any additional information, please contact me at 564 -4303 or Gerald Murphy / Torin Roschinger at 659 -5102. Sincerely, Douglas A. Cismoski, P.E. BPXA Wells intervention Manager Attachments: TIO Plot Wellbore Schematic Cc: Doug Cismoski Steve Rossberg Bixby /Liddelow Murphy /Roschinger Flow Station 1 Operations Team Leader Bob Chiwis Harry Engel • • WGI -05 (PTD #1900250) TIO Plot wiltwesis 4000 1 1 1 3,000 1 -44-T6p -f- IA BOA 2.000 • OOA t 000A I woo On I, 1,000 • 'Ai 1 Ilii,itijilldl 1 6 1 4 /1.11.1 1 4 ( lipA, 1 _ nr,. 12/29/09 01/29/10 03/ 04/01 /10 05 08/02/10 07/03/10 08/03/10 09/03/10 10/04/10 11/04/10 12/05/10 1 r. • 0 . -t .I l - 1- l. : •. TREE • 638' CAMERON 1 C ATa u %I -o : KB. ELEV a Sr SF. 81@V ■ z ' KOP• 0' *Mx And* • 10 8303' Damara 1e ■ NA L Mum WOO' SS 134.0 - CSG, 88I, L40 (0002/04).10 • 12A1 CUL et N(40 01E1004 100 &Mr Er 8$'[ ,4?•. LAO (O1/0IRN Delmar •�iY+...i v. X rJOb. ® ®6�!{'' B Hr commas pal D•830' 1 I r TeG.TIo®.21A 480. 3383 WC D • 8.28' H 2237 r X Nur xo. D • 6.2I' a -3/r COO. . 480. D ®12.415• ' I In u;m = a�a5s•• 73411' 5.112" HES XN NIPPLE sair ' CIAO, .0444tpt.D•6.t8'`, -1 E Iii au�x r Xa�,nf 77'A' 71`68► RP 41.5443 ' �Ltj' K-22ANCl1 $E • .A Y. D• SOW E ■ ��, X7' SAd3NYR0Ser Met 0■tor .._ X8.113' X4 0.4-88` 17 1110.104 2110 480..0383 Eft, 0. 128' H 7t 1""'—' ■ I 1 7$17• H61a2' HES XM D ■ CSC , orr up H 7$4, 1---. I II Me 1Q'N68ww NO. a•4483" i J5.10 1* L4 .0232 bit 0 .4.8r H 7670 r- ---r'y + 787C' HS-112" 11X00 TAIL WII1u.asloE I 04/, CM, 478.L40.0• stet- 4' • PERFORATION SUMMARY FIEF LOL2 SWS cum 038600 APCLEATTOPt EF 1 x8181 Nob: Fbttl b Frodix000 ' ! for llMetall t dab 1 Al E 31mi Vii: 3-38' 4 8184.8220 : 08104141 340' 4 8274 -8308 0 08/04180 3-38' 4 8319 -8348 0 OQ/01/80 348' 4 8348.8476 0 08101180 3448' 4 8484.8818 0 08101/80 3448' 4 8822.8842 0 08/01/80 3-38' 4 8884.8613 0 000080 343- 4 8620 - 8633 0 08(0414) NW CT/1 • 0.t Ella. (0142004)1 Ir wt. 288. LAD, .03t1 60.10 . 8.184• •• C.22 a �: • � * .J G LiiII IIIIIIII .-.T rt PRUEICESAY UNIT [rr E.) ®`6•a 7` 1.�i �. IZI iL ..311111111 ®® NIIIIIIIIIIIIIIIIIIIIINIIIIII W*.L° WOWS ' [ '� E`: e11(: rte" mow ax 'imam I. m4. 1I1tJi.. -I*: - .'.1•• = hi•i:UM MINI MUM API Mx 80..028`2201600 Leakj 1•- i'IYr.d.i• IN= 1.1111 Sir 11. TUN. R144 loiter F .&1102.9? L : L'.. - MINI IIIIIIIIIIIIIIIIIIIIMIIIIIIII , MIMI 1111111111111111111111011111111•1111•1111 MINN 1111111111111111111111111111111111111111111I 11. EAplora Uon (Mask* • . Page 1 of 1 Regg, James B (DOA) ~', ~~~~ ~ 2 From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Friday, April 23, 2010 8:01 PM I nQ~ / To: Regg, James B (DOA); NSU, ADW Well Integrity Engineer ~~~~'(4 "Ul ~ o Cc: Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA) Subject: RE: PBU WGI-05 MIT Attachments: MIT PBU WGI-05 04-21-10.x1s Jim, This MITIA was conducted for regulatory compliance per AIO 4E.031. I have attached the MIT form we have on record for WGI-05 on 04/21/10. Please let me know if you require any additional information. Thank you, Toxin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Harmony Radio x2376 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 t..~ ~1 'L ,..r,.y' `. From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, April 23, 2010 11:17 AM To: NSU, ADW Well Integrity Engineer Cc: Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA) Subject: PBU WGI-05 MIT Attached is Inspector's report form MIT done 4/21 indicating a tubing tail plug installed. Is this supposed to be a MITT (4500 psi) for diagnostic purposes or an MITIA for regulatory compliance per AIO 4E.031? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 4/28/2010 STATE OF ALASKA Email to:jim.regg@alaska.gov; phoebe.brooks@alaska.gov; tom maunder@alaska.gov; doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: BP Exploration (Alaska), Inc. FIELD /UNIT /PAD: Prudhoe Bay /PBU /WGI DATE: 04/21 /10 OPERATOR REP: Torin Roschinger AOGCC REP: Chuck Scheve ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Packer Depth Pretest Initial 15 Min. 30 Min. Well WGI-05 ' T pe Inj. G TVD '' 7,791' Tubin 2,000 2,400 2,380 2,380 Interval V P.T.D. 1900250 ~ Type test P Test psi 1947.75 Casin 880 14,500 '4,480 ~ 4,480 P/F P ~ Notes: AA for slow TxIA Comm OA 0 0 0 0 ~ 4t•~3( Caw,pi~~~ Well T pe Inj. TVD Tubing Interval P.T.D. Type test Test psi Casin P/F Notes: OA Well Type Inj. TVD Tubin Interval P.T.D. Type test Test psi Casin P/F Notes: OA Well Type In'. TVD Tubin Interval P.T.D. Type test Test psi Casin P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G=Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT PBU WGI-OS O4-21-10.x1s • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission ' \Q ~ ~(~ Jr~ DATE: Friday, April 23, 2010 To: Jim Regg ~ `~ P.I. Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC WGI-OS I;Ito1vl: Chuck Scheve PRUDxoE BAY UNIT WGI-os Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~- Comm Well Name: PRUDHOE BAY UNIT WGI-OS API Well Number: 50-029-22015-00-00 Insp Num: mitCS100421095935 Permit Number: 190-025-0 Rel Insp Num: Inspector Name: Chuck Scheve Inspection Date: 4/21/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well wGI-os Type Inj. N TVD 779 ' IA aso asoo aaso aaso P.T.D I9oozso TypeTest SPT Test psi ~ I9a~ ~ pA o 0 0 0 Interval REQvAR p/F P - Tubing zooo zaoo z3so z3so Notes: Test perf~~orjjmed with plug set in tubing tail. :/ Friday, Apri123, 2010 Page 1 of 1 WGI-OS (PTD #1900250) IA repressurization -Reclassified as Operable Page 1 of 2 Regg, James B (DOA) • From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.comj ~~~~ Q 13~I ~~ Sent: Wednesday, April 30, 2008 11:01 AM l J To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; GPB, FS1 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor Cc: Winslow, Jack L.; NSU, ADW WI Tech; Senden, Leslie B; NSU, ADW Well Integrity Engineer Subject: WGI-05 (PTD #1900250) IA repressurization -Reclassified as Operable All, Well WGI-05 passed an AOGCC witnessed MITIA on 04!27/08. The passing MITIA proved the tubing, production packer and production casing competent to liquid. Therefore, the well is Operable per the Well Integrity System Policy. An Administrative Approval (AA) request has been submitted to the AOGCC for continued injection with IA repressurization to comply with AOGCC Area Injection Order 4E. The well has been reclassified as Operable. Notification will be sent to Operations upon receipt of AA. if approval is not granted, the well will be shut-in and secured. Please call with any questions or concerns. Thank you, ~~~r~;6~NE~ MAY ~ 2 20a~ Andrea Hughes From: NSU, ADW WeII Integrity Engineer Sent: Wednesday, April 09, 2008 3:45 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, Area Mgr East (FSl/2/COTU/Seawater); GPB, FSl OTL; GPB, FSl DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor Cc: NSU, ADW Well Integrity Engineer; Winslow, Jack L.; NSU, ADW WI Tech; Senden, Leslie B Subject: UNDER EVALUATION -WGI-05 (PTD #1900250) IA repressurization Jim, Well WGI-05 (PTD #1900250) has recently shown an increase in IA pressure. DHD bled the IA pressure from 1160 psi to 500 psi on 04/07/08. The well passed an AOGCC witnessed MITIA on 02/12/08. Our plan is to leave the well on injection for further diagnostics. The plan forward on the well is as follows: 1. D: Monitor IA pressure build up rate 2. S: Troubleshoot SSSV 3. WIC: Eval for AOGCC Administrative Approval request A wellbore schematic, TIO plot and injection plot have been included for your reference. Please call with any questions or concerns. Thank you, 4/30/2008 �1 / A � ALL' ..�':� � � �� SARAH PALIN, GOVERNOR AIL&SKAL OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CO N SER VATION COMUSSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 ADMINISTRATIVE APPROVAL 4E.031 Mr. Steve Rossberg Wells Manager BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 RE: PBU WGI -05 (PTD 1900250) Request for Administrative Approval Prudhoe Bay Oil Pool Dear Mr. Rossberg: Pursuant to Rule 9 of Area Injection Order ( "AIO ") 04E.000, the Alaska Oil and Gas Conservation Commission ( AOGCC or Commission) hereby grants BP Exploration (Alaska) Inc. (BPXA)'s request for administrative approval to continue gas injection in the subject well. AOGCC finds that BPXA has elected to perform no corrective action at this time on PBU WGI -05. The Commission further finds that the well demonstrates inner annulus (IA) repressurization that can be safely managed with periodic pressure bleeds. Outer annulus pressures do not indicate anomalous conditions or loss of pressure integrity. The Com- mission believes that the well's condition does not compromise overall well integrity so as to threaten the environment or human safety, if the welI's operation is subject to the constraints enumerated below. AOGCC's administrative approval to continue gas injection in PBU WGI -05 is condi- tioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures and injec- tion rates, and shall flag the well's periodic pressure bleeds on the report; 3. BPXA shall perform an MIT - IA every 2 years to the maximum anticipated in- jection pressure; 4. BPXA shall limit the well's IA operating pressure to 2500 psi; AIO 4E.031 June 9, 2008 Page 2 of 2 5. BPXA shall install, operate and maintain remote pressure monitoring equipment on the well's IA; an alarm set point of no higher than 2000 psi shall be maintained to allow for time to respond and bleed pressure from the IA; 6. BPXA shall immediately notify the AOGCC and shut in the well if there is any continued deterioration in well integrity, indicated by increased inner or outer an- nulus pressure, increased repressure rate, or increased bleed frequency; 7. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and 8. The MIT anniversary date is April 27, 2008. DONE at Anchorage, Alaska and dated June 9, 2008. Cathy . Foerster J or n Co ssioner Comm e ANA cc: BPXA Well Integrity Coordinator, PRB -20 z P.O. Box 196612 v Anchorage, AK 99519 -6612 P RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of re- consideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Com- mission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by in- action, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on re- consideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on re- consideration. As provided in AS 31.05,080(b), "[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the pe- riod; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. • . Page 1 of 2 Maunder, Thomas E (DOA) From: NSU, ADW Well Integrity Engineer [ NSUADWWellintegrityEngineer @BP.com] Sent: Tuesday, May 27, 2008 5:55 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSU, ADW Well Operations Supervisor; NSU, ADW Well Integrity Engineer; Engel, Harry R; Senden, Leslie B Subject: RE: PBU WGI -05; NGI -05 Admin Approval Requests Jim, Topic 1: A review was completed by the Facility Engineer and Lead Operator to discuss the likely chain of events if an automatic shut -in occurred on a gas injector supplied through the Central Compression Plant and is summarized in the following paragraph. Though, installing annular automatic shut -in equipment set to trip above normal operating limits and below casing burst ratings provides a level of protection to the well and its immediate vicinity, an unplanned shut -in on any gas injector would initiate a sequence of events requiring reactive measures by operations, field wide, to control facility over pressurization. After an automatic shut -in on a gas injector, Central Compression Plant gas compressors would immediately exhibit increased discharge pressures. Managing these pressures would require a rapid reduction in the volume of gas entering the compression facility by cutting rate from gas supplying facilities. If discharge pressures reach a sufficient level the compressors' high pressure shutdowns trip. At this point the entire gas injection system, including common lines and facility gas systems, begins to increase in pressure. To manage the pressurization and incoming gas rates, facilities would begin to flare gas and shut -in entire pads /drill sites. Topic 2: When a well on AGI, NGI, or WGI -Pad has been found with IA repressurization, one of the first diagnostic steps is to troubleshoot the SSSV. On NGI -05 the SSSV was reset on 04/28/08 and on WGI -05 the SSSV was reset on 04/29/08. In both cases, slow TxIA communication still exists thus bringing us to request an AA. Topic 3: The minor OA repressurization trend could be due to thermal effects related to the TxIA communication. However, more diagnostic work is required because there was no report of a bleed in April. Our plan is to bleed the OAP to 0 psi and monitor the build up rate. Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659 -5102 Pager: (907) 659 -5100 x1154 From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Thursday, May 15, 2008 4:31 PM To: NSU, ADW Well Integrity Engineer Cc: Maunder, Thomas E (DOA) Subject: PBU WGI -05; NGI -05 Admin Approval Requests Both requests include wording to the effect that requiring auto shut in capability tied to the annulus pressure represents a hazard. Do you have something ,mate substantial to provide the Commission other than the 3 CQ �V `C N 12/21/2010 • • Page 2 of 2 sentences in your requests that tell us you've reviewed and came to some conclusion? Otherwise, I have nothing to corroborate your statements, and as I have mentioned in past emails, our decision has to be made on the facts provided in the application (and what we have on file, which is not much related to process flow and overpressure protection). Perhaps you have some sort of hazop or similar that could be provided? It seems to me from similar concerns with other injectors at AGI, NGI, WGI that the TxIA communication is directly linked to the SSSV (I believe I have seen statements about gas injection drying seals). At what point do you attempt a repair (reseat SSSV, install new SSSV, etc.)? Has there been any attempt to make repairs on these 2 wells? Also, looking at the NGI -05 TIO plot, there is an increasing OA pressure beginning in February, with what I would interpret a pressure bleed event sometime in April. Please provide some discussion about this in your response. �I Jim Regg AOGCC I 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 12/21/2010 RECEIVED APR 3 0 2008 b BP Exploration (Alaska) Inc. Alaska Oil & Gas Cons. Commission p Attn: Well Integrity Coordinator, PRB -20 Anchorage Post Office Box 196612 Anchorage, Alaska 99519 -6612 (> April 29, 2008 Mr. Dan Seamount, Chairman Alaska Oil and Gas Conservation Commission 333 West 7 1 Avenue Anchorage, Alaska 99501 Subject: Prudhoe Bay well WGI -05 (PTD #1900250) Request for Administrative Approval: Continued Gas Injection Operations Dear Mr. Seamount, BP Exploration (Alaska) Inc. requests approval for continued gas injection operations into Prudhoe Bay well WGI -05. i Well WGI -05 exhibits inner annulus re- pressurization and is safely managed by periodic inner annulus bleeds. The tubing and production casing are competent barriers as indicated by a mechanical integrity test of the inner annulus to 4,480 psi. BP will continue to monitor and record wellhead pressures daily. We will also install remote pressure monitoring equipment on the inner annulus. In the event that IA pressure exceeds BP's maximum allowable annular pressure of 2,000 psi, operations will receive an alarm. This engineering control adds a level of protection and allows operations to actively manage gas rates in the event the well needs to be shut -in. BP has reviewed installing automatic shut -in equipment on dedicated, large volume gas injection wells and has concluded this is not a safe option. An automatic shut -in situation would create the potential for over pressure conditions at several facilities. This could lead to a major flare event at the gas plants and require entire drill sites to be shut down. In summary, BPXA believes Prudhoe Bay well WGI -05 is safe to operate as stated above and requests administrative approval for continued gas injection operations. If you require any additional information, please contact me at 564 -5637 or Anna Dube / Andrea Hughes at 659 -5102. Sincerely, R. Steven Rossberg Wells Manager, BPXA I • I Attachments: Technical Justification TIO Plot Injection Plot Wellbore Schematic Cc: Bixby /Olsen Dube /Hughes East Area Manager Leslie Senden Harry Engel Janice Vosika Prudhoe Bay Oil Pool well WGI -05 Technical Justification for Administrative Approval Request April 29, 2008 Well History and Status Prudhoe Bay well WGI -05 (PTD #1900250) exhibits manageable inner annulus repressurization indicated by wellhead pressure trends on a TIO plot. A MIT -IA to 4480 psi passed on 4/27/08 indicating competent tubing and production casing. Recent Well Events: • 04/09/08: Notified AOGCC of IAP increase • 04/20/08: PPPOT -T Passed to 5,000 psi. PPPOT -IC Passed to 3,500 psi. • 04/24/08: Set TTP @ 7848' • 04/25/08: MITT Passed to 2000 psi • 04/27/08: AOGCC MIT -IA Passed to 4480 psi Barrier Evaluation The primary and secondary barrier systems consist of tubing and production casing and associated hardware. A pressure test of the inner annulus passed to 4480 psi, demonstrating competent primary and secondary barrier systems. I Proposed Operating and Monitoring Plan 1. Record wellhead pressures and injection rate daily. 2. Install remote pressure monitoring equipment. 3. Submit a report monthly of well pressures and injection rates to the AOGCC. 4. Perform a 4 -year MIT -IA to maximum anticipated injection pressure. 5. The well will be shut -in and the AOGCC notified if there is any change in the wells mechanical condition. 4,000 - WGf -05 TIO Plot t Tbg 3,000 IA 2,000 I MA. s P — -- - -- -- k OA I I t I 1,000 A M ASP OOA OOOA 0 412812007 61282007 8128!2007 10128/2007 121282007 212712008 412812008 GasiMGIiPW1 +DLW SVA, MCFD,BVVPD 4. 0 30,000 60,000 90,000 120,000 150,000 180,000 210,000 240,000 270,000 300,000 v vI z co c b t!1 �. ^� O v H d W Q N A p c S O , N o � o m • 0 1,000 2,000 9 000 4,000 61sd `dIHM G^V I TREE = 6 -318" CAMERON WELLHEAD= CA MERON �� SAFETY NOT ACTUATOR = BAKER KB EL . EV _.. 61, BF. ELEV = ? KOP = _ p Max Angle = 1 @ 8300' Datum W®= WA DatumTVD= 8800'SS 13 -3/8" CSG, 68 #, L -80 (01/02 /04), ID = 12.415" 99' 1 , �,4 9 -5/8" CSG, 47 #, NT-95 (01/08/04) ID = 8.681" 741' 9 -518" CSG, 47 #, L -80 (01/08/04), ID = 8.681" 2030' 2226' 7" CAMCO DB NIP, ID = 6. 00" 7" TBG -TCII, 26 #, L-80_0383 bpf, ID = 6.28" 2237' 2237' 7" x 7 - xo, 11D = 6.28- 13 -3/8" CSG, 68 #, L -80, ID = 12.415" 3494' Minimum ID = 4.455" @ 7848' 5 -1/2" HES XN NIPPLE 7 -5/8" TBG -IPC, 29.7 #, L-80,.0459 bpf, ID = 6.88" 7757' 776y' 7" CAMCO R N�', ID = 5.963" 7790' 7" K -22 ANCHOR SEAL ASSY, ID = 6.00" 7791' 9 -5/8" X 7" SAB-3 HYRO -SET PKR ID = 6.00" 7" TBG -TC•tl, 26#, L-80_0383 bpf, ID = 6.28" 7$06' 7806' 7" X 5 112" XO, = 4.86" 7817' TOP OF 7" LNR 7849' 7848' 5 -112" HES XN N F', ID = 4.455" 5 -1/2" TBG- TC•II, 17 #, L -80, .0232 bpf, K) = 4.89" 7$70' 7870' 5 -1/2" TUBING TAL W /MULE SHOE 9- 518" CSG, 47 #, L -80, ID = 8.681" $164' PERFORATION SUMMARY REF LOG: SWS CET ON 03/06/90 ANGLE AT TOP PERF: 1 @ 8184' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 3 -318" 4 8184-8220 O 06/04190 3 -3/8" 4 8274-8306 O 06/04/90 3 -318" 4 8319-8346 O 06/04/90 3 -3 /8" 4 8348-8476 O 06/04/90 3 -3/8" 4 8484-8518 O 06/04/90 3 -318" 4 8522-8542 O 06/04/90 3 -318" 4 8554-8613 O 06/04/90 3 -3/8" 4 8620-8633 0 06/04/90 8650' CTM TOP OF FILI (01125/04) PBTD 8686' 7" LNR, 29 #, L-80,.0371 bpf, ID = 6.184" 8728' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03/02190 ORIGINAL COMPLETION WELL: WGI-05 01/16/04 SRBlTLH RIND PERMIT No: 1900250 05/31/06 DTM WELLHEAD CORRECTION API No: 50- 029- 22015 -00 08/07/07 DSM/SV TREE GO SEC 11, T11 N, R14E, 1077.09' FR & 1102.97' FNL BP Exploration (Alaska) NGI-OS (PTD #1760140) and WGI-OS (PTD #1900250) MIT Forms Page 1 of 1 Regg, James B (DOA) • • From: NSU, ADW Weil Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent:. Tuesday, April 29, 2008 7:01 AM ~Q ~ Q (Zg'~~ To: Regg, James B (DOA); Maunder, Thomas E (DOA); Fleckenstein, Robert J (DOA) Cc: NSU, ADW Weil Integrity Engineer; NSU, ADW WI Tech; Senden, Leslie B Subject: NGI-05 (PTD #1760140) and WGI-05 (PTD #1900250) MIT Forms Attachments: MIT PBU NGI-05 04-26-08.x1s; MIT PBU WGI-05 04-27-08.xis Jim, Tom and Bob, Please see the attached MIT forms for the MIT-IA's performed on NGI-05 (PTD #1760140) and WGI-05 (PTD #1900250). The tests were performed for AA application. The AA requests will follow. «MIT PBU NGI-05 04-26-08.x1s» «MIT PBU WGI-05 04-27-08.x1s» Please call with any questions or concerns. Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 ~~~ ~~E~ M~,Y ~ ~. ZOD8 4/29/2008 STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: BP Exploration (Alaska), Inc. FIELD /UNIT /PAD: Prudhoe Bay /PBU /WGI-Pad ~ I ~t4 J~j/~ DATE: 04/27/08 ~Gi~ ~' I (, OPERATOR REP: Andrea Hughes AOGCC REP: Packer Dep Pretest Initial 15 Min. 30 Min. Well WGI-OS Type Inj. N TVD 7,791' Tubing 1920 2380 2380 2350 Interval O P.T.D. 1900250 Type test P Test psi 4450 Casing 80 4480 4480 4480 P/F P Notes: MIT-IA for AA Request OA 0 0 0 0 Witness declined by Chuck Scheve. Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastev/ater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 9/1105 MIT PBU WGI-OS O4-27-08.x1s UNDER EVALUATION -WGI-OS (PTD #1900250) IA repressurization • Page I of 1 Regg, James B (DOA) • From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.comJ ~ Q ~Z91~' Sent: Wednesday, April 09, 2008 3:45 PM ~~~ To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; GPB, FS1 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor Cc: NSU, ADW Well Integrity Engineer; Winslow, Jack L.; NSU, ADW WI Tech; Senden, Leslie B Subject: UNDER EVALUATION -WGI-05 (PTD #1900250) IA repressurization Attachments: WGI-05.pdf; WGI-05 TIO PIot.BMP; WGI-05 Injection PIot.BMP Jim, Well WGI-05 (PTD #1900250) has recently shown an increase in IA rp essure. DHD bled the IA pressure from 1160 psi to 500 psi on 04/07/08. The well passed an AOGCC witnessed MITIA on 02/12/08. Our plan is to leave the well on injection for further diagnostics. The plan forward on the well is as follows: 1. D: Monitor IA pressure build up rate 2. S: Troubleshoot SSSV ~-- 3. WIC: Eval for AOGCC Administrative Approval request A wellbore schematic, TIO plot and injection plot have been included for your reference. «WGI-05.pdf» «WGI-05 TIO PIot.BMP» «WGI-05 Injection PIot.BMP» Please call with any questions or concerns. Thank you, ,~nntx I~u6e, ~'.~E. Well Integrity Coordinator GPB ells Group Phone: (907} 659-5'IC32 Pager: {9Q7) 659-5100 x1154 ~~~~E~ MAY ~ ~ 200E 4/29/2008 ~,oaa -~- Tb~ 3,aoa ~- fA i.'.. MAASP' ~,aaa ~ a~ 1 ,aoa tJ~. h,~~~,SF OOA a Lw.L Lia•~.LLd LLI.i L •L• iil iLaL~.-~~-~iLLLLil 41L LiiL iL_i 1 rrr~aas 1 ~12~oos 2~sr~aas 221 boas 317f2oas sr~2r aos ~3fT ~2oa$ ~rzarzaos ~- 00~ • a aaa'tr *.. 0 .~ ~a O .~ t17 + _ ~4v{~ .SIP, p~i~ oao' E aaa` ~ ooo' ~ ti v 0 ti 0 0 a 0 a00' o8Z Oaa' a 6Z Oaa' atr 6 Oaa' aL 0 ~ • c+~ d C7 a a Q Q a 0 0 ~ld~lti9 ~1~::-L~J 'V4lti~ INti47+IIVtid I~-L"J; ~-"f TREE= 6-3'8" CAMERON WELLHEAD = __ ___.. CAMERON ACTUATOR = BAKER KB. ELEV = 61' BF. ELEV = ? KOP =_____ ~r>ax Angie = ~ 0' 1 @ 8300' Datum ~v1D = NIA Datum TV D = 8800' SS 13-318" CSG, 68#, L-80 {01!02!04), ID = 12.415" ~ 99' 9-5(8" CSG, 47#, NT-95 {01/08!04}, ID = 8.681" 741' 9-5,`8" CSG. 47#, L-80 (01108(04}, ID = 8.881" 2030' 7" TBG-TCII, 26#, L-80; .0383 bpf, ID = 6.28" 2237" 13-318" CSG, 68#, L-80, ID = 12.415" 3494' Minimum Id = 4.455'" @ 7848' 5-112'" HES XiV iV1PPLE 7-5/8°' TBG-IPC, 29.7#: L-80, .0459 bpf< ID = 6.88" 7757' 7" TBG-TCII, 26#, L-80, .0383 bpf, tD = 6,28" TOP OF 7" LNR (-~ 7$49 5-112'° TBG-TG[I: 17#, L-80, .0232 bpf, #D = 4.89" 7$70' 9-518'° CSG, 47#, L-80, 1D = 8.681" -~' PERFORATION SUPAMARY REF LOG: SLNS CET ON 03106/90 ANGLE AT TOP PERF: 1 ~ 8184' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-31'8" 4 8184 - 8220 O 46/04/90 3-31'8`° 4 8274 - 8306 O 06104/90 3-3I8" 4 8319 - 8346 O O6/04/90 3-3I8" 4 8348 - 8476 O 06/04/90 3-3l8" 4 8484 - 8518 O 06/04;`90 3-318" 4 8522 - 8542 O 06/04190 3-318" 4 8554 - 8613 O 06/04190 3-3!8'" 4 8620 - 8633 O 06/04/90 PBTD -( 8686, 7" LNR, 29#, L-80, .4371 bpf, ID = 6.184" $'72$' 's ~ SAFEi~TES: I n $650' CTM I~TOPOF FILL (01,•'25104] 2214' --~ 7-518" X 7" XO; ID = 6.28" 2226' 7" CAMCO DB NIP, ID = 6.00" 2237' 7" X 7-5!8" XO, ID = 6.28" 7757' ~ 7-5/8" X 7" XO, ID = 6.28" 7769' 7" CAMCO R NIP; ID = 5.963° 7790' 7" K-22 ANCHOR SEAL ASSY, ID = 6.00" 7791' 9-518" X 7" SAB-3 HY RO-SET PKR, !D = 6.00" 7806' 7" X 5-112" XO, ID = 4.86" 7817' S-1.•'2" HES X NIP, ID = 4.56" 7$4$' S-1 i2" HES XN NIP, ID = 4.455" 7$7{1' S-1;2" TUBING TAIL VVIMULE SHOE DATE REV BY COMMENTS 03/02190 t7RIGINAL CAMPLETtON 01116104 SR8ITLH RWO .~ 05!31!06 DTTv1 WELLHEAD CORRECTION 08;07107 DSMiSV TREE CIO TE COMMENTS PRUDHOE BAY UNIT WELL: WGI-05 PERMIT No: 1900250 API No: 50-029-22015-00 SEC 11, T11N, R14E, 1077.09' FEL & 1102.97' FNL BP Exptoratlon {Alaska) Recent MITIAs for 11-38A (PTD~982160), R-03A (PTD #1981710), W~OS (PTD #1900250) Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWe111ntegrityEngineer@BP.com] ~~ t9 ~~~~~ Sent: Sunday, February 17, 2008 6:41 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Fleckenstein, Robert J (DOA) Cc: NSU, ADW Well Integrity Engineer; NSU, ADW WI Tech Subject: Recent MITIAs for 11-38A (PTD #1982160), R-03A (PTD #1981710), WGI-05 (PTD #1900250) Follow Up Flag: Follow up ~ p/ O .. ~ ~~ Flag Status: Red ~ "~ Attachments: MIT PBU 11-38A 02-12-08.x1s; MIT PBU R-03A 02-12-08.x1s; MIT PBU WGI-05 02-12-08.x1s Hi Jim, Tom, and Bob, Please find the attached MITIA forms for 11-38A (PTD #1982160), R-03A (PTD #1981710), and WGI-05 (PTD #1900250). 11-38A: 2-year MITIA for UIC compliance of a monobore injector R-03A: 4-year MITIA for UIC compliance and qualification for MI service ~/VGI-05: 4-year MITIA for UIC compliance «MIT PBU 11-38A 02-12-08.x1s» «MIT PBU R-03A 02-12-08.x1s» «MIT PBU WGI-05 02-12-08.x1s» Please let us know if you have any questions. Thank you, nnrx 1~u6e, ~'. E. Well Integrity Coordinator ~~ ~E~ ~ ~a~~ GB Wells Group Phone: (907) 659-5102 Pager: (9177} 659-51(}0 x1154 2/20/2008 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: FIELD /UNIT /PAD DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay / PBU /WGI 02/12!08 ~~~ 1 ~~~ ~0~~ Anna Dube Packer De th Pretest Initial 15 Min. 30 Min. Well WGI-O5 Type Inj. G TVD 7 791' Tubing 3700 3680 3640 3620 Interval 4 P.T.p. 1900250 Type test P Test psi 1948 Casing 1010 150 2090 2070 P/F P Notes: 4-year UIC Compliance MITIA OA 10 10 10 10 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPEINJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test o~`' ~%J INTERVAL Codes f =Initial Test 4 =Four Vear Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 9/1/05 MIT PBU WGI-OS 02-12-08.x1s MEMORANDUM State of Alaska TO: Alaska Oil and Gas Conservation Commission THRU: Jim Regg P.I. Supervisor Z\\~\OA- Ke{tt DATE: Wednesday, February 18,2004 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC WGI-05 PRUDHOE BAY UNIT WGI-05 FROM: Jeff Jones Petroleum Inspector Src: Inspector NON-CONFIDENTIAL API Well Numbe 50-029-220 I 5-00-00 InspN mitlJ040216095156 Inspection Date: 2/1 5/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well: WGI-05 Type Inj. G TVD 7791 IA 700 2120 2100 2080 2080 P.T. 1900250 TypeTest SPT Test psi 1947.75 OA 0 0 0 0 0 Interval Post Workover Test P/F Pass Tubing 3500 3500 3550 3560 3560 Notes: 1.5 BBLS diesel pumped. Monitored IA additional 15 min. to further demonstrate stabilization. Type INJ. Fluid Codes F =FRESH WATER INJ. G=GAS INJ. S=SALT WATER INJ. N=NOT INJECTING Type Test M=Annulus Monitoring P=Standard Pressure Test R=lntemal Radioactive Tracer Survey A=Temprature Anomaly Surve D=Differential Temprature Test Interval 1=lnitial Test 4=Four Year Cycle. V=Required by Variance W=Test during Workover O=Other (describe in notes) Wednesday, February 18,2004 Page 1 of 1 ~Ct\M~NE[J; MJ'R 1 2 2004 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: 0 Abandon 0 Suspend 0 Operation Shutdown 0 Perforate 0 Waiver 0 Other 18:1 Alter Casing 18:1 Repair Well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 ChanQe Approved ProQram 18:1 Pull TubinQ 0 Perforate New Pool 0 Re-Enter Suspended Well 0 Annular Disposal 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. D Development D Exploratol) 190-025 3. Address: D Stratigraphic Test iii Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22015-00-00 7. KB Elevation (ft): RKB = 61' 9. Well Name and Number: PBU WGI-05 8. Property Designation: 10. Field / Pool(s): ADL 028302 Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 8728 feet true vertical 8728 feet Plugs (measured) None Effective depth: measured 8686 feet Junk (measured) None true vertical 8686 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1530 520 Surface 34941 13-3/8" 3494' 3494' 4930 2270 Intermediate 81641 9-5/8" 8164' 8164' 6870 4750 Production Liner 879' 7" 7849' - 8728' 7849' - 8728' 8160 7020 Perforation Depth MD (ft): 8184' - 8633' Perforation Depth TVD (ft): 8184' - 8633' Tubing Size (size, grade, and measured depth): 7-5/8",29.7# x 7",26# x 5-1/2", 17# L-80 7870' Packers and SSSV (type and measured depth): 9-5/8" x 7" 'SABL-3' packer; RECEIVE~~: 7" Camco 'DB' Nipple 12. Stimulation or cement squeeze summary: FEB 1 0 2004 Intervals treated (measured): Alaska Oil & Gas Cons. Commission Treatment description including volumes used and final pressure: Anchorage 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casina Pressure Tubina Pressure Prior to well operation: 254,905 3,589 Subsequent to operation: 280,543 3,697 14. Attachments: D Copies of Logs and Surveys run 15. Well Class after proposed work: B Daily Report of Well Operations D Exploratory D Development Ia Service B Well Schematic Diagram 16. Well Status after proposed work: DOil DGas DWAG IiIGINJ OWINJ 0 WDSPL 17. I hereby certify that the foregoing IS true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 303-329 Printed Name Terrie Hubble Title Technical Assistant Signature ~l\~..I~ Phone' Date O~~/O'l Prepared By Name/Number: . . 564-4628 Terrie Hubble, 564-4628 Form 10-404 Revised.12@QOt'F.B 1 3 2004 AL rø:tMS Bfl FEB 1,' ~\GANN [j,' ., - I.. ,~. .. OR\G\N Well: Field: API: Permit: WGI-05, Rig Workover Prudhoe Bay Unit 50-029-22015-00-00 190-025 I 303-329 Accept: Spud: Release: Rig: 12/20/03 N/A 01/15/04 Nabors 4ES PRE-RIG WORK 11/25/03 PULLED 7" DSSSV @ 21781 SLM. RAN 4 1/2" EQ PRONG TO 7826' SLM. PULLED 4 1/2" XXN PLUG @ 78261 SLM. TAGGED BTM @ 86431 SLM, (8669' CORRECTED). TUBING PUNCH. SHOOT 21 - 1.56" 20 ES HNS TUBING PUNCHER - 4 SPF FROM 782511-7821' - DEPTH REFERENCED TO SLB PERF REC DATED 1/03/1990. DID NOT TAG TD. 11/29/03 T/I/O=2760/1450/1150. PUMP SIZED SALT PILL. (PREP FOR RWO). PUMP 450 BBLS 1% KCL @ 15 BPM, PUMP 50 BBL HI-VIS PILL @ 7.5 BPM, PUMP 85 BBLS SIZED SALT PILL (PUMPED EXTREMELY HARD) UNABLE TO GET ALL SALT IN ON THE FLY (ADDED 1050# PLUGSAL X AND 2200# DOWELL ROCK SALT), PUMPED 25 BBLS HI-VIS FOLLOWED BY 85 BBLS 10# HEC WI 12,800# NACL. DISPLACE W/ 20 BBLS 2% KCL AND 72 BBLS 60/40. WELL ON VAC DURING DISPLACEMENT. EST 8 BBLS BEHIND PIPE (WHEN PRESSURE STARTED TO INCREASE). PRESSURED UP TO 1000 PSI. CONTINUE RE-PRESSURE UNTIL IT TOOK.2 BPM TO GAIN 1000 PSI. RDMO. FINAL WHp1S=660/1000/500. 12/02/03 DRIFTED AND TAGGED DOWN TO SALT @8561' SLM, 8581' CORRECTED MD. LOCATED TUBING TAIL @7838' SLM. 7864' MD (CORRECTED DEPTH IS 261 DIFFERENCE). 12/06/03 TIIIO = 660/860/40, TEMP = SI. CLEAN THREADS AND HANG UNION ON CONDUCTOR, TUBING AND IA FLS FOR COIL. CLEANED THREADS AND HUNG UNION. TUBING FL @ 210'. IA FL @ 305'. 12/10/03 . PERFORM WEEKLY BOP TEST. BLEED GAS OFF IA. FP IA WITH 10 BBLS MEOH. RIH WITH 10# NACL. SET DOWN AT 81531. SOLID TAG WITH 3000# DOWN. (WINDOW FOR SALT 8050-8150') LINE UP AND PUMP 7 BBLS 15.8 PPG CLASS G CEMENT. DISPLACE WITH FRESH WATER. 12/11/03 SI/100/50. BLEED TBG X IA X OA (PRE RWO). BLED lAP FROM 100 PSI TO 40 PSI; BLED OAP FROM 50 PSI TO 0+ PSI. COULD NOT GET TBG PRESSURE FROM P- SUB AT THIS TIME. LAY IN CEMENT. TOC ESTIMATED AT 7964 CTMD (CEMENT WINDOW: 7900 - 8000'). BBL CHECK. SHOWS 1:1 RETURNS. HOLD 200 PSI ON WELL AND POH PUMPING 60/40 MEOH. FREEZE PROTECT WELL FROM 2000 WITH 60/40 MEOH. TRAP 200 PSI ON WELL. RDMO. 12/13/03 . TIO= 300/80/10. BLEED WHPS (PRE RWO). BLED TBG FROM 300 PSI TO 0+ PSI IN 45 MINS, TBG FL NEAR SURFACE, BLED lAP FROM 80 PSI TO 0+ PSI IN 1 HR, IA FL NEAR SURFACE. BLED OAP FROM 10 PSI TO 0+ PSI IN 15 MINS, OA FL @ SURFACE. SI BLEEDS AND MONITOR FOR 30 MINS, NO CHANGE IN PRESSURES. FINAL WHPS= 0+10+10+. WGI-05, Rig Workover Page 2 12/16/03 T/I/O 2201010. MIT TBG (PRE-RWO) TO 1500 PSI. PASSED ON 1ST ATTEMPT. PRESSURED UP TBG WI 3 BBLS DIESEL TO 1500 PSI. 1ST 15 MINS LOST 50 PSI. AND 2ND 15 MINS LOST 10 PSI FOR A TOTAL OF 60 PSI. 30 MINS. BLEED OFF TBGP. FWHP 150/010. 12/17/03 T/I/O= SI/OIO PRE- RIG WELLHEAD MIT PPPOT-T PASSED. TEST TUBING HANGER VOID TO 5000 PSI. 30 MINUTES. LOST 200 PSI IN 30 MIN. CYCLE ALL LDS ON TUBING SPOOL. NO SIGNS OF ANY BENT OR BROKEN LDS. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: BP EXPLORATION Operations Summary Report WGI-05 WGI-05 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Date From- To Hours Task Code NPT Phase I ... .. 12/18/2003 01 :00 - 03:30 2.50 MOB P PRE 03:30 - 08:00 4.50 MOB P PRE 08:00 - 11 :00 3.00 MOB N WAIT PRE 11 :00 - 13:00 2.00 MOB P PRE 13:00 - 15:00 2.00 MOB N WAIT PRE 15:00 - 20:30 5.50 MOB P PRE 20:30 - 00:00 3.50 MOB N WAIT PRE 12/19/2003 00:00 - 23:00 23.00 MOB N WAIT PRE 23:00 - 00:00 1.00 MOB P PRE 12/20/2003 00:00 - 03:00 3.00 RIGU P PRE 03:00 - 06:00 3.00 WHSUR P DECOMP 06:00 - 07:30 1.50 WHSUR N SFAL DECOMP 07:30 - 08:00 0.50 WHSUR P DECOMP 08:00 - 08:30 0.50 WHSUR P DECOMP 08:30 - 10:00 1.50 WHSUR P DECOMP 10:00 - 13:00 3.00 WHSUR P DECOMP 13:00 - 19:30 6.50 BOPSUF P DECOMP 19:30 - 00:00 4.50 BOPSUF P DECOMP 12/21/2003 00:00 - 01 :00 1.00 BOPSUR P DECOMP 01 :00 - 03:00 2.00 BOPSUR P DECOMP 03:00 - 06:45 3.75 PERF P DECOMP 06:45 - 07:00 0.25 PERF P DECOMP 07:00 - 09:30 2.50 PERF P DECOMP 09:30 - 11 :00 1.50 PERF P DECOMP Page 1 of 15 Start: 12/19/2003 Rig Release: 1/15/2004 Rig Number: 4ES Spud Date: 2/16/1990 End: 1/15/2004 Descri ptionofOperations PJSM. Scope down derrick & layover. Prep rig components for move. PJSM with all parties involved. Move camp & rig to Milne Point turn off @ spine road. Nabors rig 3S moving from Kuparuk to Frontier Yard, security escorting same. Wait for Security to return from escorting 3S. Continue to Kuparuk River Bridge. Wait for gravel & matting boards to be laid down for rig move to negotiate Kuparul River Bridge area. Continue moving rig to WGI pad via K Pad access road. Well House unable to be removed due to prevailing winds that have been ongoing for last 7 days or more. Rig on Standby. Note: Stand by time started @ 15:30 hours, 12/18/2003. (20:30 hours minus 5 hours wait time during move as noted in time summary). 49 mile move. Continue to Stand By with rig, waiting on wind to subside so well house can be removed. Move rig over wellhead and begin to assemble modules. Rig up Nabors 4 ES. Accept rig at 0300 hours. Spot & rig up lines to tiger tank. P/U lubricator, pull BPV. 1450 psi on tubing. master valve leaking. Rig up to bleed pressure to tiger tank. Call for grease crew. Grease & operate master valve. Close hydraulically operated surface valve. LID lubricator. Pressure test lines to 2500 psi, OK. Pre well meeting with the day crew. Discuss overview of well. Emphasis on taking each step, one at a time. Emphasis on good well monitoring practices, good communication. PJSM. Line up on choke to tiger tank. O/A 0 psi, IIA 0 psi, 7" tbg 550 psi at the choke. Bleed off pressure, fluid back of a watery nature. Monitor well & call for 2 way check. Monitor well, no pressure. Well stable. Set two way check valve. PJSM. Nipple down tree. PJSM. Nipple up BOPE. Change out pipe rams to 7". Connect test lines to BOP. Pressure test BOP in presence of AOGCC rep. John Crisp. Pressure test all components @ 250/4000 psi, annular preventor @ 250 I 3500 psi. Pressure test BOP. Attempt to make up one joint 7" into tubing hanger to facilitate 7" pipe ram pressure test. Threads were galled in hanger. No 7" test spool available. Called 2ES for spool, none available. Discussed options with Anchorage office. Spool being manufactered by Baker Machine. Called out SWS wireline for tubing punch, string shot, and tubing cut. Rig up SWS wireline and Schlumberger spooler for control line retrieval. Pre job safey meeting. Emphasis on gun awareness, staying clear of rig floor while picking up & running & laying down gun. RIH wI ccl, gamma & perf assembly. Tie in & perforate (9) holes f/ 7740' -7742. Observe 150 psi increase on I/A. POOH wI perf assembly. Printed: 1/19/2004 9:46:32 AM BP EXPLORATION Page 2 of 15 Operations Summary Report Legal Well Name: WGI-05 Common Well Name: WGI-05 Spud Date: 2/16/1990 Event Name: WORKOVER Start: 12/19/2003 End: 1/15/2004 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/15/2004 Rig Name: NABORS 4ES Rig Number: 4ES Date From -To Hours Task Code NPT Phase Description of Operations .. . .... 12/21/2003 11 :00 - 12:00 1.00 PERF P DECOMP Rig down Schlumberger off to the side & rig up to circulate well. 12:00 - 14:30 2.50 KILL P DECOMP SITP = 0 psi. SICP = 300 psi. @ choke manifold. PJSM. Circulate 8.5 ppg seawater down tubing, taking returns up IIA, fluid returns, to tiger tank. 5 bpm @ 900 psi. 520 bbls pumped. 1:1 returns. 14:30 - 17:00 2.50 BOPSUF P DECOMP PJSM. Set 2 way check. MIU 7" test joint, X/Os & circ head. Pressure test 7" pipe rams @ 250 I 4000 psi, charted, OK. Pick up lubricator & pull 2 way check. Break down test joint. 17:00 - 19:00 2.00 PULL P DECOMP PJSM. Pick up double spear assembly, stab in 7" tubing, BOLDS. PIU weight 175K, released t0155K, then PIU to 250K to attempt to pull free from Baker Locator Seal. Pulled to 300K. Slacked off and released double spear and LD same. 19:00 - 22:30 3.50 PULL P DECOMP Confer with BP Anchorage. RU SWS, MU string shot. RIH wI string shot to to straddle 7772' (7758' - 7774'), middle of 7" tubing joint immediately above packer assemble. Fired string shot at 22:15 hours. 22:30 - 23:30 1.00 PULL P DECOMP POH wI W/L and rig down string shot tools. 23:30 - 00:00 0.50 PULL P DECOMP MU SWS 7" tubing chemical cutter assembly and start into well to make chemical cut @ 7772'. 12/22/2003 00:00 - 03:00 3.00 PULL P DECOMP RIH wI SWS chemical cutter to 7772' and fire cutter at 0240 hrs. Good response up E-line. 03:00 - 07:00 4.00 PULL P DECOMP POH wI chemical cutter, hanging up at collars on way out, working thru same. Thru SSSV & OOH, OK. Rig down Schlumberger E-Line Services. 07:00 - 09:00 2.00 PULL P DECOMP PJSM. RIH wI double spear assembly & engage 7" below tubing hanger. Pull to 205K & observe pipe pulling free. Up weight 185K. Pull hanger to floor, LID spear assembly & rig up control line spooling unit. 09:00 - 14:30 5.50 PULL P DECOMP POOH wI 7", 26#, L80, LTC Mod IPC tbg & (2) contollines. 55 jts laid down, recovered 55 stainless steel bands out of possible 59. Laid down 7" CAMCO BAL-O Nipple. Rig down spooler. 14:30 - 22:00 7.50 PULL P DECOMP POOH wI 7", 26#, LTC tbg. LID 195 joints and chemical cut joint: 18.55'. 22:00 - 00:00 2.00 PULL P DECOMP Clear rig floor; RID hydraulic tongs. 12/23/2003 00:00 - 02:00 2.00 BOPSUF P DECOMP Clear rig floor; change pipe rams to variable: 2.875" x 5"; set test plug; Make BOP body pressure test. 02:00 - 03:00 1.00 PULL P DECOMP MIU Baker Fishing Tools BHA for 7" tubing; 12,6-1/4" Drill Collars. 03:00 - 1 0:30 7.50 PULL P DECOMP RIH wI Baker BHA #2, DC's and 3-1/2" Drill Pipe, 230 jts. to spear 7" Seal Assembly, TOF @ 7772'. 10:30 - 11 :30 1.00 PULL P DECOMP PJSM. Establish parameters. Up wt = 135,000#, down wt = 140,000#. MIU head pin & bottom out @ 7769'. Top of 7" stub @ 7759'. Verify spears engaged with 65K overpull to 200K. Jar (3) times @ 200K with overpulls to 250K. Jar (1) time @ 225K & observe fish free up. Pick up & see weight bobbling for 8-10' to 150K, (seals pulling out). Lay down 1 jt & make up head pin & circulating hose. 11 :30 - 14:00 2.50 PULL P DECOMP PJSM. Circulate btms up @ 1000 psi; pumped 492 Bbls. 14:00 - 18:00 4.00 PULL P DECOMP TOH wI 3-1/2" DP, 6-1/4 DC, and BHA #2. 18:00 - 19:00 1.00 PULL P DECOMP LID BHA #2. Attempt to release fish from grapple unsuccessful; LID fish with spear. (Cut jt = 21.10'; XO = 2.05'; Printed: 1/19/2004 9:46:32 AM .. BP EXPLORATION Page 3 of 15 Operations. Summary Report Legal Well Name: WGI-05 Common Well Name: WGI-05 Spud Date: 2/16/1990 Event Name: WORKOVER Start: 12/19/2003 End: 1/15/2004 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/15/2004 Rig Name: NABORS 4ES Rig Number: 4ES I..... Date From - To Hours Task Code NPT Phase Descri ptionof Operations I.. ... ... 12/23/2003 18:00 - 19:00 1.00 PULL P DECOMP pup = 6.02'; seal section = 12.67') 19:00 - 20:00 1.00 PULL P DECOMP MIU BHA, Packer Milling Assy. Begin to RIH; hit obstruction @ 250'. Tried to lift up and lower, used 30K overpull to pull out. Aborted BHA; TOH. 20:00 - 21 :30 1.50 PULL X DPRB DECOMP LID Packer Milling Assy. and move 2 stds DC's aside. 21 :30 - 00:00 2.50 PULL X DPRB DECOMP MIU BHA #3, String Mill assembly to clean out to top of packer @ +1- 7800'. Obstruction @ 250'. Pick-up Kelly. 12/24/2003 00:00 - 01 :30 1.50 CLEAN X DPRB DECOMP Continue to work String Mill from 250-ft down to 285-ft. Hard reaming. Rotate at 50 RPMs. Weight on Mill 2 -4 K Circulate at 3 bpm/75 psi. Did not torque up even with full string weight stacked out on Mill. Fell through at 285-ft. Set back Kelly. 01 :30 - 02:30 1.00 CLEAN X DPRB DECOMP Continue RIH. Tagged hard again at 320-ft. Pick-up Kelly. Rotate at 50 RPMs. Weight on Mill again 2-4K. Circulate at 4 bpm/100 psi. Hard reaming down to 340-ft...then found stringers down to 468-ft. Fell through at 468-ft. 02:30 - 03:30 1.00 CLEAN X DPRB DECOMP Circulated wellbore clean. No solids in returns. Set back Kelly. 03:30 - 05:00 1.50 CLEAN X DECOMP Continued RIH with 8.50" String Mill down to 7,791-ft dpm (top of Liner) with no further problems. 05:00 - 08:00 3.00 CLEAN X DPRB DECOMP Mix and pumped a 20 bbls Hi-Vis Sweep. Circulated wellbore clean at 5.0 bpm/1000 psi. Total volume = 579 Bbls. 08:00 - 10:30 2.50 CLEAN X DPRB DECOMP TOH wI DP and BHA #3. 10:30 - 11 :00 0.50 CLEAN P DECOMP Bleed down OIA from 300 psi to 0 psi to Tiger Tank. 11:00-12:30 1.50 CLEAN P DECOMP Cut and slip drilling line (84'); adjust brakes. 12:30 - 13:30 1.00 CLEAN X DPRB DECOMP TOH wI DP and BHA #3. 13:30 -14:30 1.00 CLEAN P DECOMP LID BHA #3. 14:30 - 15:30 1.00 CLEAN P DECOMP MIU BHA #4 (Packer Plucker and Mill). 15:30 - 18:30 3.00 CLEAN P DECOMP TIH wI BHA #4 and 3-1/2" DP to 7760'. 18:30 - 21 :30 3.00 CLEAN P DECOMP PIU kelly and 10' pup joint, tag fill @7788.5'. PU/SO weight 140,000 Ibs. Pump 3 BPM at 5-600 psi; 6 BPM at 1050-1300 psi. Rotate 30 RPM and set down 2-15,000 Ibs. Pump Hi-Vis sweep. Tag TOP @ 7791'. 21 :30 - 00:00 2.50 CLEAN P DECOMP Mill wI BHA #4 at 4 BPM/700 psi, set down 2-5,000 Ibs, 2,500 Ib-ft torque 12/25/2003 00:00 - 05:00 5.00 FISH P DECOMP Milling on packer. Pieces of rubber, metal shavings and scale over shaker. 4 BPM at 500 psi, 30-60 RPM, 2,000-20,000 Ibs WOB. 7,000 Ib-ft of torque was maximum torque seen during milling ops. Up Weight and Down Weight = 145,000 Ibs; Rotating Weight = 138,000 to 140,000 Ibs. 05:00 - 06:00 1.00 FISH P DECOMP BHA #4 and milled packer stacked on top of 7" liner at 05:00 hours. Circulate bottoms up with a lead Hi-Vis sweep. 06:00 - 07:30 1.50 FISH P DECOMP Finished cleaning up Wellbore with a 40 bbl Hi-Vis Sweep at 5 bpm/850 psi. Returns were Scale and milled up Packer junk. 07:30 - 11 :30 4.00 FISH P DECOMP POOH with 3 1/2" Drill Pipe and BHA #4. 11 :30 - 13:30 2.00 FISH P DECOMP Stand back Collars. Lay down BHA #4. Lay down recovered Fish. Packer and Tail Pipe recovered complete. 13:30 - 14:00 0.50 FISH P DECOMP Clear and Clean Floor. 14:00 - 16:00 2.00 CLEAN P DECOMP Make up BHA #5 as follows: 81/2" Bit, 3 ea Junk Baskets, Bit Sub, Bumper Jar, Oil Jar, XO, 12 ea Drill Collars, XO. 16:00 - 18:45 2.75 CLEAN P DECOMP RIH with BHA #5 and 31/2" Drill Pipe. Tagged top of liner @ +1- 7849'. 18:45 - 21 :30 2.75 CLEAN P DECOMP Reverse circulate 20 Bbl Hi-Vis sweep and seawater for a total of 556 Bbls. 21 :30 - 00:00 2.50 CLEAN P DECOMP TOH wI BHA #5 and drill string. Printed: 1/19/2004 9:46:32 AM BP EXPLORATION Page 4 of 15 Operations Summary Report Legal Well Name: WGI-05 Common Well Name: WGI-05 Spud Date: 2/16/1990 Event Name: WORKOVER Start: 12/19/2003 End: 1/15/2004 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/15/2004 Rig Name: NABORS 4ES Rig Number: 4ES Date From-To Hours Task Code NPT Phase Descrjption otOperations .. 12/26/2003 00:00 - 00:30 0.50 CLEAN P DECaMP TOH wI 3-1/2" DP, BHA #5; Bit to drill floor at 0030 hours. 00:30 - 01 :00 0.50 CLEAN P DECaMP Lay down BHA #5 as follows: 8 1/2" Bit, 3 Junk Baskets, Bit Sub, Bumper Jar, Oil Jar, XO, 12 Drill Collars, XO. Stand aside 4 stands of Drill Collars. 01 :00 - 02:30 1.50 TA P DECaMP MU HES 9-5/8" Composite BP and running string, as follows: 9-5/8" FasDrill CBP, 9-5/8" FD Setting Sleeve, 9-5/8" FD Bridgeplug MST, Ported Sub, and 3-1/2 x 4-1/2 IF XO. Onsite machining required to fit CBP running neck into running sleeve. 02:30 - 06:00 3.50 TA P DECaMP TIH wI CBP, setting tool, and 246 jts 3-1/2" DP (78 stands and 12 singles). 06:00 - 06:30 0.50 TA P DECOMP Set HES Composite Bridge Plug #1 at 7,802-ft. Normal set. 06:30 - 07:00 0.50 TA DECOMP Pressure test BP at 3,000 psi/15 min and record on chart. Good test. Blow down test equipment. 07:00 - 08:30 1.50 TA P DECaMP Hold PJSM with All. Finish RU Dowell/Schlumberger Cementers. Pressure Test Lines @ 3000 psi. Pump Cement Plug as follows 10 bbl Fresh Water @ 2bpm/150 psi. 7.5 bbls Class "G" Cement @ 1.8 bpm/160 psi. 1 bbls Fresh Water. Displace with 48 bbls Sea Water @ 5bpm/875 psi. SD Pumps and leave -1 bbl of Cement inside Drill Pipe. RD Cementers. 08:30 - 09:00 0.50 TA P DECOMP Single down 5 jts of 3 1/2" Drill Pipe. 09:00 - 09:30 0.50 TA P DECOMP Bring Rig Pump on line and pump 2 bbls to clear Drill Pipe. Then Rev Circ Drill Pipe (1 1/2 Vol = 75 bbls). No Cement returns to surface. 09:30 - 11 :30 2.00 TA P DECOMP Single down 12 more Jts 31/2" Drill Pipe. Continue POOH standing back in Derrick (77 stds) 11 :30 - 12:00 0.50 TA P DECaMP Lay down Bridge Plug Running Tools and re-build for next Composite Bridge Plug run. 12:00 - 12:30 0.50 TA P DECaMP Make up HES 9 5/8" Composite Bridge Plug #2. 12:30 - 15:00 2.50 TA P DECaMP RIH with BP, Setting Tool, and 3 1/2" Drill Pipe (126 Jts). 15:00 - 15:30 0.50 TA P DECaMP Set BP at 4,007-ft. Normal set. 15:30 - 16:00 0.50 TA P DECaMP Pressure test BP at 3,000 psi/15 min and record on chart. Good test. Blow down test equipment. 16:00 - 17:00 1.00 TA P DECaMP R/U, reverse 40 Bbls diesel into annulus. BID lines. 17:00 - 18:00 1.00 TA P DECaMP POOH wI CBP setting tool and DP. 18:00 - 19:00 1.00 TA P DECaMP Break out and lay down CBP setting tools. 19:00 - 20:00 1.00 CASE P TIEB1 P/U BHA #6: 9-5/8" Multi-string Cutter, XO, 8-1/2" Stabilizer, XO, and 20 jts 3-1/2" DP. 20:00 - 20:30 0.50 CASE P TIEB1 TIH wI BHA #6 to -602'. 20:30 - 00:00 3.50 CASE P TIEB1 Wait on Diesel Power/Freeze Protect fluid. Bleed down OIA from 150 psi to 0 psi to Tiger Tank. Clean Pit 1 and Tiger Tank--send 106 Bbls of cementing wash-up to Pad 3. Load diesel powerlfreeze fluid in pit; diesel fluid arrived 23:00 hours. Vac Trucks hard to come by due to other GPB Operations. 12/27/2003 00:00 - 01 :00 1.00 CASE N DPRB TIEB1 RIH wI BHA #6: Baker Multi String casing cutter, XO, 8-1/2" Stabilizer, XO, 20 joints 3-1/2" DP. Locate top and bottom of 15th jt 9-5/8"; make cut @ -62?'. 01 :00 - 01 :30 0.50 CASE N DPRB TIEB1 Attempt to circulate in Diesel freeze protect fluid. Pressured up to 1000psi, but would not bleed through to pits. 01 :30 - 03:00 1.50 CASE N DPRB TIEB1 TOH wI BHA #6 and Break Out and LID Baker casing cutter tools. Change out rig tongs to Baker tongs for remainder of casing operations. 03:00 - 05:00 2.00 CASE N DPRB TIEB1 ND BOP and Remove Tubing Spool. 05:00 - 07:30 2.50 CASE N DPRB TIEB1 Install Test Spool and NU BOP Stack. Printed: 1/19/2004 9:46:32 AM BP EXPLORATION Page 5 of 15 Operations Summary Report Legal Well Name: WGI-05 Common Well Name: WGI-05 Spud Date: 2/16/1990 Event Name: WORKOVER Start: 12/19/2003 End: 1/15/2004 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/15/2004 Rig Name: NABORS 4ES Rig Number: 4ES Date From. -.To. Hours Task Code NPT Phase pescrjption of Operations I... 12/27/2003 07:30 - 08:30 1.00 CASE N DPRB TIEB1 Pick-up BHA #7 as follows: 9 5/8" Spear Pack-Off, 9 5/8" Spear, Extention, Stop Sub, Bumper Sub, XO, 1 Jt 31/2" DP. 08:30 - 09:30 1.00 CASE N DPRB TIEB1 Plant Spear in 9 5/8" Casing. BOLDS. Attempt to pull 9 5/8" (622-ft) Casing and pull Hanger to the Floor. Work Casing up to 150K (free string weight above cut point should weight -28,200 Ibs). 09:30 - 10:00 0.50 CASE N DPRB TIEB1 lay down Spear Assembly. 10:00 - 11 :00 1.00 CASE N DPRB TIEB1 Pick-up Spear Assembly...added Jar Assembly and 1 ea 61/4" Drill Collar above Spear Assy. 11 :00 - 13:00 2.00 CASE N DPRB TIEB1 Spear 95/8" Csg again. Work Csg. Trip Jars at 100K - 125K. No movement. Discuss plan forward to re-cut Casing with Anchorage Eng. 13:00 - 13:30 0.50 CASE N DPRB TIEB1 Release Spear and lD same. 13:30 -14:00 0.50 CASE N DPRB TIEB1 PU BHA #8 as follows: 9 5/8" MS Cutter, XO, Stablizer, XO. Replaced Cutter Blades. 14:00 -15:00 1.00 CASE N DPRB TIEB1 RIH with BHA #8. Pick-up Kelly. Cut 9 5/8" Csg at 44-ft 4es kb. 15:00 - 15:30 0.50 CASE N DPRB TIEB1 Set back Kelly. POOH. lD BHA #8. 15:30 - 16:00 0.50 CASE N DPRB TIEB1 PU Spear Assy (BHA # 9). Spear 9 5/8" Csg. Pull Hanger/Pack-Off to Rig Floor with no problems. 16:00 - 18:00 2.00 CASE P TIEB1 lay down 9 5/8" Hanger/Pack-Off, 4.20' Pup Jt, 18.50' of Jt #1. 18:00 - 20:00 2.00 CASE N DPRB TIEB1 PU BHA #10 as follows: 9 5/8" MS Cutter, XO, Stablizer, XO. Replaced Cutter Blades. RIH and locate to initial cut @ 622', and recut 9-5/8" casing. 20:00 - 20:45 0.75 CASE N DPRB TIEB1 POH wI BHA #10, break out and LID. 20:45 - 21 :15 0.50 CASE N DPRB TIEB1 Pick-up BHA #11 as follows: 9 5/8" Spear Pack-Off, 9 5/8" Spear, Extension, Stop Sub, Bumper Sub, XO, 1 Jt 31/2" DP. Find TOF @ +1- 44', and enter fish; S/O weight = -22K, P/U weight = 35K. Fish successfully moved up hole. 21:15 - 22:00 0.75 CASE P TIEB1 Circulate out Arctic Pack with diesel, 79 Bbls. 22:00 - 00:00 2.00 CASE P TIEB1 RU casing handling equipment and TOH 9-5/8" casing. Top of first cut joint to floor at 2235 hours. 12/28/2003 00:00 - 01 :30 1.50 CASE P TIEB1 POH wI 14 jts 9-5/8" 47#, l-80 casing, and two cut joints; total length = 579.14'. The previously recovered cut joint = 18.5'. Total 9-5/8" casing recovery = 18.5' + 579.14' = 579.64'. 01 :30 - 03:30 2.00 CASE P TIEB1 RID Casing Handling Equipment. MU BHA # 12: 12-1/4" bit, 13-3/8" casing scraper, XO, Bumper Sub, XO. 03:30 - 04:30 1.00 CASE P TIEB1 RIH with BHA #12 and clean out to 620-ft +. 04:30 - 06:00 1.50 CASE P TIEB1 POOH wI BHA #12 06:00 - 07:00 1.00 CASE P TIEB1 Service Rig. Clear and Clean Floor. 07:00 - 07:30 0.50 CASE P TIEB2 MU Halco 13 3/8" Composite Bridge Plug and Running Tool. 07:30 - 09:00 1.50 CASE P TIEB2 RIH with 13 3/8" CBP, Drill Collars and Drill Pipe. Set CBP at 603-ft. 09:00 - 09:30 0.50 CASE P TIEB2 Pressure 13 3/8" CBP at 1,000 psi/15 min and record on Chart. 09:30 - 10:30 1.00 CASE P TIEB2 POOH with Drill Pipe, Drill Collars, and Running Tool. lD Running Tool. 10:30 - 11 :30 1.00 CASE P TIEB2 PU BHA #13 as follows: 13 3/8" MS Cutter, Stabilizer, XO,XO. locate collar for cutter stack out. 11 :30 - 13:00 1.50 CASE P TIEB2 PU Kelly, secure BOP, H/U Vac trucks, PJSM for casing cutting ops. 13:00 -14:00 1.00 CASE P TIEB2 TIH wI BHA #13, spot cutter @ 78' and begin cut. Cutter not operating properly. 14:00 - 15:00 1.00 CASE P TIEB2 POH wI cutter, and find cutters had not moved far enough to Printed: 1/19/2004 9:46:32 AM .. BP EXPLORATION Page 6 of 15 Operations .SummaryReport Legal Well Name: WGI-05 Common Well Name: WGI-05 Spud Date: 2/16/1990 Event Name: WORKOVER Start: 12/19/2003 End: 1/15/2004 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/15/2004 Rig Name: NABORS 4ES Rig Number: 4ES .. Date From- To Hours TaSk Code NPT Phase DescriptjonofOperations .. .... I 12/28/2003 14:00 - 15:00 1.00 CASE P TIEB2 facilitate full cut. 15:00 - 16:00 1.00 CASE P TIEB2 TIH wI BHA #13, reposition assy with new cutters @ 78' and make cut. 16:00 - 17:00 1.00 CASE P TIEB2 POH and LID BHA #13. 17:00 - 18:00 1.00 CASE P TIEB2 Prepare to NID BOP, clear clean drill floor. 18:00 - 19:30 1.50 CASE P TIEB2 NID BOP stack, clean drill floor. 19:30 - 20:00 0.50 CASE P TIEB2 R/U Wachs External Casing Cutter. PJSM for NID BOPS and for Wachs cutting ops. 20:00 - 22:00 2.00 CASE C TIEB2 NID BOP. Confer with Anchorage: 13-318" casing hung in slips required a change in scope. 22:00 - 00:00 2.00 CASE C TIEB2 PJSM to RIH wI 13-3/8" Baker casing spear (BHA #14) to measure gage. Spear would not fit through 13-3/8" spool due to restriction caused by landing shoulder profile. N/U BOP. 12/29/2003 00:00 - 02:30 2.50 CASE C TIEB2 N/U and body test BOP. 02:30 - 03:30 1.00 CASE C TIEB2 P/U BHA #14, casing cutter; break down and service and install . new seals and cutters. Make up all connections. 03:30 - 05:00 1.50 CASE C TIEB2 TIH wI BHA #14, make cut @ 27'...4es kb. 05:00 - 06:00 1.00 CASE C TIEB2 POOH and LID BHA #14. 06:00 - 08:00 2.00 CASE C TIEB2 ND BOP Stack. 08:00 - 09:00 1.00 CASE C TIEB2 Bolt "Potato-Masher" to Wellhead. Attempt to pull Wellhead and 6-ft Casing stub free using the Blocks (10K). No-Joy. 09:00 - 11 :00 2.00 CASE C TIEB2 RU WACHS Cutter. Cut the 13 3/8" just below Wellhead. Made a clean cut in 13 minutes...IMPRESSIVE!...(it only took 30 min to RU cutter, level, and adjust). LD Wellhead and remove from Cellar. 11 :00 - 12:00 1.00 CASE C TIEB2 PU BHA #15.. .13 3/8" Spear Assy as follows: Spear Pack-Off, Spear, Extention, Stop Sub, Bumper Sub, Oil Jar, XO, 12:00 - 13:30 1.50 CASE C TIEB2 Spear 13 3/8" Casing. Unable to pull free. Trip Oil Jar at 150K. Slips and 6-ft Casing stub now free. LD Casing stub. Casing was not completly cut...had two thin areas where it was still together 13:30 - 15:30 2.00 CASE C TIEB2 Break out and LD BHA #15. Clear and Clean Floor. 15:30 - 00:00 8.50 CASE X WAIT TIEB2 Phase # 3 weather conditions Slpoe wide. Discuss conditions with Supervisor. Halt operations WOW. Well is secure. 12/30/2003 00:00 - 08:30 8.50 CASE X WAIT TIEB2 Continue to Wait on Weather. Still Phase 3. 08:30 - 09:00 0.50 CASE C TIEB2 Weather improved to Phase 2. Resume Operations...Hold PJSM with All. Prep to begin Wash-Over Ops. 09:00 - 10:00 1.00 CASE C TIEB2 PU BHA # 16 as follows: 171/2" Mill Shoe, 16 WP Extention, Drive Sub, XO, XO. 10:00 - 18:00 8.00 CASE C TIEB2 Begin Washing-Over 13 3/8" Csg. String weight = 18K, Set 1-3K down weight on Shoe, 50 - 60 RPMs. Circulate using Charge Pump as needed up to 2 1/4 BPM @ 20 psi. Wash from 27-ft 4es kb down to 62'. PIW 22K, SIO 18K, Rot 20K. 18:00 - 19:00 1.00 CASE C TIEB2 Set back kelly. POOH wI washpipe & check shoe. 19:00 - 20:00 1.00 CASE C TIEB2 Make 2nd connection of 16" pipe. Work down over 13 3/8" casing stub which is laying against conductor casing. 20:00 - 22:30 2.50 CASE C TIEB2 P/U kelly & con't to wash over. Mill over casing (acted like junk for 2 ft) @ 64', Wash to 68', would not drill off. Attempted dry drilling no progress appear to to be spinning on junk. No torque. WOB 5K, 40-80 RPMs, 2+ BPM wI charge pump @ 20 psi. P/U 22K, SIO 18K, Rot 20K. 22:30 - 00:00 1.50 CASE C TIEB2 Set back kelly. POOH & check shoe on washpipe. 2 metal rings inside of bottom jt of washpipe. LID bottom jt of washpipe. Printed: 1/19/2004 9:46:32 AM BP EXPLORATION Page 7oft5 Operations Summary Report Legal Well Name: WGI-05 Common Well Name: WGI-05 Spud Date: 2/16/1990 Event Name: WORKOVER Start: 12/19/2003 End: 1/15/2004 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/15/2004 Rig Name: NABORS 4ES Rig Number: 4ES Date From.. To Hours Task Code NPT Phase Descriptjon of. Operations .. . 12/31/2003 00:00 - 01 :00 1.00 CASE C TIEB2 RIH wI washpipe assy. Work over casing stub. 01 :00 - 03:00 2.00 CASE C TIEB2 P/U kelly & con't to wash from 68 to 84'. 03:00 - 03:30 0.50 CASE C TIEB2 Set back kelly. Make 18' pup connection. 03:30 - 05:00 1.50 CASE C TIEB2 Con't to wash from 84 to 99'. P/U 23K, SIO 18K, Rot 21 K. 40-80 RPMs, WOB 2-5K, 2 1/4 BPM. 05:00 - 06:00 1.00 CASE C TIEB2 POOH & LID pup jt. & P/U 32' WP Jt. 06:00 - 07:00 1.00 CASE C TIEB2 Continue to wash-over from 99' 4es kb - 104' 4es kb. Good indication of Collar at 98'. 07:00 - 08:30 1.50 CASE C TIEB2 Circulate Well clean Sea Water. Mix and pump final circulation with 9.8 Iblgal Brine. 08:30 - 09:00 0.50 CASE C TIEB2 POOH with 16" Wash Pipe Assy. 09:00 - 10:30 1.50 CASE C TIEB2 LD Wash Pipe Assy. Clear 16" handling equipment from Rig Floor. 10:30 - 11 :30 1.00 CASE C TIEB2 Pick up 13 3/8" Spear Assembly. 11 :30 - 13:00 1.50 CASE C TIEB2 Spear 13 3/8" Csg. Pull 13 3/8" Csg to surface. RU 13 3/8" handling equipment. LD recovered Csg as follow: remainder of Jt #1 = 32.30' and the top cut-off of Jt #2 = 19.65'. Bottom of recovered Csg is "sliced", probably due to at sometime during the WO the WP was picked up and the cut Csg was also picked up with a "friction-bite". When the Csg fell out of the WP it fell on top of the Stump looking up and both peices were "sliced". Order out 13 3/8" string Mill. 13:00 - 14:30 1.50 CASE C TIEB2 While waiting for String Mill to arrive on Location. PU 12 1/4" Bit and RIH to attempt to get inside 13 3/8" Csg Stump. Would not go. POOH. 14:30 - 15:30 1.00 FISH C TIEB2 Clear & clean rig floor. Clean out cellar box with "Super-Sucker" truck. 15:30 - 18:00 2.50 FISH C TIEB2 M/U 12 1/4" string mill. RIH & dress off top of casing stub. Con't to RIH to 106' & insure casing is gauge wI mill. 18:00 - 19:00 1.00 FISH C TIEB2 Set back kelly & POOH wI Milling assy. LID mill. 19:00 - 22:30 3.50 FISH C TIEB2 Hold PJSM. M/U Back off tools & Chech all service breaks. RIH & space out mill. TOP of stub @ 81.71'. Collar to be backed off @ 99'. Set back off tool pkrs from 91.50' & 117'. 22:30 - 23:00 0.50 FISH C TIEB2 Fill drill string wI diesel. Pressure up & set packers w/1 000 psi & 2300 psi respectively. 23:00 - 00:00 1.00 FISH C TIEB2 Pressure up to 5000 psi ( 50K torque on connection) and broke connection @ 99' free. Con't to cycle Back off tool. 1/1/2004 00:00 - 01 :30 1.50 FISH C TIEB2 Con't to back off 13 3/8" casing @ 99'. Made 6 full revolutions. Final pressure 700 psi. Release tool. 01 :30 - 03:30 2.00 FISH C TIEB2 POOH & LID Back off tools. 03:30 - 04:30 1.00 FISH C TIEB2 M/U spear & bumper sub. RIH on 3 1/2" DP to 81.71'. Engauge spear. Finish backing off casing stub. Took additional 6 1/2 turns. P/U & POOH w/13 3/8" casing stub. 04:30 - 05:30 1.00 FISH C TIEB2 Clear & clean rig floor. P/U casing spider & 13 3/8" slips to LID recovered casing. LID 19.81' cut off jt. (collar looking up @ 98.6' Rig 4 RKB) 05:30 - 06:30 1.00 FISH C TIEB2 RIH wI Muleshoe on 3 1/2" DP to -475'. 06:30 - 08:00 1.50 FISH C TIEB2 Swap Wellbore over to clean Diesel. 08:00 - 08:30 0.50 FISH C TIEB2 POOH with Drill Pipe. 08:30 - 10:00 1.50 FISH C TIEB2 Clear and Clean Floor. RU to handle 133/8" Csg. 10:00 - 11 :00 1.00 FISH C TIEB2 Pick up Lone Star 13 3/8" x 68 Ibltt x L-80 x BTC Csg as follows: Jt #1 = 18.83', Jt #2 = 41.41', Jt #3 = 41.20', Landing Printed: 1/19/2004 9:46:32 AM .. BP EXPLORATION Page 80f 15 Operations Summary Report Legal Well Name: WGI-05 Common Well Name: WGI-05 Spud Date: 2/16/1990 Event Name: WORKOVER Start: 12/19/2003 End: 1/15/2004 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/15/2004 Rig Name: NABORS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of Operations 1/1/2004 10:00 - 11 :00 1.00 FISH C TIEB2 Jt. String Weight = 18,000 Ibs. 11 :00 - 12:00 1.00 FISH C TIEB2 Work Casing...attempt to screw into Collar connection looking up at 98.69' 4 es kb. No-Joy? 12:00 - 13:30 1.50 FISH C TIEB2 LD Landing Jt. POOH and inspect Pin-end Thrd...Good. Make a small "Cut-lip" guide in leading edge of Pin. 13:30 - 15:00 1.50 FISH C TIEB2 RIH & attempt to screw into casing collar @ 98'. Torquing up before fully engauged. No good. 15:00 - 16:00 1.00 FISH C TIEB2 POH & LID 13 3/8" casing. Inspect threads, good. 16:00 - 18:00 2.00 FISH C TIEB2 Clear floor. Load, caliper & tally BHA to attempt to align casing using 3 string stabilizers. 18:00 - 19:30 1.50 FISH C TIEB2 P/U & M/U BHA wI 2 ea 12 1/4" stabilizers to help align casing to screw together. RIH on drill pipe. Stack out BHA (Drill Pipe Tail Pipe) on top of plug. Top stabilizer @ 92.7' & bottom stabilizer @ 105.3'. 19:30 - 20:00 0.50 FISH C TIEB2 R/U casing tools to 13 3/8" casing. 20:00 - 21 :30 1.50 FISH C TIEB2 Hold PJSM. Run in hole w/13 3/8" casing to 98'. 21 :30 - 23:00 1.50 FISH C TIEB2 Attempt to screw into 133/8" casing collar @ 98'. Pipe torquing up in 3+ turns, appears to be wanting to cross thread. 23:00 - 00:00 1.00 FISH C TIEB2 POOH & inspect 13 3/8" casing pins. Bottom pin had some cement in threads. Discussed next option with Anch Eng. Have elected to make up a Overshot guide on the bottom of a 133/8" short jt to screw in collar @ 98'. Send extra "Short Jt to Baker. Baker Machine Shop start to fabricate Overshot Guide. 1/2/2004 00:00 - 15:00 15.00 FISH C TIEB2 Waiting on fabrication of a Screw-in Guide from Baker machine. Cleaning & performing maintenance on rig. The Back-Brake was installed on the Rotary Table. 15:00 - 18:00 3.00 FISH C TIEB2 PU Guide Jt and 133/8" Csg. Tag top of Csg Collar at 98.6'. 13 3/8" Pin end inside Guide fell right into Collar. Begin to work Csg and attempt to screw into Collar. 18:00 - 19:00 1.00 FISH C TIEB2 Can't to work pipe & M/U threads. Made 11 + rounds wI final torq of 9k. P/U wt 20K. Pull to 1 OOK & test make up. 19:00 - 20:00 1.00 FISH C TIEB2 R/U head pin & lines. Fill casing, pressure up to 1000 psi & hold for 10 min. Tested Ok. Charted same. Bled off lines & RID equip. 20:00 - 23:30 3.50 FISH C TIEB2 Back out swage & head pin. R/U vac truck & suck diesel out of 13 3/8" casing to 6' below ground level. 23:30 - 00:00 0.50 FISH C TIEB2 R/U WACHS cutting tools. Begin cutting off 13 3/8" casing 1/3/2004 00:00 - 00:30 0.50 FISH C TIEB2 Finish cuttung off 13 3/8" casing. RID cutting tools. 00:30 - 01 :30 1.00 FISH C TIEB2 Lay down landing jt & cut-off jt. RID casing equip. Clear & clean rig floor. 01 :30 - 02:30 1.00 FISH C TIEB2 RIH w/3 1/2" DP & screw into alignment BHA w/2 stabs. P/U til tool jt is @ floor. Install head pin & displace diesel out of inside of 13 3/8" casing. 02:30 - 03:30 1.00 FISH C TIEB2 POOH & LID alignment BHA wI stabs. 03:30 - 09:00 5.50 WHSUR P TIEB2 PJSM. Safe-Out Cellar. Install casing head on 13 3/8" and weld same. 09:00 - 09:30 0.50 WHSUR P TIEB2 Cameron perform initial test at 500 psi/30 min. Good test. 09:30 - 16:30 7.00 WHSUR P TIEB2 Post heat wrap and "slow cool" down. 16:30 - 17:00 0.50 WHSUR P TIEB2 Cameron perform final test at 1,700 psi/30 min. Good test. 17:00 - 18:00 1.00 WHSUR P TIEB2 Install test spool. 18:00 - 21 :00 3.00 BOPSUF P TIEB2 N/U BOPE. 21 :00 - 00:00 3.00 BOPSUF P TIEB2 Pressure test BOPE. LP 250 psi, HP 3500 psi. Tested, Rams, Kelly & Valves, Choke Manifold, Koomey & Annular (HP 2500 Printed: 1/19/2004 9:46:32 AM BP EXPLORATION Page90f 15 Operations Summary Report Legal Well Name: WGI-05 Common Well Name: WGI-05 Spud Date: 2/16/1990 Event Name: WORKOVER Start: 12/19/2003 End: 1/15/2004 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/15/2004 Rig Name: NABORS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT.. Phase Description of Operations ... 1/3/2004 21 :00 - 00:00 3.00 BOPSUF P TIEB2 psi). Test witnessing waived by Chuck Scheve wI AOGCC. 1/4/2004 00:00 - 01 :00 1.00 BOPSUF P TIEB2 Finish pressure testing BOPE. Lp 250 psi, HP 3500 psi. 01 :00 - 01 :30 0.50 BOPSUF P TIEB2 P/U landing jt & M/U running tool. Pull Test plug. Set Wear bushing. UD landing jt. 01 :30 - 02:00 0.50 BOPSUR P TIEB2 Close rams & pressure test 13 3/8" casing to 1500 psi for 10 min, Ok. Charted same. 02:00 - 02:30 0.50 DRILL P TIEB2 M/U BHA # 22 as follows: 12 1/4" Bit, BS, XO, 2* JBs, XO, Bumper Sub, XO, 9 DCs, XO. TL 305.92'. 02:30 - 03:30 1.00 DRILL P TIEB2 RIH wI BHA #22. P/U kelly & tag up on fill @ 600'. 03:30 - 04:00 0.50 DRILL P TIEB2 Displace hole to 9.8 ppg fluid. 4 BPM @ 150 psi. 04:00 - 06:30 2.50 DRILL P TIEB2 Drill fill and Halco 13 3/8" Composite Bridge Plug from 600 to 603'. Continue to rotate down to top of 9 5/8" "Cut-off" Stump at 622'. 06:30 - 07:00 0.50 DRILL P TIEB2 Pump Hi-Vis Sweep and displace back to surface with 9.8 Iblgal Brine. 07:00 - 08:00 1.00 CASE P TIEB2 Test 13 3/8" Casing after drilling out CBP at 2,500 psi/15 min. Good test. 08:00 - 09:00 1.00 CASE P TIEB2 POOH & UD BHA #22. 09:00 - 10:00 1.00 CASE P TIEB2 Clear rig floor. Dump & clean out junk baskets. Load & tally tools. (Recovered -3 qts of CBP chips and small metal pieces). 10:00 - 11 :00 1.00 CASE P TIEB2 M/U BHA # 23. Cutter assy. 11 :00 - 23:30 12.50 CASE N DPRB TIEB2 Prepare to RIHwl BHA. Open rams, Trapped gas.. Hole unloaded approx. 10 Bbls of diesel, 90% contained to rig. Called & reported spill. Estimated 1 bbl was carried by high winds causing a mist onto pad & tundra. See Traction report for details. SID operations & Clean up spill & rig. (Took 12 bbls to fill hole). 23:30 - 00:00 0.50 CASE P TIEB2 R/U to RIH & displace fluid. 1/5/2004 00:00 - 01 :00 1.00 CASE C TIEB2 M/U BHA. Mule shoe & DCs. Open well. Well had 20 psi SIP. Monitor well. Fluid bubbling gas. No flow. Gas decreased, but did not completely stop. Fluid level dropped. 01 :00 - 02:00 1.00 CASE C TIEB2 RIH to top of 95/8" casing stub & tag obstruction @ 622'. Could not get deeper. Must have plug reminants blocking top of 95/8". 02:00 - 03:00 1.00 CASE C TIEB2 Break circulation & displace wellbore to 9.8 ppg brine. Well still bubbling, however it is less then before displacement. NO FLOW. 03:00 - 03:30 0.50 CASE C TIEB2 POOH wI muleshoe & DCs.. 03:30 - 06:00 2.50 CASE P TIEB2 M/U BHA # 23. 9 5/8" Dressoff Assy as follows: Shoe, Wash pipe, WIO Boot Basket, XO, Bumper Sub, Oil Jars, XO, 9 DCs, XO. TL = 337.33'. Start RIH. 06:00 - 11 :00 5.00 CASE P TIEB1 Wash-Over 9 5/8" Csg Stump from 622' down to 655' on the outside and 627' on the inside. Found the Casing Collar at 644'. 11 :00 - 11 :30 0.50 CASE C TIEB1 Circulated hole w/9.8 Ib/gal Brine. Oil/Arctic Pack streaks in returns. Gas bubbles observed breaking out at surface. LEL reading 0% - 4%. 11 :30 - 12:30 1.00 CASE C TIEB1 POOH with BHA #23. 12:30 - 15:00 2.50 CASE C TIEB1 LD BHA #23. Empty Junk Baskets. Recovered 2 gals of Composite Plug chips and small metal pieces. Rig down handling equipment. Clear Floor. Now at Phase 2 weather conditions. 15:00 - 15:30 0.50 CASE C TIEB1 Make-Up 8 1/2" Bit and Bit Sub. Printed: 1/19/2004 9:46:32 AM BP EXPLORATION Page100f 15 Operations Summary Report Legal Well Name: WGI-05 Common Well Name: WGI-05 Spud Date: 2/16/1990 Event Name: WORKOVER Start: 12/19/2003 End: 1/15/2004 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/15/2004 Rig Name: NABORS 4ES Rig Number: 4ES Date From- To Hours Task Gode NPT Phase Description. of Operations 1/5/2004 15:30 - 19:00 3.50 CASE C TIEB1 Flow check well. RIH & tag up on junk 5' below 9 5/8" casing stub. ( 627') Con't to run in hole & push junk to bottom. Tag plug @ 4000'. 19:00 - 19:30 0.50 CASE C TIEB1 POOH to 2200'. 19:30 - 20:30 1.00 CASE C TIEB1 Hold PJSM. R/U to circulate wI Hot Oiler. Pressure test lines. 20:30 - 00:00 3.50 CASE C TIEB1 Break circulation & circulate hot fluid around wellbore. Circulated thru choke & then opened to flow lines. Temperature increased from 50 to 90 deg. LEL range 5 to 61@ bottoms up, then decreased to 9. Whwn from trace of oil to high of 5%. Fluid temp in is 150 deg. Pumping 1.5 BPM @ 100 psi. 1/6/2004 00:00 - 06:00 6.00 CASE C TIEB1 Con't to circulate @ 1.5 BPM, 100 psi. wI 170 Deg. brine. Temp out = 118 Deg. LELs averaging 11. Oil cut less than 2%.. Brine Wt = 9.8 in...9.8 out. 06:00 - 08:30 2.50 CASE C TIEB1 Complete circulating hot Brine. Final results. 1000 bbls pumped, 170 deg/9.8 Brine in, 123/9.8 Brine deg out. 1 % oil/Arctic Pack in returns. Still some gas bubbles in returns. Rig down Hot Oil. 08:30 - 09:00 0.50 CASE C TIEB1 Blow down lines 09:00 - 10:00 1.00 CASE C TIEB1 POOH with Drill Pipe and 12 1/4" Bit. 10:00 - 10:30 0.50 CASE C TIEB1 Lay down Bit and Bit Sub. Clear Floor. 10:30 - 11 :00 0.50 CASE C TIEB1 Monitor fluid in Stack and observe "oil/gas break-out". However, no flow. 11 :00 - 11 :30 0.50 CASE C TIEB1 Make-up Halco 9 5/8" RTTS Pkr. 11 :30 - 12:30 1.00 CASE C TIEB1 RIH with Pkr. Enter top of 95/8" Stump at 622'. Continue down to - 755'. Set Pkr. 12:30 - 13:30 1.00 CASE C TIEB1 Pressure tested Composite Bridge Plug at 4,007' and 9 5/8" Csg to 3,900 psi/30 min (lost 100 psi in 30 min). Monitor OillGas "break-out" in Stack same as before Pkr was ran and set. 13:30 - 14:30 1.00 CASE C TIEB1 Unset RTTS. POOH & LID RTTS. 14:30 - 15:30 1.00 CASE C TIEB1 Clear & clean rig floor. Wait on Loggers. 15:30 - 17:00 1.50 CASE C TIEB1 Hold PJSM. R/U Schlumberger. 17:00 - 20:00 3.00 CASE C TIEB1 RIH wI USIT log. Log from 2500' to 622'. Top Of Cement @ 2280'. Completely free pipe @ 2040'. Elect to cut casing in the middle of jt above free pipe @ 2010' 20:00 - 21 :30 1.50 CASE C TIEB1 RID logging equip. Clear floor. 21 :30 - 22:30 1.00 CASE C TIEB1 P/U & M/U BHA # 24. 9 5/8" Cutter Assy. 22:30 - 00:00 1.50 CASE C TIEB1 RIH slowly. Rotate thru top of cut off jt @ 622'. Con't to RIH & space out between collars @ 1990 & 2029'. Set cutter @ 2010'. 1/7/2004 00:00 - 01 :30 1.50 CASE P TIEB1 Cut 9 5/8" casing @ 2010'. P/U 55K, SIO 55K, Rot 54K. 70 RPMs, 2 BPM @ 350 psi, 3 BPM @ 700 psi. Torq 2K increased to 10k. Picked up wI 25K overpull. Blades supporting casing string. 01 :30 - 03:00 1.50 CASE P TIEB1 POOH wI Cutting Assy. Inspect cutters. Good indication blades cut all the way thru casing. LID cutting tools. 03:00 - 04:00 1.00 CASE P TIEB1 Clear floor. M/U BHA # 25 Spear & Jarring Assy. 04:00 - 04:30 0.50 CASE P TIEB1 RIH & spear into casing stub, swallow to 632'. P/U to 92k, 54K overpull & casing started to come. Pull to floor. Monitor well. Well static. 04:30 - 07:30 3.00 CASE P TIEB1 R/U & circulate wellbore wI hot 9.8 ppg brine. 3 BPM @ 200 psi. (2.5) hole volumes. Well stable with little bubbling. 07:30 - 13:30 6.00 CASE P TIEB1 PJSM. POOH w/3 1/2" DP & LID cut joint, (20.61'), 33 jts of 9 Printed: 1/19/2004 9:46:32 AM BP EXPLORATION Page 11 of 15 Operations Summary Report Legal Well Name: WGI-05 Common Well Name: WGI-05 Spud Date: 2/16/1990 Event Name: WORKOVER Start: 12/19/2003 End: 1/15/2004 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/15/2004 Rig Name: NABORS 4ES Rjg Number: 4ES .. Date From - To Hoürs Task. Code NPT Phase Descri ptionofOperations ... 1/7/2004 07:30 - 13:30 6.00 CASE P TIEB1 5/8" casing, & bottom cut of jt, (21.05'). LID fishing tools. Rig up equipment & POOH wI 9 5/8" casing, cleaning (thick oil) off casing. 13:30 - 15:30 2.00 CASE P TIEB1 Clear / Clean rig floor. Rig down 9 5/8" casing equipment. 15:30 - 18:30 3.00 CASE P TIEB1 Pick up cleanout BHA. Pull wear bushing to get casing scraper thru. RIH wI scraper assy. 18:30 - 20:00 1.50 CASE P TIEB1 RIH wI Scraper Assy. Tag top of stub @ 2010'. P/U 2'. 20:00 - 23:00 3.00 CASE P TIEB1 M/U head pin in 3 1/2' DP to circulate. Pump 20 Bbls of diesel followed by 20 bbl Hi-Vis pill. Chase wI hot 9.8 ppg brine. Pump @ 3 BPM, 400 psi while reciprocating pipe 10-25' occasionaly. Recovered oil & black brine. Hole cleaned up as before wI occasional oil globules coming to surface. No gas. monitor well. 23:00 - 00:00 1.00 CASE P TIEB1 RID head pin & POOH w/ scraper assy. 1/8/2004 00:00 - 01 :30 1.50 CASE P TIEB1 POOH & LID bit & scraper assy.. Clean out junk baskets. Junk baskets contained heavy tar & oil. Clear & clean rig floor. 01 :30 - 02:30 1.00 CASE P TIEB1 P/U & M/U 9 5/8" Back off tools. RIH wI same. 02:30 - 06:30 4.00 CASE P TIEB1 RIH wI back off assy fill DP wI diesel every 10 stands. Fill DP wI diesel. 06:30 - 08:00 1.50 CASE P TIEB1 PJSM. Establish parameters. Up wt= 60K, Down Wt = 61 K. Position upper anchor @ 2020', lower anchor @ 2049'. Pressure up to set lower anchor, 1500 psi. Slack off 20K. Pressure up to 5000 psi, set upper anchor. Bleed pressure & allow spring to recock tool. Pressure up to 3500 psi, (35,000 ft / Ibs), & observe sudden pressure drop & pipe turning to the left. Repeat & see pipe turn @ 1500 psi. Continue until (6) turns achieved. 08:00 - 12:00 4.00 CASE P TIEB1 PJSM. POOH (wet) wI back off tool. Pin sheared indicating good back off achieved. 12:00 - 13:30 1.50 CASE P TIEB1 M/U spear assembly & RIH on 3 1/2" DP. 13:30 - 14:00 0.50 CASE P TIEB1 PJSM. P/U kelly. Establish parameters. Up wt = 56K, down wt 56K, rotating 56K. Ran in to 2010', swallowed 10'. Pick up 10K over up wt, slack to neutral wt, turned (6) turns to the left, no torque, picked up free. 14:00 -15:30 1.50 CASE P TIEB1 POOH w/3 1/2" DP. LID spear assembly. Pin end on cut off joint looks good. 15:30 - 16:30 1.00 CASE P TIEB1 Clear & clean rig floor. 16:30 - 18:00 1.50 CASE TIEB1 Set test plug. Change out & Install 9 5/8" rams in BOP. Test door seals to 3500 psi, OK. 18:00 - 18:30 0.50 CASE P TIEB1 Pull Test plug. 18:30 - 19:30 1.00 CASE P TIEB1 R/U to run 9 5/8" casing. 19:30 - 21 :00 1.50 CASE P TIEB1 Hold PJSM. M/U Overshot/Screw-in shoe, 20' pup, ES Cementer. Baker-Iok connections. 21 :00 - 00:00 3.00 CASE P TIEB1 Run 9 5/8" casing. Ran 30 jts 47#, L-80 BTC-M, casing. 1 X-over jt, 8 jts 47#, NT-95 HS, NSCC casing. M/U NSCC to 9900 ft-Ibs. 38 jt in hole @ 2400 hrs. 1/9/2004 00:00 - 01 :30 1.50 CASE P TIEB1 Con't to RIH wI 9 5/8" casing. Ran total of 49 Jts wI Halliburton free floating centralizers on every other joint. 01 :30 - 02:30 1.00 CASE P TIEB1 Install X-over on top jt for cementing head. RIH & tag up on casing collar @ 2030'. Check space out, collar within l' of cut off point, Too close. 02:30 - 03:00 0.50 CASE N MISC TIEB1 No NSCC short jts or pups available. Clear floor. Prep to LID to BTC X-over jt. Printed: 1/19/2004 9:46:32 AM BP EXPLORATION Page 12 of 15 Operations Summary Report Legal Well Name: WGI-05 Common Well Name: WGI-05 Spud Date: 2/16/1990 Event Name: WORKOVER Start: 12/19/2003 End: 1/15/2004 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/15/2004 Rig Name: NABORS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase DescrjptionofOperations ,. .. 1/9/2004 03:00 - 04:30 1.50 CASE N MISC TIEB1 Pull & UD 18 jts to X-over. 04:30 - 06:00 1.50 CASE N MISC TIEB1 Install 1 0' BTC-mod pup in string. P/U X-over jt & RIH wI 9 5/8" NSCC casing. 06:00 - 06:30 0.50 CASE P TIEB1 PJSM. Lightly tag top of 95/8" collar @ 2030'. Rotate (2) turns to the left, see guide drop over collar. Rotate to the right slowly while inching pipe down. See torque developing & continue inching down. See torque to 9900 ftllbs w/12 1/4 turns. Release torque & pull to 200K, OK. 06:30 - 07:30 1.00 CEMT P TIEB1 Rig up cementers & cementing head. 07:30 - 08:00 0.50 CEMT P TIEB1 Safety meeting with all associated personel with regard to cement job. 08:00 - 09:30 1.50 CEMT P TIEB1 Ship fluid to cementers. Pressure test lines to 3500 psi, OK. Pressure test 9 5/8" casing to 2000 psi, OK. See ES valve open @ 2100 psi. 09:30 - 12:00 2.50 CEMT P TIEB1 Pump 32 bbls diesel ahead, pump 97 bbls 15.8 ppg Arctic Set cmt. Displace wI 9.8 ppg brine @ 8 bpm. Slow pump down wI 142 bbls away, watch for plug to bump. 5 bbls over & no bump. Consult town, go 10 over to 158 bbls displaced, no bump. Getting diesel back wI 133 bbls displaced. 12:00 - 13:30 1.50 CEMT N SFAL TIEB1 Adjust to take cement returns to pits. Line up on lower valve on cementing head only. Displace diesel & cement wI 9.8 ppg brine. Total displacement after cement = 375 bbls. 13:30 -14:30 1.00 CEMT N SFAL TIEB1 PJSM. Rig down cementing head. Plug still in head. Appears lower pin pull did not retract all the way. The release indicator somehow tripped, indicating plug had dropped, but not the case. Plug still in good condoiton. 14:30 - 18:00 3.50 CEMT N SFAL TIEB1 Call for more fluids. Reload cementer for 2nd job. Reinstall plug in cementing head. 18:00 - 19:00 1.00 CEMT N SFAL TIEB1 Finish R/U cementers & equip. Hold PJSM wI all hands & contractors. 19:00 - 21 :30 2.50 CEMT P TIEB1 Cement well as follows: Pump 5 Bbls freah water & fill lines. pressure test lines to 3500 psi, Ok. Pump 36 Bbls of diesel. Clear cement truc. Mix & pump 98 Bbls of Articset I cement. Mixed @ 15.7 ppg, Yld .93 cuftlsx. APR 6.5 BPM, APP 630 psi. Open valve, Drop plug & displace wI 149 Bbls of 9.8 ppg brine @ 6.5 BPM. Pressure increased from 300 to 1330 psi. Bump plug & sleeve shifted close wI 1600 psi. Pressure up to 2000 psi & hold for 2 min. Bled off & sleeve held. PD @ 2120 hrs. monitor well. 21 :30 - 00:00 2.50 CEMT P TIEB1 Blow down lines. UD cementing head. R/U vac line & suck out landing jt. Clear & clean rig floor. 1/10/2004 00:00 - 01 :00 1.00 CEMT P TIEB1 Finish Clear & clean floor & sucking out landing jt. Hold PJSM prior to lift BOP & set Slips. 01 :00 - 03:00 2.00 BOPSUR P TIEB1 P/U BOP stack. Set slips wI 125K. Cut & dress casing stub. 03:00 - 04:00 1.00 WHSUR P TIEB1 Set back BOP stack. UD landing jt & cut-off jt. Break out X-over. 04:00 - 05:00 1.00 WHSUR P TIEB1 N/U tubing spool & test tbg spool & pack off to 80% of collapse = 3825 psi. Good test. 05:00 - 09:00 4.00 BOPSUR P TIEB1 N/U BOPE. 09:00 - 12:30 3.50 BOPSUR P TIEB1 PJSM. Change out P/Rams from 95/8" to 2 7/8" X 5" variables. Clean cement out of ram cavities & test ports. 12:30 - 17:30 5.00 BOPSUR P TIEB1 PJSM. Conduct full test of BOPE. AOGCC rep Jeff Jones waived witnessing. Printed: 1/19/2004 9:46:32 AM BP EXPLORATION Page 13 of 15 Operations Summary Report Legal Well Name: WGI-05 Common Well Name: WGI-05 Spud Date: 2/16/1990 Event Name: WORKOVER Start: 12/19/2003 End: 1/15/2004 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/15/2004 Rig Name: NABORS 4ES Rig Number: 4ES Date From- To Hours Task Code NPT Phase Description of Operations 1/10/2004 17:30 - 18:00 0.50 BOPSUF P DECOMP Pull test plug. Install wear bushing. 18:00 - 18:30 0.50 WHSUR P DECOMP RILDS. UD landing jt & running tool. 18:30 - 19:00 0.50 DRILL P DECOMP Clear & clean rig floor. R/U to P/U BHA. 19:00 - 20:30 1.50 DRILL P DECOMP P/U BHA # 28. 81/2" bit, & 3 boot baskets, XO, Bumper sub, Oil Jars, XO, 12 DCs, XO. 20:30 - 21 :30 1.00 DRILL P DECOMP RIH wI BHA # 28 on 31/2" DP. Tag up on cement @ 1991'. P/U kelly & break circulation. 21 :30 - 23:00 1.50 DRILL P DECOMP Drill up cement & ES cementer plug from 1991 to 2004'. P/U 60K, S/O 58K. Rot 59K. 70 RPMs, Torq 2-4K. 5 BPM @ 375 psi. 8-12K WOB. 23:00 - 00:00 1.00 DRILL P DECOMP Circulate bottoms up & monitor well. Well static, No gas or pressure observed. Set back kelly & blow down lines. 1/11/2004 00:00 - 01 :00 1.00 DRILL P DECOMP Con't to RIH w/3 1/2" DP & BHA #28 & tag up @ 3985'. 01 :00 - 01 :30 0.50 CASE P DECOMP Close rams & pressure test casing to 4000 psi, for 10 min. Good test. Charted same. 01 :30 - 06:00 4.50 DRILL P DECOMP P/U kelly & break circulation. Drill debris, cement & composite plug to 4008'. 75 RPMs, 10-12 WOB, 5 BPM @ 575 psi. P/U 87K, S/O 84K, Rot 85K. Had oil & gas to surface. 06:00 - 07:30 1.50 DRILL P DECOMP Circulate btms up @ 5 bpm 11000 psi. 07:30 - 09:00 1.50 DRILL P DECOMP PJSM. Stand back kelly, lay down (3) singles & RIH wI stands. Tag cement @ 7712', 29' in on jt #230. 09:00 - 15:00 6.00 DRILL P DECOMP PJSM. Establish parameters. Up wt = 135K, down wt = 131k, rotating wt = 133K. Mill on cement pumping 5 bpm @ 1000 psi, rotating 75 RPM, 8-12K WOB. Pump sweeps & circulate between connections to clean hole. Drill to 7802', tag composite bridge plug. 15:00 - 16:30 1.50 DRILL P DECOMP Mill on bridge plug w/8-12K WOB, rotating 75 RPM, milled thru in about 45 minutes. Tag liner @ 7831' DPM. 16:30 - 18:00 1.50 DRILL P DECOMP Circulate hole clean, clean pits to take on 9.9 ppg brine, clean out cuttings box. 18:00 - 20:30 2.50 DRILL P DECOMP Displace wellbore to 9.9 ppg brine. 5 BPM @ 800 psi. SID & monitor well. 20:30 - 23:30 3.00 DRILL P DECOMP POOH & stand back 31/2" DP. 23:30 - 00:00 0.50 DRILL P DECOMP POOH & LID BHA & excess 6 1/4" DCs. 1/12/2004 00:00 - 00:30 0.50 DRILL P DECOMP LID BHA # 28. Clear & clean Rig floor. 00:30 - 02:00 1.50 DRILL P DECOMP M/U BHA # 29 as follows: 6" bit, 2 Junk Baskets, XO, 10* 4 3/4" DCs, XO, 9 5/8" Csg Scraper, XO, Bumper sub, Oil Jars, XO, 6* 61/4" DCs, XO. TL 536.63' ( Note: Bit to Scraper = 320.6') 02:00 - 05:30 3.50 DRILL P DECOMP RIH wI BHA # 29 on 3 1/2" DP. Tag up @ 7834', DPM. 05:30 - 06:30 1.00 DRILL P DECOMP P/U kelly & break circulation. Drill debris & cement from 7834' -7841'. Indication of junk getting up around scraper. 06:30 - 14:30 8.00 DRILL P DECOMP PJSM. Establish parameters. 133 K up wt, 131K down, 134K rotating wt. Pumping 4 1/2 bpm @ 1100 psi. 75-80 RPM, 8 - 12K WOB. Wash down wI little to no resistance f/7841'-7856'. Mill on junk f/7856' - 7864'. Wash down to 7883'. (see btms up from 7883' contains cement). Mill cement I cement stringers to 7911'. Mill cement, (med hard), f/7911' - 8101'. Average ROP = 50 fph. 14:30 - 15:00 0.50 DRILL P DECOMP Continue to mill cement as above, ROP = 50 fph. See ROP increase significantly @ 8115'. Drill on to kelly down @ 8131' with little resistance. 15:00 - 17:30 2.50 DRILL P DECOMP PJSM. Pick up off bottom 5' & reverse circulate @ 5 bpm I Printed: 1/19/2004 9:46:32 AM BP EXPLORATION Page 14 of 15 Operations Summary Report Legal Well Name: WGI-05 Common Well Name: WGI-05 Spud Date: 2/16/1990 Event Name: WORKOVER Start: 12/19/2003 End: 1/15/2004 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/15/2004 Rig Name: NABORS 4ES Rig Number: 4ES Date From -To Hours Task Code NPT Phase Descrjptjpn of Operations '. 1/12/2004 15:00 - 17:30 2.50 DRILL P DECOMP 1200 psi. Pump 20 bbl sweep. See salt returns with bottoms up. Continue to reverse circulate sweep around with no losses. H2S Drill wI circulating. 17:30 - 18:00 0.50 DRILL P DECOMP PJSM. Open bag, stand back kelly. Prep to LDDP. 18:00 - 00:00 6.00 DRILL P DECOMP POOH & UD 31/2" DP. 1/13/2004 00:00 - 01 :00 1.00 DRILL P COMP Cut & slip 84' of drilling line. Service rig & adjust brakes. 01 :00 - 01 :30 0.50 DRILL P COMP Finish POOH & UD 3-1/2" DP. 01 :30 - 03:00 1.50 DRILL P COMP POOH & UD BHA # 29. 03:00 - 04:00 1.00 WHSUR P COMP M/U landing jt & running tool. RIH & pull wear bushing. Install test plug. Ud running tool. Clear & clean rig floor. 04:00 - 06:00 2.00 BOPSUF P COMP Change out rams to run 7 5/8" casing. Body test to 4000 psi. 06:00 - 08:30 2.50 RUNCOr rP COMP PJSM. Rig up compensator, elevators, casing tongs & torque turn unit. Prep to run completion. 08:30 - 09:00 0.50 RUNcor rP COMP Safety meeting with all hands regarding pinch points, running procedure & torque applications. 09:00 - 00:00 15.00 RUNCOr fP COMP Make up jewelry & 51/2". Torque turn 5 1/2" TCII to 4350 ft/lbs. All connections under packer Baker Locked. Torque Turn 7" TCII connections to 8800 ftllbs. Torque turn all 7 5/8" L-80, IPC Vam Top HC connections to 14,450 ftllbs. Connections hanging up on tbg spool while running in hole. Adjust rig. Change out compensator. Continue in hole wI 7 5/8" completion string. 1/14/2004 00:00 - 09:00 9.00 RUNCOr /P COMP Continue RIH wI 7-5/8", 29.7#, L-80, IPC, VAM-Top HC tubing. Up wt 210K, down wt 215K. 09:00 - 11 :00 2.00 RUNCOr /p COMP Lightly tag top of 7" liner @ 7835', (28' in on jt #187), wI mule shoe. PJSM. Set slips & rotate 5 1/2 turns, 3500 ft/lbs torque. RIH wI jt #187, no bobbles. Make up tubing hanger & landing jt wI circulating head. 11 :00 - 12:30 1.50 RUNCOr ~ COMP Rig down torque turn equipment, tongs, compensator, clearlclean rig floor. 12:30 - 17:00 4.50 RUNCO~ P COMP PJSM. Reverse circulate seawater @ 3 bpm 1550 psi. Pump 290 bbls unheated seawater, 150 bbls 130 degree seawater, & 140 bbls 130 degree seawater with corrosion inhibitor. 17:00 - 18:00 1.00 RUNCO~ /P COMP PJSM. Drain stack. Land tubing hanger. RILDs. 18:00 - 19:30 1.50 RUNCO~ /P COMP R/U hot oil truck, test lines to 3000 psi, pump 80 degF diesel @ 2 BPM and 750 psi, 140 bbls pumped. 19:30 - 21 :00 1.50 RUNCOr /P COMP U-tube diesel back into tubing. 21 :00 - 21 :45 0.75 RUN cor /P COMP R/U test lines and M/U landing jt, stab into hanger, and prepare to drop 1-7/8" ball and rod. 21 :45 - 00:00 2.25 RUNCOr /P COMP Drop 1-7/8" ball and rod and wait 30 mins; pressure tbg to 4300 psi and hold for 30 mins; tbg bled to 4200 psi. 7-5/8" x 9-5/8" annulus pres climbed to 1000 psi and held rock steady for 30 mins. Bleed tbg pres to 1500 psi, pres up 7-5/8" x 9-5/8" annulus to 4000 psi and hold for 30 mins. Annulus held 4000 psi rock steady for 30 mins and tbg pres was rock steady @ 2200 psi. No communication between 7-5/8" tubing and annulus. 1/15/2004 00:00 - 01 :00 1.00 WHSUR P COMP Bleed off and RID test lines. Set TWC and test to 4000 psi. 01 :00 - 05:00 4.00 BOPSUF P COMP Change rams to 2-7/8" x 5" variable. Clean cellar. N/D BOPE. 05:00 - 06:00 1.00 WHSUR P COMP N/U Tree & test to 5000 psi, OK. 06:00 - 08:00 2.00 WHSUR P COMP PJSM. pull two way check valve, (some trouble getting swab valve to operate properly, grease up & work, OK). Set BPV & test to 1000 psi, OK. Secure well. Rig released @ 08:00 hrs, Printed: 1/19/2004 9:46:32 AM BP EXPLORATION Page 15 of 15 Operations Summary Report Legal Well Name: WGI-05 Common Well Name: WGI-05 Spud Date: 2/16/1990 Event Name: WORKOVER Start: 12/19/2003 End: 1/15/2004 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/15/2004 Rig Name: NABORS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Descri ptjon of Operations .. .. 1/15/2004 06:00 - 08:00 2.00 WHSUR P COMP 01-15-2004. Printed: 1/19/2004 9:46:32 AM Well: Field: API: Permit: WGI-05, Rig Workover Prudhoe Bay Unit 50-029-22015-00-00 190-025 / 303-329 Accept: Spud: Release: Rig: 12/20103 N/A 01/15/04 Nabors 4ES POST RIG WORK 01/22/04 PULL BALL & ROD FROM RHC PLUG & 7873' WLM. PULL PLUG BODY @ 7842' WLM. 01/24/04 MIRU. RIH WITH 1.75" DJN AND RIH. TAG TOP OF SALT PILL AT 8149' CTMD, JET DOWN THROUGH SALT WHILE MAKING FREQUENT SHORT TRIPS. JET DOWN TO 8650' CTMD. MAKE UP/DN PASSES WHILE JETTING. PUH, WAIT FOR ANY FALL BACK AND RBIH TO DRY TAG 86611 CTMD, NO FILL ENCOUNTERED. INJECTIVITY 6.3 BPM @ WHP 1220 PSI. PUH AND CONTINUE SOAKING. POOH FOR JSN. RIH WITH 2.5" JSN. 01/25/04 RIH WITH 2.5" JSN. JET PERF INTERVAL AT MAX RATE AND MIN ROP CLEANING AND DISSOLVING SALT TO IMPROVE INJECTIVITY. FINAL INJECTIVITY -7.9 BPM AT 1140 PSI WHP WITH 1% KCL. FREEZE PROTECT WELL TO 2500' WITH 115 BBLS DIESEL. LEFT WELL SHUT IN. RDMO NOTIFY DSO OF WELL STATUS. JOB COMPLETE. SET 7" A-1 INJECTION VALVE @ 2,212' SLM. (SERIAL# HVS-399). GOOD CLOSURE TEST. RDMO. 01/30/04 T/I/O= SSV/O+NAC. TEMP=SI. MONITORED WHP'S (PRE INJ). DSO TO PUT ON INJECTION. INSTALLED HEATER ON CELLAR LANDING NIPPLE. IA AND OA FL'S SURFACE. 01/31/04 T/I/O= 350010+10+. TEMP= HOT. (PREP FOR TOP JOB). REMOVED 5" BULL PLUG ON SURFACE CASING. TAGGED BOTTOM OF SURFACE CASING AT 75'. FLUID LEVEL APPEARED TO BE AT 101 FROM SURFACE. RE-INST ALLED BULL PLUG. TREE :::. McEVOY WELLHEAD ::: McEVOY ACTUATOR::: AXELSON KB. ELEV::: 61' BF. ELEV::: ? KOP::: 0' Max Angle ::: 1 @ 8300' Datum MD ::: NIA Datum lVD ::: 8800' SS WGI-05 I Cement Top -500' 113-3/8" CSG, 68#, L-80, ID::: 12.415" I 17-5/8" TBG-IPC, 29.7#, L-80, .0459 bpf, 10::: 6.875" I Minimum ID = 4.455" @ 7855' 5.1/2" HES XN NIPPLE TOPOF 7" LNR I 19-5/8" CSG, 47#, L-80, ID::: 8.681" I PERFORATION SUMMARY REF LOG: SWS CET ON 03/06/90 ANGLE AT TOP PERF: 1 @ 8184' Note: Refer to A'oduction DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 3-3/8" 4 8184-8220 0 6/4/1990 3-3/8" 4 8274-8306 0 6/4/1990 3-3/8" 4 8319-8346 0 6/4/1990 3-3/8" 4 8348-8476 0 6/4/1990 3-3/8" 4 8484-8518 0 6/4/1990 3-3/8" 4 8522-8542 0 6/4/1990 3-3/8" 4 8554-8613 0 6/4/1990 3-3/8" 4 8620-8633 0 6/4/1990 I 7" LNR, 29#, L-80, .0371 bpf, ID::: 6.184" I -i9 5/8" Csg, 47#, NT-95 HS NSCC -i 95/8" Csg, 47#, L-80 BTC-Mod -i 7" CAMCO "OB" NIP, 10::: 6.000" I I I 7-5/8" X 7" X-OV ER 7" HES "R" NIP, 10 ::: 5.963" -19-5/8" x 7" SABL-3 PKR, 10::: 6.00" 1-1 7" x 5-1/2" X-OV ER -15-1/2" OTIS "X" NIP, 10::: 4.562" 5-1/2" OTIS "XN" NIP, ID::: 4.455" 5-1/2" Mule Shoe ?f37Dt C,;\~¿ 0 v..-t I ~81S6. I" Top of 9~1t 01019' DATE REV BY COMMENTS OATE REVBY COMMENTS 03/02/90 ORIGINAL COMPLETION 04/11/03 JRClKK CASING CORRECTION 01/17101 SIS-SL T CONVERTED TO CANVAS 02/02/01 SIS-LG REVISION 11/03/01 RN/TP CORRECTIONS 03/23/03 JMP/KK SAFETY NOTE REV IS ION 03/25/03 JLA/KK CSG & SAFElY NOTE REV. PRUOHOE BAY UNrT WELL: WGI-05 PERMIT No: 1900250 API No: 50-029-22015-00 SEe 11, T11N, R14E, 1077.09' FEL & 1102.97' FNL BP Exploration (Alas ka) t' STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: [] Abandon [] Suspend [] Operation Shutdown [] Perforate [] Variance [] Other [] Alter Casing [] Repair Well I-I Plug Perforations [] Stimulate [] Time Extension [] Change Approved Program [] Pull Tubing [] Perforate New Pool [] Re-Enter Suspended Well [] Annular Disposal 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. [] Development [] Exploratory 190-025 .'"" 3. Address: [] Stratigraphic [] Service 6. APl Number: / P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22015-00-00 7. KB Elevation (ft): RKB = 61' 9. Well Name and Number: PBU WGI-05 8. Property Designation: 10. Field / Pool(s): ADL 028302 Prudhoe Bay Field / Prudhoe Bay Pool 1:!1.' ' ' :. PRESENTWELL COND.ITIONSUMMARY ;: ': , , : Total Depth MD (ft): Total Depth TVD (ft): [ Effective Depth MD (ft): [Effective 'Depth TVD (ft): 'Plugs (measured): Junk (measured): 8728 8728 [ 8686 [ 8686 None None i:;Cas'i ng: ::,,. ~, ,, ', ,,,;,~:~:,/i,, :,,!,;i' i~'L~'n~:th:'i:: , ,: :, :~:::::i,': :i= ?:::::; i i::'= =,size':,:,::i; !: iii,!:, ;:,ii;,; ::::: i:,:: = i~ ::!:i; ,.: ?,; ::: ~',;',' !i:iM:,Di;: ::,,: ::=~! iI ::i :i i i,;, ;i: :,!;,' ;' ::. :: :~VD::.,'!(: I: :,: :'! '! i': ; :!::,,:~ i: :i, ;,!/: :=: ::BUtUt :: :' :,,::::i i:: ,': ::':: ': c ella pse Structural Conductor 110' 20" 110' 110' 1530 520 Surface 3494' 13-3/8" 3494' 3494' 3450 1950 Intermediate 8164' 9-5/8" 8164' 8164' 6870 4750 Production Liner 879' 7" 7849' - 8728' 7849'- 8728' 8160 7020 , ,, ,,,,,, Perforation Depth MD (ft): I Perforation Depth TVD (,):I Tubing Size: Tubing Grade: I Tubing MD (ft): 8184'- 8633' 8184'- 8633' 7" 26# x 4-1/2" 12.6# L-80 7865' Packers and SSSV Type: 9-5/8" x 5-1/2" Baker 'FB-I' Permanent Packer; Packers and SSSV MD (ft): 7800' 7" Camco 'BaI-O' SSSV Nipple 2202' 12. Attachments: 13. Well Class after proposed work: [] Description Summary of Proposal [] BOP Sketch [] Detailed Operations Program [] Exploratory [] Development [] Service i 4. Estimated Date for /,'" 15. Well Status after proposed work: Commencing Operations: December 1,2003 [] Oil [] Gas [] Plugged [] Abandoned i6. Verbal Approval: Date: [] WAG [] GINJ [] WINJ [] WDSPL Commission Representative: 17. I hereby certif~hat the foregoing is true and correct to the best of my knowledge. Contact David Ream, 564-5743 Printed Nam~ Ipavid Re,~n Title Drilling Engineer : .' ':: . i ' ::: i .:: '.i '. i: :: ic0m.mission use'only .' ... .: - ~" -!' ~' I Sundry Number: Conditions of approval: Notify Commission so that a representative may witness , [] Plug Integrity [] BOP Test I~r Mechanical Integrity Test [] Location Clearance re~, ' ~ ;. ,, , .-. ~-,,. ,.: ,,,, / Other: NOV 0 3 . Subsequent form required 10- ¢.../O~:./"' NOV 4 2003 0it $ Cons. ,Anchorage ,,,Approved By: ," "~'---,~ COMMISSIONER THE COMMISSION Date Form 10-403 Revised 2/200~ t" wc -os Workover Scope CURRENT STATUS: WGI-05 is shut-in with robing x inner annulus communication and slow inner annulus x outer annulus communication. The top joint of' 13-3/8" is K-55 grade which limits outer annulus pressure testing to 3000 psi. OBJECTIVES: A. Increase injection capacity by replacing the existing 7" internally plastic coated robing and 4-1/2" tailpipe with 7-5/8" internally plastic coated robing with premium connections and a 5-1/2" tailpipe. B. Replace the top joint of 13-3/8" surface casing (K-55 grade) with a new joint of 13- 3/8" surface casing (L-80 grade). TREE = IVb EVOY WGI 05 s .o-r s= ACTUATOR = AXELSON' '"" DO NOT PRESSURE OA ABOVE 3000 PSI. KB. ELEV = 6T BF. ELEV = ? i KOP = 0' Ua., Ang,~ = 1 ~ 8300' Datum'lVD = 8800' SS 113-3/8"cs~,68#. K-s5,~D=12.41~' ~ 74' I la-3/8" cSG, 6~, C-80, rD= ~2.415" ~ ' 7~00' 1--19-5~"XS-~/2"BKam-IPmUPKRI Minimum ID = 3.?25" @ ?853' , 4-112" OTIS XN Nl~l.l:: ITOF'O~*I/2"~-IF'CI--I 782o' I--- ~t 7820' I-I?-~,~"x,,-,,~"xol ~ 7884' /2" 4'1/2'' TRG';'c' 12'6#' L'~°' '°'~ 52 bpf' D = 3'958'' I ~'-[--L~[--.F-'-~ 1 9-5/,' csG, 4~#, L-80, ~-8.~1" I-t 8384' ~EF~OR~ TION SUMM~ RY REF LOG: SWS ~T ON 03/06/90 ANGLEATIOP PERF: 1 @ 8184' NOto: R~er to R'oductbn I~ for historical porf data SEE SPF IN3ERVAL Opn/Sqz DATE 3-3/8" 4 8184-8220 O 06/04/90 3-3/8" 4 8274-8306 O 06/04/90 3-3/8" 4 8319-8346 O 06/04/90 3-3/8" 4 8348-8476 O 06/04/90 3-3/8" 4 8484-8518 O 06/04/90 3-3/8" 4 8522-8542 O 06/04/90 3-3/8" 4 8554-8613 O 06/04/90 . 3-3/8" 4 8620-8633 O 06/04/90 i I"~*° H s~' I I DATE REV BY COMIVENTS DATE REV BY COMMENTS I PRUDHOE BAY UNIT 03/02/90 ORIGINAL COMPLETION 04/11/03 JRC/KK CASING CORRECTION WELL: WGI-05 01/17/01 SIS-SLT CONVERTED TO CANVAS 08/24/03 JRC/KK WELLHEAD CORRECTION PERMIT No: 1900250 02/02/01 SIS-LG REVISION APl No: 50-029-22015-00 11/03/01 RN/'rP CORRECTIONS SEC 11, T11 N, R14E, 1077.09' FEL & 1102.97' FNL 03/23/03 JIVP/KK SAFE'rY NOTE REVISION 03/25/03 JLA/KK CSG & SAFETY NOTE I;~'V. BP E~ploration (Alaska) PEF;FORA TION SUMMA RY REF LOG: SWS CET ON 03/06/90 ANGLEATTOP PERF'.' 1 @ 8184' Note: Refer to R'oductbn IDB for historical perf data SEE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 8184-8220 O 06/04/90 3-3/8" 4 8274-8306 O 06/04/90 3-3/8" 4 8319-8346 O 06/04/90 3-3/8" 4 8348-8476 O 06/04/90 3-3/8" 4 8484-8518 O 06/04/90 3-3/8" 4 8522-8542 0 06104190 3-3/8" 4 8554-8613 O 06/04/90 3-3/8" 4 8620-8633 O 06/04/90 DATE REV BY COMIVENTS DATE REV BY COIVlMENTS 03/02/90 ORIGINAL COMPLErlON 04/11/03 JRC/KK CASING CORRECTION 01/17/01 SIS-SLT CONVERTED TO CANVAS 08/24/03 JRC/KK WELLHEAD CORRECTION 02/02/01 SIS-LG REVISION 11/03/01 RN/'rP CORRECTIONS 03/23/03 JIVP/KK SAFE'rY NOTE REVISION 03/25/03 JLA/KK CSG & SAFETY NOTE I::ac-'V. • • Maunder, Thomas E DOA From: NSU, ADW Well Integrity Engineer [ NSUADWWellintegrityEngineer @BP.com] Sent: Sunday, January 12, 2003 7:54 PM To: Maunder, Thomas E (DOA) Cc: Regg, James B (DOA); 'NSU, ADW Well Integrity Engineer' Subject: Information concerning BP Internal waivers at NGI and WGI Tom and Jim, k' — Q� Please see the information that you requested concerning the gas injection wells with BP internal waivers below. NGI -07: Waivered for production casing leak on 10/23/90. Records indicate on 8/20/90, the IAP was pressured to 2200 psi when it suddenly dropped to 2100 and started falling. A CMIT TxIA conducted 10/08/90 failed to hold 2500 psi. MITIA's routinely pass to 2000 psi, the most recent was on 06/02. WGI -04: Waivered for slow IAxOA comm on 4/28/00. MITIA passed 10/02 to 2650 psi. OA re- pressure review conducted 12/02 indicates the IAxOA communication is no longer present. WGI -05: Waivered for slow IAxOA comm on 5/12/00. MITIA passed 06/02 to 2060 psi. OA re- pressure rate not recently quantified. TIO trends indicate IAxOA comm is still present. If you have any questions, or would like to discuss in greater detail, please let me know. Thanks, John Cubbon GPB Well Integrity Coordinator 1- 907 - 659 -5102 pgr. 659 -5102, x. 1154 �Ef 7 t ll9 - - - -- Original Message---- - From: Tom Maunder [mailto:tom maunder @admin.state.ak.us] Sent: Tuesday, December 24, 2002 9:41 AM To: Cubbon, John R Cc: Jim Regg (E- mail); NSU, ADW Well Integrity Engineer Subject: Re: NGI -11 (PTD 41770800) OA pressurization John, We have received you message with regard to NGI -11. We are frankly surprised that you would propose to evaluate this well for an internal waiver. I seem to remember some discussions with regard to a couple of WGI wells that may have BP's internal waivers. Would you please provide a listing of the gas injection wells (NGI, WGI, AGI, LGI) that may have internal waivers and the reason a waiver is necessary. Although you indicate in your action plan that you plan to perform MITs and then evaluate the well for the internal waiver. We suggest that you also look into repairing the well. Tom Maunder, PE AOGCC " Cubbon, John R" wrote: > Hi Tom and Jim, • The NGI pad operator has notified us that the bleed frequency for the • OA 1 at • 0 > NGI -11 has increased recently. A brief history of events is as follows: > > 05/02/00: MITIA Passed to 3000 psi. > > 02/08/02: MIT IA Passed to 3000 psi. Investigate high IAP > > 10/19/02: DSO reported OA had jumped from 1600 to 2100 psi > > overnight. IA > gauge on wellhead shows 200 psi higher than test gauge. > > 10/20/02: PPPOT -T PASSED > > 12/22/02: PPPOT -IC PASSED > > 12/23/02: OAP increased 750 psi in 2 days. • As you can see from the attached TIO plot, since October 2002 the OA • repressurization rate for this well has increased. The source of the • pressure in the OA does not appear to be communication through the wellhead > (passing PPPOT -IC). > Our plan of action is as follows: > 1. MITIA to 3000 psi with the OA bled down to < 500 psi. > 2. MITOA to 3000 psi. > 3. Evaluate for an internal waiver to allow OAP to go to a maximum of > 2000 psi. • Please let me know if you would like us to procede in a different • manner or > if more information is required. > Thanks, • John Cubbon • GPB Well Integrity Coordinator • 1- 907 - 659 -5102 • pgr. 659 -5102, x. 1154 > «NGI -11 TIO.jpg>> «NGI- ll.pdf>> «NGI -II Inj. plot.jpg » > ------------------------------------------------------------------------ > Name: NGI -11 TIO.jpg > NGI -11 TIO.jpg Type: JPEG Image (image /jpeg) > Encoding: base64 > Name: NGI- ll.pdf > NGI- ll.pdf Type: Acrobat (application /pdf) > Encoding: base64 > Name: NGI -II Inj. plot.jpg > NGI -II Inj. plot.jpg Type: JPEG Image (image /jpeg) > Encoding: base64 2 • • Page 1 of 1 Maunder, Thomas E (DOA) From: NSU, ADW Well Integrity Engineer [ NSUADWWelllntegrityEngineer @BP.com] Sent: Sunday, October 20, 2002 3:54 PM To: Maunder, Thomas E (DOA) Cc: 'jlanders @alaska.net' Subject: Information concerning internal waivers on injectors, and information about WGI -04 and WGI - 05 Attachments: WGI- 04,05.ZIP; Waiver'd injectors.xls Hi Tom, Please see the attached spreadsheet and Word document for the information that you requested concerning BP's internally waivered wells and the WGI -04 an WGI -05 wells. Joe Anders has gathered some additional information to present to you and he will likely be contacting you on Monday, October 21, 2002 in order to set up an appointment. Please let me know if you have additional questions or need additional information. Best Regards, John Cubbon Well Integrity Engineer 659 -5102 Maunder, Thomas E (DOA) From: Tom Maunder [tom_maunder @admin.state.ak.us] Sent: Monday, October 21, 2002 5:40 PM To: 'Cammy Oechsli; 'Mike Bill'; Regg, James B (DOA) Subject: [Fwd: Information concerning internal waivers on injectors, and information about WGI -04 and WGI -05] Attachments: Information concerning internal waivers on injectors, and information about WGI -04 and WGI -05; tom_maunder.vcf O L,J Information tom_maunder.vcf :oncerning interns.., Here is the info I received in answer to my email. Tom • • Review of Ann -Comm Activities at WGI -04 and WGI -05 WGI -04: OA wavier for 2000 psi service, dated 4/28/00 > 04/07/99: Checked IAxOA packoff - bled off & did not build up. > 08/01/99: MITIA / MITOA Passed. > 03/17/00: DSO bled OA 1000 /550, monitored buildup rate > 05105100: DSO bled OA 2200/800 psi > 05/06/00: Distributed OA waiver > 08/09/00: MITIA, MITOA passed WC > 11/14/00: Bled IA 2000/1500, OA 1800/1000 > 02/11/01: DSO bled IA 2200/1600 > 06/14/01; DSO bled IA 2100/1580, bled OA 2100/1500 > 07/17/01: DSO bled IA > 09/26/01: MIT IA & MIT OA Passed (WC) > 12/27/01: DSO bled IA 2150/1500, bled OA 2150/1350 > 01/26/02: Valve Shop pumped 5 gallons GX down control line, did not see a pressure increase. > 02/03/02: DSO bled IA 2200 to 1500 psi, gas > 02/07/02: SL R &R SSSV - Control line would hold pressure > 02/08/02: DSO bled IA 2200 > 1700 > 02/10/02: DSO bled IA 1900/1400, Bled OA 1400/800 > 02/14/02: Monitor IAP > 02/15/02: PPPOT -T & PPPOT-IC Passed > 06/02/02: DSO bled gas from IA 2150 > 1150, Bled OA 1900 > 1200 > 06/13/02: DSO bled IA 2200 >1400 WGI-04 Annulus Pressures { -0- TW o 1 N C p 5 # I ry a { o { o i i . 1018t2001 1P184002 4f18P002 7118!2002 10118/2002 WGI -05: OA wavier for 2000 psi service, dated 5/12/00 > 02/07/99: Valve shop pumped 4 gal of GX Sealant down Balance line. Did not pressure up. • 02/14/99: Ran re- packed SSSV; tested OK 2600/2200/2200 psi. • 07/29/99: DSM added GX Seal, cntl line held 4950 psi for 15 min. Per DSO notes, GX no help, WL time. > 07/31/99: Called DSM to re -apply GX. Cntl line tracks tbg, Bal line tracks IA, indicates upper set (of 3) packing is leaking. Pull and redress SSSV if GX fails. MITIA & MITOA Passed. > 8/13/99: DSM removed GX Sealant set -up. Seems to be holding good. > 08/23/99: SSSV pulled, ran WRDP with 3 sets packing. Bal would not hold. > 02/04/00: IA/OA 1680/1600 > 02/08/00: Loaded well with water wash, PPPOT -IC PASSED > 03/17/00: DSO bled OA 1100 /500 > 04/06/00: DSO bled OA 1100/700 psi > 04/13/00: DSO bled IA 1400/650, OA 1000/400 > 04/26/00: DSO bled OA 1300/500 > 04/30/00: DSO bled IA 1500/750, OA 1100/750 > 05105100: DSO bled IA & OA 1200/600 psi > 06/05/00: DSO bed IA 2075/1200, OA came down 1725/1600 > 09/01/00: DSO bled IA 2100/1500, OA 2000/1500 (MIT's (P) 08/08/00) > 11/18/00: Valve shop pumped GX into balance line > 08/15/01: MIT OA Passed > 08/25/01: AOGCC MIT IA Passed > 11/14/01: DSO bled IA 2200/1700 - OA 2200/2000 > 11/15/01: PPPOT -T Failed > 11/22/01: Bled down high OAP 2000 > 350 > 12/07/01: DSO bled IA > 01/21/02: CO ISSSV > 06/01/02: MITIA PASSED to 2060 psi ( AOGCC -J. Crisp) > 06/09/02: MITOA PASSED to 2000 psi (WC) > 08/09/02: Valve shop pumped GX sealant down the control line. > 08/17/02: Bled IA from 2230 psi to 400 psi and OA from 2070 to 350 psi. Valve crew called out to pump GX sealant into balance line. > 08/18/02: IAP gained 1200 psi and OAP gained 230 psi since yesterday. > 08/20/02: SL changed out SSSV in an effort to stop leakage past packing and into the IA. > 08/21/02: Bled OAP > 10/16/02: T /I /O = 3650/260/230 psi. 0 • 0 WGW5 Annulus Pressures ' o 0 a Tbg � I I m L i E N QQ IA g� a I OA 10118720[11 1 A 88002 4/18/2002 7118/2002 10f Bf"2 i 1/3 GPB AOGCC Sundry & Waivered Wectors Revised: 10/20/02 AOGCC Sundry 300 -198, Slow TAA comm 01 -08 11ni YES TAA Slow 12 48 12 Y YES 8/15/00 01 -09A IN YES - PC leak IAxOA 48 12 12 IYES AOGCC Sundry 300 -107, PC Leak 5/9/00 AOGCC Sundry #300 -106, IAxOA comm, 03 -10 In' YES IAxOA 24 YES 5/9/00 AOGCC Variance #399 -084, Rapid TxIA comm 03 -11 In' YES TxIA rapid 24 YES 5/21/99 • 03 -33 In' NO TAA 12 12 Waivered, Slow TAA comm to MI 9/12/96 04 -11A IN Iln TAA Slow I YES AOGCC Sundry in progress, Slow TAA comm AOGCC Sundry 301 -162, Rapid TxIA comm 04 -17 In' YES TxIA 241 1 1 IYES 10/11/02 04 -28 In' INO TAA 12 Waiver, TxIA comm 11/6/90 04 -42 In' IYES TAA 24 YES IAOGCC 302 -059, TxIA comm 2/19/02 04 -45 In' IYES TAA 24 YES AOGCC 300 -173, TxIA comm 7/5/00 09/12 In' INO TAA - MI 24 24 Waiver, TAA comm when on MI 3/15/99 Waivered, TxIA comm [9/23/91] Possible IAxOA 09 -15 In' NO possible TxlAxOA 12 12 12 1 comm as well AOGCC Sundry 301 -351, Slow TAA comm 09 -37 In' YES TxIA Slow 48 12 1 YES 12/21/01 AOGCC Sundry 301 -350, Slow TAA comm 09 -40 IN YES ITAA Slow 12 48 12 YES 12/21/01 AOGCC Sundry 9 -490, Slow TxIA comm 11 -10 IN YES -Slow TxIA IAxOA 12 l 1/30/901 Possible IAxOA comm not TxIA comm AOGCC Variance #398 -035, Slow TAA comm 11 -29 In' IYES TxIA Slow 48 12 YES 2/22/98 Waivered, Slow TxIA comm to MI [5/17/00] Possible slow IAxOA comm, Need to remove 12 -02 FIN NO IAxOA Slow 12 12 waiver on TAA comm AOGCC Sundry # 301 -244, TxIA comm 12 -21 YES TAA 241 121 1 YES ri 0/16/01 12 -23 In' IYES IAxOA Rapid 24 YES AOGCC 300 -174, Rapid IAxOA comm 7/5/00 13 -09 In' YES TxIA Rapid 24 YES AOGCC 301 -159, Rapid TAA comm 10/11/01 13 -15 In' YES TxIA 24 YES AOGCC 399 -091, TAA comm 6/16/99 13 -31 In' YES TxIA Rapid 24 YES AOGCC 300 -188, Rapid TxlA comm 8/1/00 14 -14 In' YES TxIA Slow t48 48 12 YES AOGCC 300 -199, Slow TxIA comm 5/9/00 14 -21 In' YES TxIA Ra id 24 YES AOGCC 399 -248, Ra id TAA comm 12/17/99 I AOGCC Sundry- Waivered Injectors 2/3 L �'T ? r -llt .• 711 i11�fNfM11 '_ Waiver, AOGCC verbal approval, TxIA comm when on MI [3/2/93] Possible IAxOA comm 16 -02 In' NO Possible TxIAxOA 1 12 12 121 1 and /or PC Leak Waiver, AOGCC verbal approval, TxIA comm 16 -03 In' NO Possible TxIAxOA 12 12 12 12 when on MI [8/9/931 Possible IAxOA comm AOGCC verbal approval; TxIA comm when on MI [2/22/94] Evidence of comm non - existent, 16 -05 In' NO TxIA - MI 12 12 12 need to cancel verbal sund Waiver, wtr &MI injection, Slow IAxOA comm 17 -06 11ni NO IAxOA Slow 1 121 12 1 f2/26/991 • AOGCC Sundry in progress, TxIA comm, A -05 In' In Progress TxIA YES LLR =.83b m @ 2750 psi AOGCC Sundry #301 -245, Rapid TxIA comm A -17 In' YES TxIA Rapid 24 YES 10/16/01 A -31 IN YES PC Leak 24 12 12 YES AOGCC 300 -008, PC Leak 1/10/00 AOGCC verbal approval, TxIA comm (possible leak @ bottom connection of upper packer) L -108 IN NO TxIA 6 1 10/02/02 LPC -01 In' NO PC Leak 12 Waiver, Small Packer Leak 7/12/93 AOGCC Sundry #302 -169, Rapid TxIA comm M -30 In' IYES TxIA Rapid 24 IYES 6/6/02 NGI -07 In' INO PC Leak 12 Waiver, PC Leak NK -65 In' IYES TxIA Rapid 24 YES AOGCC 302 -168, Rapid TxIA comm 6/6/02 AOGCC Sundry #302 -016 expires 10/31/02, NS -29 In' YES I TAA Slow 1 241 1 121 1 3 1 Slow TxIA comm 2/19/02 AOGCC Sundry #302-017 expires 10/31/02, NS -31 IN YES TxIA Slow 24 1 12 3 Slow TxIA comm 2/19/02 P1 -01 In' YES TxIA Rapid 12 YES AOGCC 398 -188, Rapid TxIA comm 7/22/98 AOGCC Sundry 300 -038, Rapid TxIA comm P -14 In' YES TxIA Rapid 24 YES 2/10/00 Waiver, TxIA comm on MI, Waiver needs updating /canceling for WAG injection, No P2 -29 In' NO 1 12 evidence of TxIA comm AOGCC Sundry # 301 -246, Rapid TxIA comm P -23 In' IYES TxIA Rapid 241 1 IYES 10/16/01 AOGCC Sundry #398 -243, Slow TxIA comm P2 -34 In' YES TxIA Slow 24 12 1 12 YES [9/23/981 Possible IAxOA comm Not a waiver; TxIA and Low OA FL, MONITOR S -25 In' NO TxIA, Low OA FL 6 6 Y LTSI TROUBLE WELL Waiver, Slow TxIA comm [5/13/01] Currently SI, S -31 In' NO High IAP 12 Possible high IAP AOGCC Sundry # 301 -160, Slow TxIA comm U -05 In' YES TxIA Slow 48 12 Y YES 110/16/011 Currently SI AOGCC Sundry # 302 -170, Slow TxIA comm W -42 In' YES TxIA Slow 48 12 1 1 1 1 YES 1[6/6/021 Possible IAxOA comm WB -06 In' I In Progress TxIA Slow I JAOGCC Sundry in progress, Slow TxIA comm AOGCC Sundry- Waivered Injectors 3/3 M014 HLY r� I15i1 ilt�' ; ht riT1#17"1 Ft.I+tF 1* pM�ab id {y4 F �ls ! I# 11 #11J4L +Cf1�AM�1l+t I WGI -04 In' NO IAxOA 12 12 Waiver, IAxOA comm 4/28/00 WGI -05 IN NO IAxOA 12 12 X X Waiver, IAxOA comm 5/12/00 AOGCC Sundry # 301 -068, Slow TAA comm Y -03 In' YES TAA Slow 48 12 YES 4/27/01 AOGCC Sundry #300 -103, Rapid TAA comm Y -10 In' YES TAA Rapid 24 YES [4/20/00 AOGCC Sundry- Waivered Injectors Maunder, Thomas E (DOA) From: Tom Maunder [tom_m au nder@ad min. state. ak.us] Sent: Wednesday, October 16, 2002 5:06 PM To: 'Joe Anders /Kevin Yeager'; 'Kira Barton' Cc: Regg, James B (DOA) Subject: WGI -04 an WGI -05 Attachments: tom_maunder.vcf i Cl o— O a S7 Ai tom_maunder.vcf John, I was just looking at Jeff Jones reports of safety valve testing at WGI. He notes that the subject wells are on BP's internal waiver list for 9 -5/8" x 13 -3/8" communication. Please provide additional information with regard to the problems on these wells. This should include when the problem was noted, the diagnostics performed to determine the problem, what the IA and OA pressure history are, how often these annuli may require bleeding down. By copy of this email, you are also requested to provide a listing of ALL service wells that are presently waivered under BP's internal system. I will be out of town tomorrow and Friday. I would appreciate finding this information in my email box on Monday morning. Please call with any questions. Tom Maunder, PE AOGCC Maunder, Thomas E (DOA) From: Tom Maunder [tom_maunder @admin.state.ak.us] Sent: Wednesday, October 16, 2002 5:07 PM To: 'Cammy Oechsli'; Seamount, Dan T (DOA); 'Mike Bill'; DOA AOGCC Prudhoe Bay Subject: [Fwd: WGI -04 and WGI -051 Attachments: WGI -04 and WGI -05; tom maunder.vcf 0 L J WGI -04 and tom_maunder.vcf WGI -05 All, Enclosed is a note I sent to Joe /Kevin, et al. When Jeff went out for some safety valve tests at WGI he noted that these 2 wells were tagged indicating they are on BP's internal waiver system. This was news to me. Tom MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: camille O. Taylor Chair THRU: Tom Maunder P.I. Supervisor FROM: John Crisp Petroleum Inspector DATE: June 1, 2002 SUBJECT: Mechanical Integrity Tests BPX WGI 02,03,05 & .08 Prudhoe Bay Field Prudhoe Bay Unit NON- CONFIDENT.,.IAL 'Type INJ. ~luid COdes. ' ' F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING .......... Facke'r Depth ...... pretest Ini'tial" '15Min. 30'M'in. wa~I W:~o2,:'":iT~.pe lnj'I ' G!T.V.D.'I75~5 I Tubing i 3550:'i' 3556 '! "3550 P.T.D.i '1790.430 ,l.TY~te.stl, ''F~'' ITe~tpsii. 1.,8~.'i I Casingl-470-i 2490 I-2475-I 247;0' .!.. pIF"I .P Notes: 'we',[WG'I'-03'! Type inj. ! .... G ! T'v'D- i' ~255 ('Tubin';I i ~55~) I 355(~ I: 3550 I 3550" [l'ntervall 4 P','I'-D.i 1790490 !Typ(~testl ' P.l%si~gl'. 1 ...... ~0~4 l casin,~l-3'50I 2190 Notes: M°ni{ored pressure for one hour to confirm stabilization. . ' weul WGI-o5' IType Inj. [" G. i T'V'D: i :/'800 [' TUbing I 3550' 'l' 3550 P'T'D,'I 190,0250:lTypetes;(I 'P'I T~Si'~-'~!1950'lCa'singl 220' I 2066"!-2660[2000. '1 '~ii: !P Notes: Monitored pressure for 45 minutes to confirm stabilization. W3i!l' wGI-01~ I"l:ypelnj.[' :G "1 T'.v.D: i :'060 [~ubin.~l 3550 i 3550'[ '3550 P.T.,.D:,i...1.9,0.~490' ITY.pe testI P, .! Test'pSi i' '1915 !c,s~'i '~0.0I 2560. ! 2550 _1 2540 .... !. 'PIE, _! P-: Notes: Insignificant pressure loss of 20 psi. after 30 minutes. We, ll ' ,"-,,-I Type !nj. !. - .. ':' i T:.'.V..D' '1 '....l TUbing''[ '' ', ": l' . "1 ' ,, I," l~ntervfiii' P.T...D:[ .... l. Ty.pe.testi . . !Test psi l I Casing ! .... ! ,. i ...... I '.. I .... P/,F i. Notes: ....... T~;,'~"~ ..... ' ........................ i.i~.~i ........ M= Annulus'Monitoring I= Initial Test P= Standard Pressure Test 4= Four Year Cycle R= Internal Radioactive Tracer Survey V= Required by Variance A= Temperature Anomaly Survey W= Test during Workover D= Differential Temperature Test O= Other (describe in notes) Test's Details I traveled to BP's Prudhoe Bay Field to witness MIT's on WGI Pad. WGI-03 had starting pressure of 2550 psi. The first 20 minutes of 03's test the pressure dropped from 2550 to 2320 psi. The last 10 minutes of 03's test tho pressure dropped fxom 2320 psi to 2190 psi. The Operator asked ifI wanted to increase pressure back to 2500 psi on 03. I requested the Operator to m°nitor 03's test for another 30 minutes, w/o re-pressuring, to verify stabilization. The test pressures are recorded on the test form above. I witnessed no change on 05 until I tapped on the gauge after 30 minutes. I verified stabilization by witnessing no change in 05% pressure from 30 to 45 minutes. M.I.T.'s performed:. 4_ Attachments: Number of Failures: 0_. Total Time during tests: 3 hrs. cc: MIT report form 5/12/00 L.G. MIT PBU WG! 06-01-02jcl.xi$ 6/4/02 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Cammy O Taylor/~ DATE: August 25, 2001 Chair t. SUBJECT: Mechanical Integrity Tests Tom Maunder ~_~~.~ BPX THRU: P.I. Supervisor~,~..>~ ~3~::~ NGI & WGI NGI-01& 02 WGI-01,05 & 08 FROM: Chuck Scheve PBU Petroleum Inspector Prudhoe Bay NON- CONFIDENTIAL I Packer Depth Pretest Initial 15 Min. 30. Min. w~,I ,o,-o, Type,nj.I GI ~.V.O. I~ I Tubingl~0 I~0 I~0 I~0 I,.t~a,I a P'T'D'I 1750480 Typetestl P ITestpsil 1827 I Casingl 90 1220012180121801 P/F I E Notes: P.T.D.I 1750610 ITypetestl P ITestpsii 1843 I Casingl 0 I 2200 I 2180 I 2180 I P/F I __P Notes: w,,I wo,~, IType,nj.i G I ,.v.o. I~' I Tu"ngl 350oI.~o I ~o I ~o I,.t~va, I,4 P.T.D.I 1790310 ITypetestl P ITestps, il 1843 I CasingI 920 I 2100 I 2O8O I 2O00 I P/F I E Notes: w~,I wo,~ I Type,nj.I o I ~.~.~. i~ J TubingI ~ I ~o I ~ I ~ I'nt~a'lv P.T.D.I 1900250 ITypetestl P I Testpsil 1950 J CasingI 400 I 22O0 I 2100 I 2140 I P/F I E Heres: w~,I wo,~ I,~,,~.! o I ~.v.o.'l ~ I,u~,~ I ~o I ~,oo I ~. I~o I,~t~va,! o P.T.D.I 1900490 ITypetestl P ITestpsil 1915 I Casingl 700 I 22S0 I =~0 I 2240I P/FI E Heres: Annual MIT Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Vadance W= Test dudng Workover O= Other (describe in notes) Test's Details I traveled to BPXs NGI & WGI locations in the Prudhoe Bay field and witnessed the MIT on wells NGI-01, NGI-03, WGI-01, WGI-05 and WGI-08. The pretest pressures were observed and found to be stable. A standard annulus pressure test was then performed with all 5 wells demonstrating good mechanical integrity. M.I.T.'s performed: _.5 Attachments: Number of Failures: 0 Total Time during tests: 4 hours cc: MIT report form 5/12/00 L.G. MIT PBU NGI, WGI 8-25-01 CS.xls 8/30/01 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission THRU: TO: Julie Heusser, ~-~ DATE: Commissioner Tom Maunder, ~.~e~~ P. I. Supervisor~,, - FROM: John Crisp~ SUBJECT: Petroleum Inspector January 15, 200~ Safety Valve Tests Prudhoe Bay Field WGI Pad January 15, 2001' I traveled to BP's Prudhoe Bay Field to witness Safety Valve System testing on WGI Pad.. BP representative Bill Preston was in charge of SVS tests on WGI Pad. Testing was conducted in a safe & efficient manner. Two failures were witnessed. WGI 06 surface & sub-surface valves failed to hold DP. This well was shut in until rePaired & re-tested. The AOGCC test report is attached for reference. I inspected wellhouses on WGI Pad during SVS tests. All are clean & in good shape. SUMMARY: I witnessed SVS tests on PBU WGI Pad. 8 wells, 24components tested. 2 failures witnessed. 8.3% failure rate. 8 wellhouses inspected. Attachments: SVS PBU WGI Pad 1-15-01jc cc; NON-CONFIDENTIAL SVS PBU WGI Pad 1-15-01jc.doc Alaska Oil and Gas ConServation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Bill Preston AOGCC Rep: John Crisp Submitted By: John Crisp Date: Field/Unit/Pad: Prudhoe Ba7 Field WGI Pad Separator psi: LPS HPS 1/15/01 3400 Well Permit Separ Set L~ Test Test Test Date Oil, WAG, GmJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE WGI-01 1790310 3400 2900 2440 P P P GINJ WGI-02 1790430 3400 2900 2650 -P P P GINJ WGI-03 1790490 3400 2900 2350 P P P GINJ WGI-04 1790500 3400 2900 2350 P P P GINJ WGI-05 1900250 3400 2900 2500 P P P GINJ WGI-06 1900300 3400 2900 2460 P 4 9 GINJ WGI-07 1900400 3400 2900 2480 P P P GINJ WGI-08 1900490 3400 2900 2620 P P P GINJ Wells: 8 Components: 24 Failures: 2 Failure Rate: 8.3% E39o var Remarks: WGI-07 Shut in untill repaired & re-tested. 1/18/01 Page 1 of I SVS PBU WGI Pad 1-15-01jc.xls "ARCO ALASKA, INC. · '"~. ~ . ' .. P·O· BOX J,30360 ...................... R E.C.E.IVED'_ .... . ~ ' -. ~-~. , . "' dUN 1 1 1 91 , , ~. DATE: 6-J 3-9t .'¢' - . : .-;.~ ........... · : .......... :' ...;~ ............. ~ ................ ~s~ 0ii & Bas ~ons. ~om~issio. . ..~ ~chomge . ..... .- t 3~2A ..... 6-2-91 COLLAR-F'ERF-:--::'. .................. " · .... RUN .t.,. 5' - - - A~'LA~ . , · , ~%:' ~ i4't? ' 5-i6-~t ';>".'." INJ F'ROF .' '":_ ~?. ;.'> ;'~:" RUN t , 5' CAHCO '--t 4-2~: ........ 5-~ 6-9t--./<::~ .... INJ F'ROF'. ......L2=._~ ........................ .'?, , .......... RUN- t, -5' ......... CAMCO .t4-25 5-i~-~i .-.:'INJ PROF,GR' ' ' ~.:-. RUN t, 5' CAMCO . :...' , ..... :.---:-t 4-~6 ........ 5-t ~-9t ..... ::.-.[NJ_PROF ..... RUN t -, --5 ' ........ CAHCO - t 5, t ~ 5-t 7-?t ' "::':':PROD pROF'~- '.'.~--::'~::"}-.- ' '- -' RUN t , '5' ' CAHCO ... t6'-f.i- 5-2S-?t .........~...INJ-.PRO~, ..... L..' .............. ' RUN t , -5' CAHCO -'~~.~,-,l-~.t6-nn~, 5-23-?t PROD PROF .:;.":_" . "' RUN t, 5' CAHCO ?~ ' t6-24 ........ 5-i?-~t~,- .....~:-..F~ROD.PRO~-'---:--~; ..................:--/-'~-- .............. RUN ~., 5' ........ CAHCO ...'":'-J 7-2 ': 5-8-?t :.~':~':?'?:LEAK DETEr::?.; . .' ." .~?~?~'... "-.: ...RUN'. ~.'~.".2' . '_ -DETECt .'~' :"-.' t7.-i t '5-27-9t .:':~".~.~LEAK .'."Z':" ' RUN i ,' 5" CAMCO ..... -.-- ~',tT.~.t-.~ ...... '-5~-i t-~.~ ..... :ZL-PROD_.PROF~.z:.~'Z ....... ' .. ' ....'-.-~:~-'- ........ RUN .--t ,.-.5" ' ::C~NCO . "' ":-'-'~-:N6I~ '-.-;':":5-~ 2-9i .-:'::.'~?::INJ ' ' F' -'::'::~'~;'~-~"'"~: ' '"'~" " " ' .. FRO '- -:? '.~- ::: ~:- -. :' "RUN .:t ~ 5 ::.:-': . C~MCO lO,J~_---~[[:5'' '5-t2-~t '.-'.INJ F'ROF . ~:.LL'2.' .... ..... /: . RUN t, 5' C~MCO PL~-~,_'~= Z~iGN~ AND RETURN THE ATTACHED COF'Y ~,:?~' ~' RECEIPT OF DATA. ~;' ~: ' B Y - - ,._CEIV~D ... _ _ -- ' ~' "~'.-- ' ::.-'~?~-:?:?'-'' ::':<::':¢C':<"~':'~f?:'~ ~: ~ TRANS~ :~ t ~- :' "..--:'.;~. -,'j.. :.~:::._~ .::' ::.. - . -.. -: ........ ~ . . ~ ..~ . /.:.:,z_ - . ~,.,~:.~_ _ -.], . ~ ..... -~ .... .. -- - DI ~T-R I.BUTI ON ............................. ~ .................................. '" . ~- ..PHILLIP~ '. ............................. ................ : ........ ~ CENTR~L.-FILE~ ..... . ................ ~ .............. ' '" ~ CHEVRON ............ " F'~ ~ELL FILE~ ............... D & H R & D .................. ~ EXTENSION EXPLORATION ~ BF'X ................... '~ EXXON ..................... : ............. ~ ....... ~ ~T~TE .-O~..~LA~KA .............................................. H~R~THON TEX~CO .... ~ HOBIL ' - .............................. '- - 1 Status of Well Classification of Service Well REVISED** GAS INJECTOR OIL [--'] GAS E~ SUSPENDED E] ABANDONED E] SERVICE ['~ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 90-25 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22015 4 Location of well at surface ~ C(';,~{PL~TJ0J~ : 9 Unit or Lease Name 1080' FNL, 1035' FEL, SEC 11, T11N, R14E UM 1 ..~._~~ PRUDHOE BAY UNIT At Top Producing Interval i~ ' - 10 Well Number 1105' FNL, 1077' FEL, SEC 11, T11N, R14E UM**~,.... :~/~2~ED WGI-5 At Total Depth ~ 11 Field and Pool 1103' FNL, 1080' FEL, SEC 11, T11N, R14E UM** PRUDHOE BAY FIELD 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. PRUDHOE BAY OIL POOL RKB 61'**I ADL 28302 ALK 2313 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. I 15 Water Depth, if offshore 116 No. of Completions 02/16/90. 02/26/90. 06/04/90*I N/A feet MSLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 8728' MD & TVD 8686' MD & TVD YES ~ NO E] 2202' feet MD 1900' (approx) 22 Type Electric or Other Logs Run GR/ACCOUSTIC, ZDL/CNL/CAL/GR, CET/CBT/VDL/GR, GCT 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Bo'FrOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 SURF 110' 30" 2150# POLESET 13-3/8" 68.0# L-80/K-55 SURF 3494' 17-1/2" 2200 SX AS III & 650 SX CLASS G 9-5/8" 47.0# L-80 SURF 8164' ? 12-1/4" 450 SX CLASS G & 306 SX AS I 7" 29.0# L-80 7849' 8728' 8-1/2" 325 SX CLASS G 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: 8184'-8220'MD & TYD 7" / 4-1/2" 7865' 7800' 8274'-8306' 8319'-8346' 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 8348'-8476' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8484'-8518' N/A 8522'-8542' 8554'-8613' 8620'-8633' 27 N/A PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift. etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-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 NH $/2/g0. TUBING HUN 5/28/g0. PERFOHATED WELL 6/4/g0. . '~'~ STATE OF ALASKA A~, ,3KA OIL AND GAS CONSERVATION CO,viMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. TOP SADLEROCHIT 8272' 8272' GOC 8633' 8633' BASE SADLEROCHIT 8690' 8690' NONE 31. LIST OF ATTACHMENTS NONE 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~x~~ (~~ /' Title DRILLINGAN/~LyST Date 7-L~-~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion repeal 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 pedinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 __ ORIGIN ~'"'"' STATE OF ALASKA ~ · A~,~,SKA OIL AND GAS CONSERVATION C~,,vIMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well GAS INJECTOR OIL r--'l GAS r'-] SUSPENDED E~ ABANDONED F'"] SERVICE 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 90-25 3 Address 8 APl Number P.O. Box 100360,. Anchorage, AK 99510-0360 50-029-22015 4 Location of well at surface ~ 9 Unit or Lease Name 1080'FNL, 1035'FEL, SEC 11, T11N, R14E UM !'~~I '¢ER,/?ED1' PRUDHOEBAYUNIT At Top Producing Interval ! . _~ ~ 10 Well Number At ll~,,~Depth IO~__~ 11 Field and Pool " ~ FNL, ~'~' FEL, SEC 11, T11 N, R14E UM PRUDHOE BAY FIELD 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. PRUDHOE BAY OIL POOL RKB 52'I ADL 28302 ALK 2313 12 Date Spudded 02/16/90. 13 Date T.D. Reached 02/26/90. 14 Date Comp. , Susp. or Aband.06/04/90, I15 water Depth' if OffshOre N/A feet MSL 116 NO' Of cOmpletiOns 1 17TotalDepIh(MD+TVD) 18 Plug Back Depth (MD+TVD) 19 DirectionalSurvey 120 Depth where SSSV set 121 Thickness of permafrost 8728' MD & TVD 8686' MD & TVD YES ~-] NO i'--]I 2202' feet MDI 1900' (approx) 22 Type Electric or Other Logs Run GR/ACCOUSTIC, ZDL/CNL/CAL/GR, CET/CBT/VDL/GR, GCT 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Be'l-rOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 SURF 110' 30" 2150# POLESET 13-3/8" 68.0# L-80/K-55 SURF 3494' 17-1/2" 2200 SX AS III & 650 SX CLASS G 9-5/8" 47.0# L-80 SURF 8164' 12-1/4" 450 SX CLASS G & 306 SX AS I 7" 29.0# L-80 7849' 8728' 8-1/2" 325 SX CLASS G 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: 8184'-8220'MD & TVD 7" / 4-1/2" 7865' 7800' 8274'-8306' 8319'-8346' 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 8348'-8476' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8484'-8518' N/A 8522'-8542' 8554'-8613' 8620'-8633' 27 N/A PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OILGRAVITY-API (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 3/2190. TUBING RUN 5128190. PERFORATED WELL 6/4/90. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NNV~ Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. TOP SADLEROCHIT 8272' 8272' GOC 8633' 8633' BASE SADLEROCHIT 8690' 8690' NONE · · 31. LIST OF A'i-I'ACHMENTS COMPLETION WELL HISTORY~ GYROSCOPIC SURVEY (2 COPIES), ADDENDUM (SIGNED 6/20/90) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~-l~J~J~ j~-~/J ~__.~. Title DRILLING ANALYST Date ~'~,~-~'0 /i - / INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 WELL HISTORY ADDENDUM WELL WORK LOG Well # WGI-5 Work performed: INITIAL PERFORATIONS Cost: z0.J37_,t Date: 6/3/90-6/4/90 AFE: AS2017 Time 1600 1045 2215 2350 0115 O25O O425 0555 O740 0920 1100 1230 1355 1530 RU SWS. RIH w/gun #1, shoot f/ 8630-8633, 8522-8542. POH, all shots fired. RIH w/ gun #2, shoot f/ 8620-8630 (misfired), 8514-8518 (fired). POH. RIH w/ gun #3, shoot f/ 8603-8613, 8583-8603. RIH w/ gun #4, shoot f/ 8573-8583, 8554-8573. RIH w/ gun #5, shoot f/ 8504-8514, 8484-8504. RIH w/ gun #6, shoot f/ 8466-8476, 8446-8466. RIH w/ gun #7, shoot f/ 8436-8446, 8416-8436. RIH w/ gun #8, shoot f/ 8406-8416, 8386-8406. RIH w/ gun #9, shoot f/ 8376-8386, 8356-8376. RIH w/ gun #10, shoot f/ 8348-8356, 8326-8346. RIH w/ gun #11, shoot f/ 8319-8326, 8286-8306. RIH w/ gun #12, shoot f/ 8274-8276, 8210-8220. RIH w/ gun #13, shoot f/ 8200-8210, 8184-8200. RIH w/ gun #14, shoot f/ 8620-8630, 8276-8286. Pump 100 bbls 60/40 meth/wtr. Freeze protect WHP=1100. Summary: DRILLING SUPERINTENDENT 8620-8633 8554-8613 8522-8542 8484-8518 8348-8476 8319-8346 8274-83O6 8184-8220 POH,..all shots fired. POH; all shots fired. POH, all shots fired. POH, all shots fired. POH, all shots fired. POH, all shots fired. POH, all shots fired. POH, all shots fired. POH, all shots fired. POH, all shots fired. POH, all shots fired. POH, all shots fired. Well secured. Perforated all w/ 4 spf ARCO Oil and Gas Company Well History - Initial Report - Daily Instructlone: Prepare and submit the ~'~l.i!blt.Rll~ml" on the first Wednesday after a wall is spudded or workover operatione are started. Daily work prior to ~~l;d~be lummarizad on the form giving inclusive dates only. &l~[.~l~ ~_~:. - .~.. ICounty. perish or ~I~'H SLOPE District I Field ~"'~'~UU.I'tO]~ J:M~X -'~;'? ILease or Unit ADT.= 28302 I Auth. or W.O. n~$20i7 IT~"e _ COMPLETE I API: 50-029-22015 Istate AK Jw~-5 Operator Spudded or W.~[~ [Date 05/25/90 [Hour 2200 HRS Complete record f~zl~l~e~ r~d ,b) TEST BOPE' S Date and depth as of 8:00 a.m. 05/2,~/90 ( IARCO W.L Prior status it 21.0000 a W.O. 7"@ 8728' MW: 9.3 NaCl TD: 0 PB: 8686 SUPV: RWO 05/27/90 (7) TD: 0 PB: 8686 SUPV:RWO MOVE RIG FROM WGI-8. ACCEPT RIG 2200 HRS, 5/25/90. ND DRYHOLE TREE, NU BOPS. TEST BOPS. ~ DAILY:S10,952 CUM:$1,682,764 ETD:S1,900,000 EFC:$2,582,764 RIH W/7" TUBING 7"@ 8728' MW: 9.3 NaCl FIN TST BOPS. DISPLACE TOP 500' OF WELL W/8.5 PPG SEAWATER. RU ELECTRIC LINE. RIH W/8.5" OD GAUGE RING/JUNK BASKET. COULD NOT GET PAST 220' MD. POOH, RECVD CMT IN JB. RIH W/8.35" OD GR/JB TO 7848' MD (2 RUNS). RECVD CMT ON BOTH RUNS. RIH W/8.5" OD GR/JB TO 220' MD, COULD NOT GET DEEPER. RIH W/ 9-5/8" PERM PKR AND 4-1/2" TAILPIPE. SET PKR @ 7800' MD. POOH, RD EL. PRESS TST 9-5/8" CSG AND PKR TO 4000 PSI F/15 MIN. CHANGE RAMS TO 7" AND TEST. MU SEAL ASSEMBLY ON 7" TUBING AND RIH. NOTE: CAMCO 'BAL-0' SSSV @ 2202', BAKER 'FB-I' @ 7800', & TT @ 7865'. DAILY:S39,749 CUM:$1,722,513 ETD:S2,000,000 EFC:$2,522,513 The above is correct ~ ~,i_L~/~ Signature ~L~ For form prep~aratio~ and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Supt. AR3B--459-1-D INumber all dally well history forms consecutively las they are prepared for each well. I iPage no. ARCO ~.,,t and Gas Company Daily Well History-Final Report Instructions: Prepare and submit th~.~*~..'.l~ oft~the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be aub~lt~e~l~~,~r~g~ ~ sl,lapended for an indefinite or appreciable length of time. On workovers when an official teat is not blocks provided. The "Final Report" form may be used for reposing the entire completion,~.~~~~t~ test data in required upon ~.~-.~.?: ~ ' Accounting cost center code Field ~O~ Auth. or W.O~20~? ~Title CO~ ~[: 50-029-220~5 Operator A.RCO A.R.Co. W.~.21' 0000 Spudded or ~l~ Date 05/25/90 Date and depth Complete reco~.~d~/;~ d~r~ported as of 8:00 a.m. Old TD 05/28/90 ( 18 TD: 0 PB: 8686 SUPV:RWO Iotal number of wells (active or inactive) on this, ost center prior to plugging and I bandonment of this well our 2200 HRS IPrlor status if a w.o. I RELEASED RIG 7"@ 8728' MW: ~.5 Seawater RIH W/7" TUBING. STING INTO PKR ]~'D PRESS TST TO 500 PSI. SPACE OUT AND MU TBG HNGR. DISPLACE WELL W/8.5 PPG SEAWATER. FREEZE PROTECT TOP 2200' MD W/ DIESEL. LAND TUBING AND PRESS TST TBG AND ANN TO 4000 PSI F/30 MIN. AOGCC WITNESSED TST. SET BPV. ND BOPS, NU TREE. TST TREE TO 5000 PSI. PRESS TBG TO 5000 PSI TO SHEAR SUB IN PKR TAILPIPE. COULD NOT SHEAR SUB. SET BPV. RD, RELEASE RIG @ 0300 HRS, 5/28/90. DAILY:S363,231 CUM:$2,085,744 ETD:S2,500,000 EFC:$2,385,744 New TD Released rig Date Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data IPB Depth Kind of rig Well no. Date Reservoir Producing Interval Oil or gasTest time Production OII on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water *Ye GOR Gravity Allowable Effective date corrected The above is corre~ For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively les they ere prepared for each we . iPage no. Dlvldon of AtlantlcRk:hfleldCompany ORIGINAL SUB. SURFACE DIRECTIONAL SURVEY ~-----] UIDANCE ~ONTINUOUS [-~]OOL : ICROFILMED Company _. ARCO ALASKA, I NC.~_~ ... Well NameWGI-5 (1080' FNL,1035' SEC ll,TllN,R14E,UM) ii ii I IIi Field/Location PRUDHOE BAY, NORTH SLOPE, ALASKA ,. = i ii I I II I i i i II Job.. Refer. ence. No; 73851 WARNER Date ... ~ ..~:~ 7 - M A R - 9 0 Computed, By: ~' ..:..~,~ :::ii .~:~, ~ ~.~ :',<.~:~i~,. ~i~: ~ ' ~. ~ora~ K R U W E L L SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. WGI - 5 PRUDHOE BAY NORTH SLOPE, ALASKA SURVEY DATE: 07-MAR-Ig90 ENGINEER: D. WARNER METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 0 DEG ! MIN EAST COMPUTATION DATE: 23-MAY-90 PAGE ARCO ALASKA· INC. WG! - 5 PRUDHOE BAY NORTH SLOPE· ALASKA DATE OF SURVEY: 07-MAR-1990 KELLY BUSHING ELEVATION: 61.00 FT ENGINEER: O. WARNER INTERPOLATEO VALUES FOR EVEN 100 FEET OF HEASURED 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 0.00 0.00 -61.00 0 0 N 0 0 E 100.00 lO0.OO 39.00 0 9 N 60 18 W 200.00 200.00 139.00 0 14 S 47 20 W 300.00 300.00 239.00 0 6 S 30 22 W 400.00 400.00 339.00 0 22 S 22 39 W 500.00 500.00 439.00 0 14 S 72 53 W 600.00 599.99 538.99 0 18 S 8 59 W 700.00 699.99 638.99 0 19 S 66 12 W 800.00 799.99 738.99 0 20 S 5 47 W 900.00 899.99 838.99 0 19 S 64 50 W 0.00 0.00 0.00 N 0.00 E -0.11 0.00 0.11 N 0.03 W -0.04 0.16 0.04 N 0.32 W 0.29 0.39 0.29 S 0.46 W 0.50 0.44 0.50 S 0.74 W 0.89 0.38 0.90 S 0.94 W 1.39 0.61 1.39 S 1.24 W 1.61 0.41 1.61 S 1.52 W 2.16 0.38 2.16 S 1.82 W 2.39 0.73 2.39 S 2.07 W 0.00 N 0 0 E * 0.12- N 16 13 W 0.32 N 83 2 W 0.55 S 57 ZOW 0.89 S 55 43 W 1.30 S 46 lB W 1.86 S 41 38 W 2.22 S 43 26 W 2.83 S 4O 10 W 3.16 S 40 55 W 1000.00 999.99 938.99 1100.00 1099.99 1038.99 1200.00 1199.99 1138.99 1300.00 1299.99 1238.99 1400.00 1399.99 1338.99 1500.00 1499.98 1438.98 1600.00 1599.98 1538.98 1700.00 1699.98 1638.98 1800.00 1799,98 1738.98 1900.00 1899.98 1838.98 0 11 S 13 57 W 0 22 S .34 41 W 010 S 3 2 W 0 17 S 74 18 W 0 20 S 12 38 E 0 10 S 66 12 W 023 S 940 E 0 3 N 50 40 E 0 18 S 5 52 W 0 18 S 61 47 E 2.90 0.70 2.90 S 2.28 W 3.10 0.47 3.10 S 2.60 W 3.66 0.46 3.66 S 2.70 W 3.77 0.65 3.77 S 2.91 W 4.29 0.21 4.29 S 3.09 W 4.57 0.47 4.57 S 3.08 W 4.99 0.53 4.99 S 3.3! W 5.36 0.37 5.36 S 3.07 W 5.49 0.77 5.50 S 3.25 W 5.90 0.27 5.90 S 2.93 W 3.69 S 38 9 W 4.05 S 39 56 W 4.55 S 36 25 W 4.76 S 37 43 W 5.29 S 35 48 W 5.51 S 33 57 W 5.99 S 33 36 W 6.18 S 29 49 W 6.38 S 30 34 W 6.59 S 26 ,iT W 2000.00 1999.98 1938.98 2100.00 Z099.98 2038.98 2200.00 2199.98 2138.98 2300.00 Z299.98 2238.98 2400.00 2399.98 2338.98 2500.00 Z499.97 2438.97 2600.00 2599.97 253B.97 2700.00 2699.97 2638.97 2800.00 Z799.97 2738.97 2900.00 2899.97 2838.97 020 S 10 7 W 0 25 S 56 56 E 0 8 S 34 52 W 0 20 S 83 39 E 0 4 S 35 47 E 020 ST0 0 E 0 13 S 65 28 E 0 26 S 42 26 E 0 16 S 16 31 E 0 31 S 47 28 E 6.20 0.51 6.20 S 2.91 W 6.79 0.39 6.79 S 2.60 W 6.98 0.45 6.99 S 2.35 W 7.30 0.43 7.30 S 2.20 W 7.23 0.45 7.23 S 1.75 W 7.55 0.29 7.55 S 1-56 W 7.57 1.20 7.57 S 1.00 W 8.03 0.52 8.03 S 0.78 W 8.4! 0.73 8.41 S 0.20 W 9.06 0.59 9.06 S 0.09 E 6.85 S 25 9 W 7.27 S 20 59 W 7.37 S 18 37 W 7.63 S 16 47 W 7.44 S 13 38 W 7.71 S 11 /+1 W 7.64 S 7 31 W 8.07 S 5 34 W 8.42 S I 23 W '~ 9.06 S 0 32 E 3000.00 2999.96 2938.96 3100.00 3099.96 3038.96 3200.00 3199.96 3138.96 3300.00 3299.95 3238.95 3400.00 3399.95 3338.95 3500.00 3499.95 3438.95 3600.00 3599.95 3538.95 3700.00 3699.95 3638.95 3800.00 3799.95 3738.95 3900.00 3899.94 3838.94 029 S 3 0 E 0 37 S 37 40 E 0 24 S 12 31 W 0 13 S 45 38 E 0 13 S 28 5 W 0 7 N 88 25 W 0 19 S 0 32 E 0 31 S 35 31 W 0 32 S 59 7 W 041 S 64 12 W 9.63 0.27 9.63 S 0.50 E 10.58 0.33 10.58 S 0.89 E 11.20 0.34 11.20 S 1.08 E 11.77 1.06 11.77 S 1.CZ E 11.94 1.78 11.94 S 1.38 E 12.19 0.16 12.19 S 1.54 E 12.56 0.50 12.56 S 1.37 E 12.97 0.32 12.97 S 0.92 E 13.59 0.68 13.59 S 0.38 E 14.24 1.07 14.24 S 0.57 W 9.64 S 3 0 E 10.61 S 4 48 E 11.25 S 5 31 E 11.85 S 6 52 E 12.01 S 6 35 E 12.29 S 7 13 E 12.63 S 6 13 E 13.00 S 4 4 E 13.60 S I 37 E 14.25 S 2 19 W ARCO ALASKA, INC. WGI- 5 PRUDHOE BAY NORTH SLOPE,~ ALASKA COMPUTATION DATE: 23-MAY-g0 PAGE DATE OF SURVEY: 07-MAR-1990 KELLY BUSHING ELEVATION: 61.00 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL OEVIATION AZIHUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0 47 S 74 18 W 0 44 $ 8t 16 W 0 51 S 75 55 14 0 48 S 73 6 W 0 49 S 74 59 W 0 53 S 72 56 W 0 51 S 71 13 W 0 54 S 75 46 W 0 38 S 87 52 W 035 S 79 14 W 4000.00 3999.93 3938.93 4tO0.O0 4099.92 4038.92 4200.00 4199.91 4138.91 4300.00 4299.90 4238.90 4400.00 4399.89 4338.89 4500.00 4499.88 4438.88 4600.00 4599.87 4538.87 4700.00 4699.86 4638.86 4HO0.O0 4799.85 4738.85 4900.00 4899.85 4838.85 5000.00 4999.84 4938.84 5100.00 5099.83 5038.83 5200.00 5199.8Z 5138.82 5300.00 5299.81 5238.81 5400.00 5399.81 5338.81 5500.00 5499.80 5438.80 5600.00 5599.80 5538.80 5700.00 5699.80 5638.80 5800.00 5799.79 5738.79 5900.00 5899.79 5838.79 6000.00 5999.78 5938.78 6100.00 6099.77 6038.77 6200.00 6199.76 6138.76 6300.00 6299.76 6238.76 6400.00 6399.75 6338.75 6500.00 6499.75 6438.75 6600.00 6599.75 6538.75 6700.00 6699.74 6638.74 6800.00 6799.74 6738.74 6900.00 6899.74 6838.74 7000o00 6999.74 6938.74 7100.00 7099.74 7038.74 7200.00 7199.73 7138.73 7300.00 7299.73 7238.73 7400.00 7399.73 7338.73 7500.00 7499.73 7438.73 7600°00 7599.73 7538.73 7700.00 7699.73 7638.73 7800.00 7799.73 7738.73 7900.00 7899.72 7838.72 0 37 S 78 40 W 0 33 S 77 55 W 0 44 S 75 8 W 031 S 77 8 W 0 37 S 68 17 W 0 28 N 72 57 W 0 27 S 73 19 W 0 36 S 61 13 W 0 24 S 71 46 W 0 45 S 70 16 W 0 37 S 59 1 W 0 48 S 58 13 W 0 33 S 53 11 W 0 29 S 75 7 W 0 27 S 50 23 W 0 37 S 52 6 W 018 S 71 47 W 0 18 S 45 29 W 031 S 30 OW 0 23 S 85 38 W ENGINEER: O. WARNER 0 22 S 31 32 W 030 S 54 6 W 0 21 N 88 21 W 0 17 S 3;? 51 W 0 26 S 33 20 W 0 18 N 85 25 W 0 17 S 58 7 W 027 S 56 6 W 0 37 N 86 2 W 0 30 N 59 15 W VERTICAL DOGLEG RECTANGULAR COORDINATES HDRIZ. DEPARTURE' SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET OEG MIN 14.66 0.88 14.66 S 1.90 W 14.81 1.46 14.81 S 3.35 W 14.88 0.45 14.88 S 4.78 W 15.00 0.16 15.00 S 6.07 W 15.Z0 1.29 15.21 S 7.36 W 15.42 O.BZ 15.43 S 8.60 W 15.85 1.20 15.86 S 9.96 W 16.37 1.57 16.37 S 11.29 W 16.78 0.70 16.78 S 12.54 W 17.13 1.10 17.14 S 13.73 W 17.37 0.97 17.38 S 14.82 W 17.70 0.37 17.71 S 16.06 W 18.08 1.61 18.09 S 17.41 W 18.25 1.44 1B.26 S 18.56 W 18.41 1.10 18.42 S 19.66 W 18.57 0.25 18.58 S 20.56 W 18.77 0.11 18.78 S 21.43 W 18.88 1.30 18.89 S ZZ.ZZ W 19.39 0.46 19.39 S 23.11 W 19.54 0.62 19.55 S 24.14 W 20.22 1.18 20.23 S 25.23 W 20.70 0.84 20.71 S 26.46, W 21.47 0.37 21.48 S 27.48 W 21.82 1.56 21.83 S 28.15 W 22.47 1.24 22.48 S 28.76 W 22.90 0.62 22.91 S 29.63 W 23.34 0.61 23.35 S 30.11 W 23.83 0.85 23.84 S 30.64 W 24.23 0.06 24.24 S 31.17 W 24.64 0.11 24.65 S 31.59 W 25.02 0.68 25.03 S 32.16 W 25.28 1.54 25.30 S 32.62 W 25.78 0.42 25.79 S 33.22 W 26.02 0.00 26.03 S 33.67 W 26.24 0.69 26.25 S 34.22 W 26.50 0.21 26.51 S 34.59 W 26.88 1.49 26.89 S 35.03 W 26.90 O.lZ 26.91 S 35.55 W 26.92 0.25 26.93 S 36.31 W 26.80 0.99 Z6.81 S 37.43 W 14.78 S 7 24 W · 15.19 S 12 45 W 15.63 S 17 48 W 16.18 S 22 2 W 16.89 S 25 50 W 17.66 S 29 9 W 18.73 S 32 9 W ~ 19.88 S 34 35 W 20.95 S 36 47 W 21.95 S 38 42 W 22.84 S 40 28 W 23.90 S 42 12 W 25.11 S 43 54 W 26.03 S 45 28 W 26.94 S 46 51 W 27.71 S 47 54 W 28.50 S 48 47 W 29.17 S 4,9 38 W 30.17 S 50 0 W 31.06 S 51 0 W 32.34 S 51 16 W 33.60 S 51 58 W 34.88 S 52 0 W 35.62 S 52 12 W 36.50 S 51 59 W 37.45 S 52 17 W 3B.10 S 52 12 W 38.82 S 52 7 W ) 39.49 S 52 7 W 40.07 S 52 2 W 40.76 S 52 6 W 41.28 S 52 12 W 42.05 S 52 10 W 42.56 S 52 18 W 43.13 S 52 30 W 43.58 S 52 32 W 44.16 S 52 29 W 44.58 S 52 52 W 45.21 S 53 26 W 46.04 S 54 23 W COMPUTATION DATE: 23-MAY-90 PAGE ' 3 ARCO ALASKA, INC. WGI - 5 PRUDHOE BAY NORTH SLOPE, ALASKA TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION aZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN DATE OF SURVEY: 07-MAR-lO90 KELLY BUSHING ELEVATION: 61.00 FT ENGINEER: O. WARNER INTERPOLATED VALUES FOR EVEN ZOO FEET OF MEASURED DEPTH VERTICAL DOGLEG RECTANGULAR COORDINATES HDRIZ. DEPARTURE. SECTION SEVERITY' NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 40 N 76 !5 g Z6.37 0.33 26.38 S 38.50 W 0 32 N 68 26 W 25.86 0.79 25.87 S 39.4Z W 0 57 N 57 35 W 25.15 0.03 25.16 S 40.49 W I I N 55 51 W 24.30 0.14 Z4.31 S ~.1.91 W 0 37 N 39 37 W 23°60 0.51 Z3.62 S 43.13 W 0 16 N 49 19 W 2Z.93 0.49 ZZ.94 S 43.71 W 0 9 S $2 59 W 22.76 0.75 2.2.77 S 44.01 W 0 28 S 7Z 34 W Z2.83 0.00 22.85 S 44.55 W 0 28 S 72 34 W 22.90 0.00 z2.gz S 44.77 W 8000.00 7999.71 7938.7! 8100.00 8099.71 8038.71 8ZO0.O0 8199.70 8138.70 8300.00 8299.69 8Z38.69 8400.00 8399.68 8338.68 8500.00 8499.67 8438.67 8600.00 8599.6T 8538.67 8700.00 8699.66 8638.66 8728.00 8727.66 8666.66 46.67 S 55 .35 W · 47.15 S 56 44 W 47.67 S 58 8 W 48.46 S 59 53 W 49.17 S 61 18 W 49.37 S 62 19 W 49.55 S 62_. 39 W 50.07 S 62 51 W } 50.Z9 S 62 53 W COMPUTATION DATE: 23-MAY-90 PAGE ARCO ALASKA, INC. WGI - 5 PRUOHOE BaY NORTH SLOPE, ALASKA DATE OF SURVEY: O7-MAR-[990 KELLY BUSHING ELEVATION: 6[°00 FT ENGINEER: D. WARNER INTERPOLATED VALUES FOR EVEN 1000 FEET-OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL OEVIATION AZIMUTH DEPTH DEPTH OEPTH DEG MIN DEG MIN VERTIC&L DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE' SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 -61.00 1000.00 999.99 938°99 2000.00 1999.98 1938.98 3000.00 2999.96 2938.96 4000,00 3999,93 3938,93 5000.00 ~999.84 4938.84 6000,00 5999,78 5938,78 7000.00 6999.74 6938°74 flOOO.O0 7999.71 7938.71 8728.00 8727.66 8666.66 0 0 N 0 0 E 0 11 S 13 57 020 S 10 7 W 029 S 3 BE 047 S 74 0 37 S 78 40 W 0 37 S 59 1 W 0 22 S 31 32 W 0 40 N 76 15 W 0 28 S 72 34 W 0.00 0.00 0.00 N 0.00 E 2.90 0.70 2.90 S 2.28 W 6.20 0.51 6.20 S 2.91 W 9.63 0.27 9.63 S 0.50 E 14..66 0.88 1¢.66 S 1.90 W 17,37 0.97 17, 38 S 14.82 W 20.22 1.18 20.23 S 25.23 W 25.02 0.68 25.03 S 32.16 W 26.37 0.33 26.38 S 38.50 W 22,90 0,00 22,92 S ~.4,77 W 0.00 N 0 0 E ' 3.69 S 38 9 W 6.85 S 25 9 W 9.64 S 3 0 E 14.78 S 7 24 W 22.84 S 40 28 W 32.34 S 51 16 W 40.76 S 52 6 W 46.67 S 55 35 W 50.29 S 62 53 W ARCO ALASKA~ INC. WGI- 5 PRUDHOE BAY NORTH SLOPE, ALASKA COMPUTATION DATE: 23-MAY-90 TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICal DEVIATION AZIMUTH DEPTH DEPTH OEPTH DEG MIN DEG MIN PAGE ~ 5 DATE OF SURVEY: 07-MAR-1990 KELLY BUSHING ELEVATION: 61.00 FT ENGINEER: D. gARNER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE, SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET OEG MIN 0.00 0.00 -61.00 0 0 N 0 0 E 0.00 0.00 0.00 N 0.00 E 61.00 61.00 0.00 0 12 N 5 43 F -0.04 1.95 0.04 N 0.03 E 161.00 161.00 100.00 0 11 S 68 222 ~ -0.12 0.03 0.12 N 0.20 W 261.00 261.00 ZO0.O0 0 13 S 8 59 W 0.19 0.36 0.19 S 0.44 W 361.00 361.00 300.00 0 15 S 64 24 W 0.34 0.55 0.34 S 0.61 W 461.00 461.00 400.00 0 12 S 30 19 W 0.83 0.66 0.83 S 0.83 W 561.00 561.00 500.00 0 25 S 19 6 W 1.14 0.40 1.14 S 1.18 W 661.01 661.00 600.00 0 1Z S 70 30 W 1.55 0.36 1.55 S 1.35 W 761.01 751.00 700.00 0 25 S 19 7 W 1.90 0.47 1.90 S 1.77 W 861.01 861.00 800.00 0 10 S 70 26 W 2.34 0.52 2.34 S 1.91 W 0 21 S 7 1Z W 2.71 0.31 2.71 S 2.26 W 0 16 S 80 13 W 2.97 0.43 2.97 S 2.42 W 0 21 S I 57 W 3.~+8 0.26 3.49 S 2.70 W 0 8 S 80 0 W 3.75 0.26 3.75 S 2.78 W 0 22 S 5 5?. W 4.04 0.42 4.05 S 3.11 W 0 6 S 3 47 W 4.52 0.36 4.52 S 3.02 W 0 21 S 23 23 W 4.75 0.76 4.75 S 3.29 W 0 15 S 47 44 E 5.31 0.58 5.31 S 3.16 W 0 12 S 68 19 W 5.36 0.46 5.37 S 3.16 W 0 19 S 51 11 E 5.78 0.12 5.78 S 3.11 W 0 12 S 2.2 48 W 6.02 0.47 6.02 S 2.85 W 0 26 S 34 17 E 6.58 0.60 6.58 S 2.81 W 0 6 S 26 23 E 6.93 0.40 6.93 S 2.34 W 0 19 S 34 30 E 7.20 0.89 7.20 S 2.39 W 0 17 N 67 35 E 7.25 0.37 7.25 S 1.86 W 0 16 S :71 55 5 7.42 0.22 7.42 S 1.70 W 0 20 N 83 8 E 7.58 0.10 7.58 S 1.19 W 0 19 S 14 10 E 7.81 0.03 7.81 S 0.91 W 0 26 S 68 39 E 8.29 0.31 8.29 S 0.37 W 0 2.9 S 25 21 E 8.78 0.76 8.78 S 0.12 W 0 21 S 31 t E 9.36 1.22 9.36 S 0.46 5 0 38 S 25 51 E 10.21 0.16 10.21 S 0.67 E 0 113 S I 37 5 10.97 0.47 10.97 S 1.12 E 0 24 S ¢6 31 5 11.63 0.53 11.63 S 1.25 E 0 5 S 32 5 W 11.88 O.Z1 11.88 S 1.43 E 0 11 S 55 22 E 12.15 0.89 12.14 S 1.54 E 0 23 S 10 45 W 12.31 0.53 12.31 S 1.37 E 0 24 S $0 16 W 12.76 0.14 12.76 S 1.15 E 0 26 S 44 34 W 13.43 1.75 13.43 S 0.66 E 0 43 S 56 11 W 13.99 0.44 13.99 S 0.16 W 961.01 961.00 900.00 1061.01 1061.00 1000.00 1161.01 1161.00 1100.00 1261.01 1261.00 1200.00 1361.01 1361.00 1300.00 1¢61.02 1461.00 1400.00 1561.02 1561.00 1500.00 1661.02 1661.00 1600.00 1761.02 1761.00 1700.00 1861.02 1861.00 1800.00 1961.02 1961.00 1900.00 2061.02 2061.00 2000.00 2161.02 2161.00 2100.00 2261.02 2261.00 2200.00 2361.02 2361.00 2300.00 2461.03 2461.00 2400.00 2561.03 2561.00 2500.00 2661.03 2661.00 2600.00 2761.03 2761.00 2700.00 2861.03 2861.00 2800.00 2961.04 2961.00 2900.00 3061.04 3061.00 3000.00 3161.04 3161.00 3100.00 3261.05 3261.00 3200.00 3361.05 3361.00 3300.00 3461.05 3461.00 3400.00 3561.05 3561.00 3500.00 3661.05 3661.00 3600.00 3761.05 3T61.00 3TO0.O0 3861.06 3861.00 3800.00 0.00 N 0 0 E ' 0.05 N 37 33 E 0.23 N 59 8 W 0.48 S 66 37 W 0.70 S 60 38 W 1.17 S 45 Z W 1.64 S 45 58 2.06 S 41 2 W 2.60 S 42 54 W 3.02 S 39 13 W 3.53 S 39 50 W 3.84 S 39 10 W 4.41 S 37 49 W 4.66 S 36 31 W 5.10 S 37 33 W 5.44 S 33 47 W 5.78 S 34. 44. W 6.18 S 30 43 W 6.22 S 30 28 W 6.56 S 28 16 W 6.66 S 25 22 W 7.16 S 23 9 W 7.32 S 18 4.0 W 7.58 S 18 20 W 7.49 S 14 2.3 W 7.61 S 12 55 W 7.67 S 8 56 W 7.86 S 6 37 W 8.30 S 2 35 W 8.78 S 0 48 W 9.37 S Z 48 E 10.23 S 3 44 E 11.03 S 5 50 E 11.69 S 6 8 E 11.96 S 6 51 E 12.24 S 7 14 E 12.39 S 6 20 E 12.81 S 5 8 E 13.45 S 2 48 E 13.99 S 0 39 W ARCD ALASKA~ INC. WGI - 5 PRUDHDE BAY NORTH SLOPE, ALASKA COMPUTATION DATE: 23-MAY-gO PAGE ~ 6 DATE OF SURVEY: O7-MAR-1990 KELLY BUSHING ELEVATION: 61.00 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0 50 S 72 25 W 0 56 S 84 55 W 0 55 S 87 41 W 0 45 N 84 29 W 0 39 N 86 48 W 0 40 N 89 27 W 0 45 S 74 17 W 0 50 S 67 37 W 0 41 S 72 21 W 0 46 S 63 47 W 3961.07 3961.00 3900.00 4061.08 4061.00 4000.00 4161.09 4161.00 4100.00 4261.10 ¢261.00 4200.00 4361.11 4361.00 4300.00 4461.11 4461.00 4400.00 4561.12 4561.00 4500.00 4661.13 4661.00 4600.00 4761.14 4761.00 4700.00 4861.15 ~861.00 4800.00 4961.16 4961.00 4900.00 5061.17 5061.00 5000.00 5161.18 5161.00 5100.00 5261.18 5261.00 5200.00 5361.19 5361.00 5300.00 5461.20 5461.00 5400.00 5561.20 5561.00 5500.00 5661.20 5661.00 5600.00 5761.21 5761.00 5700.00 5861.21 5861.00 5800.00 5961.22 5961.00 5900.00 6061.23 6061.00 6000.00 6161.24 6161.00 6100.00 6261.24 6261.00 6200.00 6361.25 6361.00 6300.00 6461.25 6461.00 6400.00 6561.25 6561.00 6500.00 6661.26 6661.00 6600.00 6761.26 6761.00 6700.00 6861.26 6861.00 6800.00 6961.26 6961.00 6900.00 7061.26 7061.00 7000.00 7161.27 7161.00 7100.00 7261.27 7261.00 7200.00 7361.27 7361.00 7300.00 7461.27 7461.00 7400.00 7561.27 7561.00 7500.00 7661.27 7661.00 7600.00 7761.27 7761.00 7700.00 7861.28 7861.00 7800.00 048 S 7242 W 0 50 S 68 9 W 054 S 68 51W 0 45 S 82 46 W 0 43 S 79 37 14 0 30 S 86 11 W 0 30 $ 66 51 W 0 28 N 82 20 W 0 39 S 58 1Z W 0 41 S 80 59 Wt 0 45 S 55 35 W 0 51 S 71 12 W 0 46 S 51 58 W 0 22 S 64 49 W 0 32 S 3446 W 0 38 S 63 30 W 015 S 54 6 W 0 30 5 31 31 W 028 566 9 W 0 14 S 57 0 W ENGINEER: O. WARNER 0 31 S 41 9 W 0 15 S 76 29 W 0 27 S 49 6 W 0 21 S 41 25 W 0 23 S 89 59 W 0 15 S 69 13 W 0 22 S 31 0 W 0 19 N 72 38 W 0 30 N 75 6 W 0 47 N 87 7 W VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE, SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 14.48 0.50 14.48 S 1.38 W 14.73 0.40 14.73 S 2.76 W 14.81 0.33 14.81 S 4.19 W 14.93 1.07 14.94 S 5.54 W 15.16 0.85 15.16 S 6.83 W 15.36 0.85 15.36 S 8.07 W 15.74 1.34 15.75 S 9.44 W 16.20 0.55 16.21 S 10.75 W 16.70 1.00 16.71 S 12.13 W 16.97 0.00 16.97 S 13.29 W 17.22 0.97 17.22 S 14.37 W 17.54 0.59 17.55 S 15.62 W 17.88 0.65 17.89 S 16.87 W 18.12 2.04 18.12 S 18.12 W 1B.ZB 1.19 18.28 S 19.20 W 18.60 0.68 18.61 S Z0.24 W 18.66 0.71 18.67 S 21.14 W 18.81 0.40 18.82 S 21.87 W 19.21 0.72 19.22 S 22.77 W 19.41 1.08 19.42 S 23.66 W 19.94 0.51 19.95 S 24.82 W 20.¢7 0.05 20.48 S 25.95 W 21.19 0.58 21.20 S 27.13 W 21.73 0.30 21.74 S 27.90 W 22.20 0.15 22.21 S 28.54 W 22.68 0.54 22.69 S 29.27 W 23.26 O.ZO 23.27 S 29.96 W 23.59 0.30 23.60 S 30.49 W 23.99 1.30 24.00 S 30.94 W 24.58 0.29 24.60 S 31.39 W 24.77 1.06 24.78 S 31.99 W 25.21 0.69 25.22 S 32.38 W 25.70 1.19 25.71 S 32.97 W 25.85 1.21 25.86 S 33.56 W 26.11 0.00 26.12 S 33.99 W 26.50 0.91 26.51 S 34.39 W 26.69 0.00 26.70 S 34.89 W 26.83 0.57 26.84 S 35.29 W 26.98 0.29 27.00 S 35.93 W 26.88 1.04 26.89 S 37.02 W 14.54 S 5 27 W ' 14.98 S 10 37 W 15.39 S 15 48 W 15.93 S 20 ZO W 16.63 S 24 16 W 17.35 S 27 43 W 18.36 S 30 56 W 'i) 19.45 S 33 33 W 20.64 S 35 59 W 21.56 S 38 4 W 22.43 S 39 50 W 23.49 S 41 40 W 24.59 S 43 19 W 25.63 S 45 0 W 26.51 S 46 24 W 27.50 S 47 24 W 28.20 S 48 33 W 28.85 S 49 17 W 29.80 S 49 50 W 30.61 S 50 37 W 31.84 S 51 12 W 33.06 S 51 43 W 34.43 S 51 59 W 35.37 S 52 4 W 36.17 S 52 7 W 37.03 S 52 13 W 37.93 S 52 10 W 38.56 S 52 15 W 39.15 S 52 12 W 39.88 S 51 55 W 40.47 S 52 15 W 41.04 S 52 5 W 41.81 S 52 3 W 42.37 S 52 23 W 42.87 S 52 27 W 43.42 S 52 23 W 43.94 S 52 34 W 44.34 S 52 44 W 44.95 S 53 5 W 65.76 S 54 0 W COMPUTATION DATE: 23-MAY-90 PAGE " 7 ARCO ALRSKA, INC. WGI - 5 PRUDHgE BAY NORTH SLOPE9 ALASKA DATE OF SURVEY: 07-MAR-1990 KELLY BUSHING ELEVATION: 61.00 FT ENGINEER: D. WARNER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG 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 7961.28 7961.00 7900.00 8061.29 8051.00 8000.00 8161.29 8161.00 8100.00 8261.31 8261.00 8200.00 8361.32 8361.00 8300.00 8461.33 8461.00 8400.00 8561.33 8561.00 8500.00 8661.34 8661.00 8600.00 872~.Q0 vB727.66 /8666.66 044 N 70 13 W 0 38 N 51 46 W 051 N $5 31W 0 53 N 62 24 W 0 42 N 64 51 W 0 31 N 43 46 W 0 19 N 69 4 W 0 28 S 72 34 W 0 28 S 72 3~ W 26.50 0.03 26.51 S 38.05 W 26.03 0.56 26.05 S 39.06 W 25.48 0.44 25.49 S 39.97 W 24.65 1.51 24.66 S 41.39 W 23.87 0.07 23.88 S 42.78 W 23.10 1.30 23.12 S ¢3.5~+ W 22.75 2.34 22.77 S 43.89 W 22.74 0.00 22.76 S ~4.26 W 22.90 0.00 22.92 S ~4.77 W 66.37 S 55 8 W q, 6.95 S 56 18 W 67.41 S 57 28 W 48.18 S 59 13 W 48.99 S 60 49 W 49.30 S 62 2 id 49.44 S 62 35 W 49.76 S 62 67 W ,, 50.29 S 62 53 W COMPUTATION DATE: 23-MAY-90 PAGE *? 8 ARCO ALASKA, INC. HGI - 5 PRUDHOE BAY NORTH SLOPE, ALASKA P~ARKER SAG SHUBLIK TOP SAD ZONE 4 ZONE 3 ZONE 2 ZONE 18 LAST GCT READING GOC PBTO BASE SAD TO DATE OF SURVEY: O7-MAR-1990 KELLY BUSHING ELEVATION: 61.00 FT ENGINEER: O. WARNER INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION : 1080' FNL E 1035' FEL, SECII T11N R14E,UM MEASURED DEPTH TVD BELOW KB FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 8172.00 8171.70 8110.70 25.41 S 40.10 W 8223.00 8222.70 8161.70 24.95 S 40.82 W 8272.00 8271.69 8210.69 24.58 S 41.53 W 8272.00 8271.69 8210.69 24.58 S 41.53 W 8350.00 8349.68 8288.68 23.94 S 42.64 W 8422.00 8421.68 8360.68 23.43 S 43.27 W 8598.00 8597.67 8536.67 22.77 S 4¢.01 W 8628.80 8628.46 8567.46 22.68 S 44.01 W 8633.00 8632.66 8571.66 22.69 S 44.04 W 8686.00 8685.66 8624.66 22.82 S 44.46 W 8690.00 8689.66 8628.66 22.82 S 44.47 W 8728.00 8727.66 8666.66 2Z.OZ S 44.77 W COMPUTATION DATE: 23-MAY-90 PAGE ~ 9 ARCO ALASKA, INC. WGI - 5 PRUOHOE BAY NORTH SLOPE, ALASKA NARKER SAG SHUBLIK TOP SAD ZONE 4 ZONE 3 ZONE 2 ZONE 18 LAST GCT READING GOC PBTD BASE SAD TD DATE OF SURVEY: 07-MAR-1990 KELLY BUSHING ELEVATION: 61.00 FT ENGINEER: D. WARNER ************ STRATIGRAPHIC SUMMARY SURFACE LOCATION = 1080' FNL E 1035' FEL, SEC11 T11N R14E,UM MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 8172.00 8171.70 8110.70 8223.00 8222.70 8161.70 8272.00 8271.69 8210.69 8272.00 8271.69 8210.69 8350.00 8349.68 8298.68 8422.00 8421.68 8360.68 8598.00 8597.67 8536.67 86Z8.80 8628.46 8567.46 8633.00 8632.56 8571.66 8686.00 8685.66 8624.66 25.41 S 40.10 W 24.95 S 40.82 W 24.58 S 41.53 W 24.58 S 41.53 W 23.94 S 42.64 W 23.43 S 43.27 W 22.77 S 44.01 W 22.68 S 44.01 W 22.69 S 44.04 W 22.82 S 44.44 W 8690.00 8689.66 8628.66 8728.00 8727.66 8666.66 22.82 S 44.47 W 22.92 S 44.77 W FINAL WELL LOCATION AT TO: TRUE SUB-SEA MEASURED VERTICAL VERTICAL OEPTH DEPTH DEPTH 8728.00 8727.66 8666.66 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 50.29 S 62 53 W SCHLUMBEROER O I RECT I ONAL SURVEY COMPANY WELL FIELD COUNTRY RUN DATE LODGED ARCO ALASKA, WOI - S PRUOHOE BAY USA ONE O? - MAR - 90 I NC. REFERENCE 72851 WELL' WGI-5. (1080' F'NL, 1035' FE~ SEC ll, TllN, R14E, UM) HORIZONTAL PROJECTION ~C~I.E = II 10 IN/FT lO -10 -4O -60 -40 -3O -ZO - 10 o 1o WELL' (1080' WGI - 5 FNL, *1035' FE, SEC ll, -B 0 6 10 TllN, R14E, UM) VERTICAL PROJECTION PROJECTION ON VERTICRL IA. RIdE SOUTH - NORTH ~ IN VERTICAL DEPTH6 HOR I Z SCALE = 1 / 6 I N,,"FT I' P~£ ~. , JC ()FILMED RECEIVED Alaska Oil & Gas Cons. Cornmissio[~ Anchora.q~. F'A;E NO, 2 ft ft d."g de.3 ~e~./lOOf t ¢lea ~[e.~ de;./lOOft CLOSURE 1130L_F~_']~ ~L$ DLSF, T ft ~g {le,~/lO~r t O,'J 0.. 0o00 0,00 0,00 0,~$ O,(X~ 0,00 0.00 0.00 0,00 53..',,0 535,~' 0,5¢:, 0,50 0,0'? ~i,O0 221,00 41,~ 1,5:-', 0,~: O,(r.'.-' 0,02 1~2,0 %48i,9~. 0,i0 0,40 0,02 -67,00 1~,~ -13+54 4,9.(, 110.90 O,OE, 19~.) I~76,96 0,!0 0,50 0,02 -2~,70 152,30 -4,~ 0,00 0.00 2476,0 2475,Y:,.,' 0,20 0,70 0,04 -f',60 142,70 -1,92 ;,01 25,07 0,04 0,00, 2976,~ 25'7.5,91 -0.30 0.~ -0,06 15.00 1~,70 3,00 -I,51 162.2':/ O,,'J7 O,O0 3447,0 3~6,90 0,10 0.5(.) 0.02 121.10 278,80 25,71 -0,10 1~,,82 0,17 0,02 379'J,:) 3792,89 -0,10 0.4C) -0,03 -53.5C 22~,30 -15.46 2.25, 129,05 0,12 0,01 4100,0 4,..q~',8~, 0,40 0,80 0,13 50,qO Z~,,70 16,42 3,87 74,35 0,20 0,03 4410.:) 44,0~,85 0.00 O,BO 0,00 -B,60 267,10 -2,77 9,46 94,14 0,04 0.05 4~';'3,0 ~,'P2.8! -0,20 0,60 -0,04 -12,~' 2F~,E)O -2,55 15,27 14S',~ 0,05 0,00 5129,3 5128,80 0,20. 0,80 0,~ -I,2C 253,60 -0,51 18,04 0,00 0,06 0.01 5444,0 5443,77. -0,30 0,50 -0,10 11,40 2E,5,t.~, 3,.42 21,52 162,8~ 0,10 0,01 5~9.:~ 5~8,76 0,10 0,60.. 0,03 -31,90 2~.1C: -I0.13 5.15 79,68 O,1C' ~72,0 6.071,7( 0,2¢: O,(tO 0,~. -0.60 _.%'2,50 -O,l!' 27,25 0.00 0,0/., 0,01 6293,:) 6292,73 -0,40 0.40 -0,18 3,70 ~,20 1.67 ~,12 t77.43 0,16 0,05 6~4,0 6353,72 0,2C 0,60 0,b33, -5,0C, 231,20 -8.20 25',54 2,5~/ 0,33 0,24 6703,:) 6902,71 -0.20 0,40 -0,06 -0,~ 23:).70 -0,14 31,91 0.00 0,06 O.O-C 696~,,0 69~.5.7C: 0,00 0,40 O,~C, 9,40 24C.,10 3,32 2(.21 ~,OC, 0,02 6,0! 72'79.3 7~8.6~ 0,~ 0,40 0,00 -8,20 231.90 -2,62 35,34 92,54 0,01 760.~',0 7606,6? -0,10 0,30 -O,O.q ~,70 26.",60 11,.":2 37,00 1S;..5.(, 0,07 O,C,? 7~/Z?,:) 7.92~,6~ 0,30. 0,60 0,09 40,~ ~,7,60 I2,~ ~,15 ~,79 0,I2' 0,02 8::'~';',08~6,-47 0,00 0,60 O,FX' -29,80 2~,89 -1E.,4F: 4':',6.6lC~1,(.7 0.19 0,~ ~-4.47,:, 8447,15 -0.0z C,56 -O,Ol 49,..o:/ 32/-.,89 1~.,'~<' 33,52 9..,..1 0,13 0.02 PAGE i~. ~I.I.I.~F, A2 IIE~TI~: I,AT(K.'-S)0,~ DEF'(E/-W) 0.00 NC,, EEA¢.IREC,Ih'I~WAL Vt~.TiCAL D~'~ DE¢3H ft ft 0.~ 0,0 0,00 987, ~ 451.0 986,98 1~2,~ 495,0 14~i,q8 ?~"~ STAT I OH AZI ~L,TH, LAT I TLPJ~,E 0,~ 0,~ 0,~ 0,00 -1,77 0,~: ~i.'~' -1,77 -3,~ 0,~ ~,00 -3,77 -6.0~ 0,40 1~.00 -6,06 -~,70 0.~ 1~2.~ -9,7¢ £/-W ft it 0,00 -1,5~ 2,34 -3,87 5.41 -4,% 7.83 -3,87 10,4~ AZI~JTH 0,00 22i,00 219,30 20~.73 lOOft C,,~.~, 0,0~ 0,04 37;3,~0 4!00.~, 4%',0 2475,73 500,0 2975,91 471,0 3446.~ 346,0 37~2,87 ~,7.0 -14,05 0.70 142,70 -14,05 -18.10 0.40 1~.7C -1~,I0 -1~,3(' 0,50 Z~8,80 -1~,33 -19,92 0,40 ~__~;,.30 -I9,92 -~,~. 0.80 Z~,70 -1,0! 14.09 184,10 0,~ !,51 18,16 175,24 0,07 · ~ ~"7 0,10 I¥,~ 1 1~,. -2,25 20.C6 1~,4~ 0,12 -5,15 21,10 194,12 0,20 4410, 517k.~O 5444 310,0 4409.85 4~3.0 4e,72,81 23~,0 5126,~ 315,0 ~3,77 315,0 b'Y56,76 -20,36 0.~ 267,10 -21,19 0,60 254,80 -21,1~ -2!,98 0.80 253.60 -21,98 -22,72 0,50 265.~q -22,72- -29,83 0,60 .233.10 -23.83 -9.46 ~,45 204,93 0,04 -15,27 26,12 215,77 0,05 -18.04 2~.44 21'~.3~, 0.0~ -21,52 3!,29 223.45 0,10 -24,21 ~.~7 225,45 6273.'YJ &..~4,~ 67{13, 313,0 6071,74 221,0 6292,73 61,0 6.~3.72 349,0 6702,71 '26,14 0,~ 232,50 -26,14 -27,5I 0,~ 2~.,20 -27,51 -27',83 0.6C 23!,20 -29,75 0,40 2~,70 -29.75 -30.87 0.40 240,10 -30,67 -27.~ 37,77 226,I9 0,0(, -29.I2 40.06 226.62 0,18 -~.54 ~',59 226,?1 0,.~ -31,9I 43,6~ ~7,0i 0,06 -3~,53 45.57 227,37 0,C,2 7~I,~ 7609,00 313,0 7298.69 310.0 318,0 792~,6e 162,0 3~,5 -32,08 0.40 231,90 -32,~ -32,77 0,30 267.60 -31,81 0.60 ~7.60 -31,~1 -3!,17 0,60 2,77,~0 -31,17 '35.34 47.7~ ,.~',76 0,0! '~ ~" 4f',44 226,,4~ 0,07 '~,!5 ~.~ ~:,9I 0.I3 '4C'.6~. 51,24 23'.',57 0,1~ -~q.a8 r~ ~ 2~.~ C..13 246,1 8(.73,2~ -4~, 3~;' 53, O0 23~,. 8': O, ~ PERMIT # ~'o - -~J'" WELL NAME COMPLETION ~'""'- ~' ! ~ i ~° ~ ' AoGcc GEOLOGICAL MA~'ERIALS INVENTORY LIST " ( check off or !ist data as it is received ) .... 4017 ! ~'?'~?¢0 drilling history ~ survey ! --'1 ~,.. tests! core des;iptiOn I cored i~terv~ls , ,,,core ,,aoa, I)~sis i, dry ditch' intervals digital data , .......... ~',~,, ,-C- , ,,,,,,, , ,! , , , ,, ,,,, ~, , , , , ,I "' LOGTYPE RUN ' iNTER~/~S ' SCAIF NO. ~.. ,~//~ ,~.,.~kA.~ /¢~ / ,~,~~- 22.~,' ~" ., ~-" " ~~2 ,, / " " , , 111 'v ' ' / , ,,, 1 41 ..... .... '"16) , , ..~7) ~q .. ARCO ALASKA, INC. F'.O. BOX 100360 ANCHORAGE, ALASKA 99510 .. DATE · 6/t 2/90 REFERFNCE' ARCO CASED HOLE FINALS t -9 6-6-90 COLLAR 2-3 6-6-90 COMP. NEUTRON G/R 2-t0 6-6-90 COMP. NEUTRON G/R 2- t S 6-9-90 COLLAR ~'~--23 6-8-90 COLLAR S-20 6-7-90 COMP. NEUTRON G/R S-C>'~.~. 6-7-90 COMP. NEUTRON G/R 4-t6 6-7-90 COMF'~ NEUTRON G/R 4-23 6-8-90 COMP. NEUTRON G/R 4-24 6-8-90 COMP. NEUTRON G/R 5-6 6-t(~-90 COMP~ NEUI'RON G/R 7-9 6-9-90 COMP NEUTRON G/R 7-9 6-9-98 DIFF. TEMPERATURE 7-34 6-9-90 COMP. NEUTRON G/R ~ 2-~ 8 6-4-90 CET ~ 2-~ 8 6-4-90 CBT ~ 6-~. 5-29-90 CBT ~ 6-~'~.~. 5-29-90 G/R J6-22 5-29-9~ CET WGI-5 6-3-90 PERF RECORD WE, I-6 5-S0-9~ F'ERF RECORD WGI-7 6-~ -90 F'ERF RECORD WGI-8 6-2-90 F'ERF RECORD RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN i, i, i, t, i, i, i, i, i, i, i, i, i, i i, i, t, i, i 5' 5' 5' 5' 5' 5' 5' 5' 5' 5' 5' 5' 5 ' 5' 5' 5' 2' 5' 5' 5' 5' 5' ATLAS ATLAS A'I'LAS Al'LAS A';'LAS Al'LAS ATLAS ATLAS ATLAS ATLA~~ ATLAS ATLAS ATLA$ ATLAS SCH SCH $CH $CH fCH $CH SCH $CH $CH -- Olf HAVE A NICE DAY~ , SALLY HOFFECKER ~ChO~8 ATO-i 529 OF APF,ROVED'~~ TRAN$~ 902t8 DATA DISTRIBUTION ~ CENTRAL FILES ~ ~ -' PHILLIPS ~ CHEVRON PB WELL FILES D & M R & D .I. ~ EXTENSION EXF'LORATION ~" BF'X ' EXXON ~ STATE OF ALASKA -r MARATHON TEXACO ~~ MOBIL ARCO ALASKA, IN(":~ I-",. 0 ~ BOX i '.')'-'":'S6':~' "'-"~' A N C: H 0 R A G E, A L A .S' K A 9 ::. _ , .,.? DATE' 5/S0/90 REFERENCE:. ARCO CASED HOLE FINALS t -7 5-23-90 COLLAR t -9 5-2S-90 PFC 5-4 5-'27-9(:) COLLAR 6--i2 5 -- 2 ,5 -- 9 (.")F'DK-i~-~.3 G/L CCI_ 9-t 5-2 i -'?'C) F'E R.F' R. ECORD 9-3 5-2t -9':') PERI:' RECORD i :1 -5 5-'27-9(:.~ F'DK-t ¢'~) G/R CCL i i-t3 5-2'7'-9~.) PDK'-i~.9':) G/R CCI_ t i -i 6 5:-28-9'3' COMP. NEUTRON G/R i4-7 5-26-9() COMP. NEUTRON G/R t 5-4 _,~-='- ~ 4-- ~?(')~. . SONAN. i 5-4 5-'24-9~.) DIFFERENTIAL TEMF'. WG]:-5 _:..= ~-' - '"' ,':, -' ~.;' ¢;' .... COLLAF.';' WG I-'7 5-22-9':) COLLAR W G I - 8 ~'" "~ '~ - ..,- ~-, 9'3 COLLAR PLEASE RECEIVED BY HAVE A NICE SALLY FtOFFECKER AT0-i529 N AND R DAY! jUN - 4 1990 Al~sl~ Ol~ & Gas Go~s. ETURN THE ATTACHED. COF'Y AS RECEIF'T OF AF'F'ROVED~~_ TRAN$~ 9r~t98 RUN t, ~'"-,' RUN t , 5" RUN t, 5" RUN t., 5<" RLJN i , _."'.." RUN i, RUN f,_.'"'" RUN t, 5" RI.~N.i, _.-. ":'" RUN i , 5" PUN t, t" RUN RUN t, 5" RLIN DATA DISTRIBUTION CENTRAL FILES -.-' F'HILLIP$ CHEVRON F'B WELL FILES D & M R.& D EXTENSION EXPLORATION "'~- BF'X EXXON ~ STATE OF ALA,S'I<A MARATHON TEXACO MOBIL A'I'I_AS A T I_ A S A'T'LA,? A TI_A '£ S L: H A'i LAS A 'i" L. A,>;' A1 I_A£ A'! LAS ATLAS A'rLA:: A '1'1._ A Ai"L. AS April 18, 1990 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: WG1-5,6,7, &8As-builts Dear Mr. Chatterton: Enclosed are copies of the subject As-builts for your information. If you have any questions, please call me at 263-4618. Sincerely, Engineering Aide DW cc: File W1-1 RECEIVED & Gas Cons. Commission Anchorage ARCO Alaska Inc. is a subsidiary of Atlantic Richfield Company AR3B-6001-A 2 THIS SURVEY RECEIVF ,, VICINITY MAP NOT TO SCALE ,o.S- ( PRUDHOE BAY LEGEND L OCA TED WITHIN PRO TRA/~[..~ & Gas Cons. SECTION II, T. I! N., R. 14 UMIA T MERIDIAN, ALASKA Anchorage e CONDUCTORS AS-BUlL T THIS SURVEY 7 15,971,418.97 685,125.51 .~[ 5,971,302. 't4 685,153.47 PLANT COORDS. 249.97 370. ~ N 489.74 w 369.94 369.90 569.81 · EXISTING CONDUCTOR NO TES I.) BASIS OF 'LOCA TK~ PER NGi MONUMENTS NI-C & NI-D. 2.) ALASKA STATE PLANE COORDINATE$ ARE ZONE 4, k., 0.9999..'390. L OCA TiON IN SECTION BASIS OF ELEVATION I~ ARCO DATUM ~t~.L.L.IFJ. REF. FIELD BOOK, 90-06 p. ~-42 IS,S1jED FOR IVF~ TION 1109' FEZ. tO~O° F.R. BELL & ASSOCIATES t ARCO Alaska, Inc. I~)RTH SLOI~ D4TI~ICT - WGI PAD~ WELLS 5~6~7 & ~ ~.o.~. os ~ I~' ~s Al' ~ OIL AND GAS CONSERVATION COMr~ lION APPLICATION FOR SUNDRY APPROVALS Operation Shutdown ~ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other_ 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ 2. Name of Operator 9951O 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 6. Datum elevation (DF or KB) feet RKB 50' 7. Unit or Property name Prudhoe Bay Unit 8. Well number WGI-5 9. Permit number 9O-25 4. Location of well at surface 1080' FNL, 1035' FEL, Sec. 11, T11N, R14E, UM At top of productive interval 1080' FNL, 1035' FEL, Sec. 11, T11N, R14E, UM At effective depth 1080' FNL, 103S' FEL, Sec. 11, T11N, R14E, UM At total depth 1080' FNL, 1035' FEL, Sec. 11, T11N, R14E, UM 10. APl number 50-029-2201 5 11. Field/Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured true vertical 8728' feet Plugs (measured) None 8728' feet Effective depth: measured true vertical 8686' feet Junk (measured) None 8 686' feet Casing Length Conductor 8 0' Surface 3457' Intermediate Production 81 28' Liner 879' Perforation depth: measured Size Cemented 20" 2150# Poleset 13-3/8" 2200 sx AS III & 650 sx Class G 9-5/8" 450 sx Class G 7" 325 sx Class G None Measured depth True vertical depth 110' 110' 3494' 3494' 8164' 7849'-8728' 8164' 7849'-8728' 13. true vertical None Tubing (size, grade, and measured depth None Packers and SSSV (type and measured depth) None Detailed operation program BOP sketch Attachments Well History Description summary of proposal Date approved 15. Status of well classification as' Oil X Gas Service Suspended 14. Estimated date for com~ operation 16. If proposal was verbally approved Name of approver 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Drilling] Analyst FOR COMMISSION USE ONLY Signed Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test_ Subsequent form require Commissioner IAppr~val No, vo-/73 Date SUBMIT IN TRIPLICATE Approved by the order of the Commission Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY LONNIE C. SMITH ARCO O. and Gas Company Well History - Initial Report - Daily Inetructione: Prepare and submit the "Initial Rel~3rt" on the first Wednesday after a well is spudded or wori<over operations are started. Daily work prior to s0udding should be summarized on the form giving inclusive dates only. District ~CO .,~LASK~ INC. PRUDHOE BAY lC .... y. pa r ~OO~[o U~%o pE Lease or U~)L: 28302 Title DRILL IState AK WGI-5 Well no. Auth, or W.O, n~ks2017 Operator zl~:~C0 Spudded or W.%l~g~n Date and depth as of 8:00 a.m. 02/17/90 ( TD: 1153'( 1 SUPV:MWW/DBJ 02/18/90 ( TD: 3075'( SUPV:MWW/DBJ 02/19/90 ( TD: 3515'( SUPV:MWW/DBJ 02/20/90 ( TD: 3515'( SUPV:MWW/DBJ 02/21/90 ( TD: 4848' ( 1 SUPV:MWW/DBJ 02/22/90 TD: 6355'( SUPV:HMP 02/23/90 ( TD: 6923'( SUPV:HMP 02/24/90 ( TD: 8178'( 1 SUPV:HMP API: 50-029-22015 ARCO W.I 21.0000 Complet ..... r66%kO~h gay reported :) L53) DRILLING 17-1/2" HOLE MW: 9.2 VIS:300 ACCEPTED RIG @ 0500 HRS, 02/16/90. NU DIVERTER, MIX SPUD MUD. SPUD WELL ~T 1330 HRS, ~B-90:'*''~'~ DRLD TO 565'. TFNB NO. 2. DRLD TO 1153'. DAILY:S302,446 CUM:$302,446 ETD:S300,000 EFC:$2,601,946 ) DRILLING MW: 9.5 VIS:250 22) DRLD TO 3075'. l) 140) ~) o) ;) ;33) ) 07) ) 68) 55) DAILY:S62,504 CUM:$467,096 ETD:S350,000 EFC:$2,614,450 PREPARE TO CEMENT CSG 13-3/8"@ 3494' MW: 9.5 VIS:210 DRLD TO 3088', TFNB NO. 3. DRLD TO 3515', CIRC, ST, CBU, POOH TO RUN CSG. RAN 89 JTS. OF 13-3/8" 68~ L-80 BTC CSG. RUN DOWELL, CIRC, PREP TO CMT CSG. DAILY:S163,411 CUM:$528,361 ETD:S500,000 EFC:$2,627,861 PREP TO PO BHA #3. 13-3/8"@ 3494' MW: 9.6 VIS: 57 CIRC AND RECIP 13 3/8" CSG, CMT W/ 2200 SX ASIII LEAD AND 650 SX OF 'G', CMT TO SURFACE, NO TOP JOB REQUIRED, FULL RETURNS, RD DOWELL, ND DIVERTER, CUT CSG, WELD WELLHEAD, NU AND TEST BOPE, PREP TO PU BHA #3. DAILY:S185,216 CUM:$713,577 ETD:S700,000 EFC:$2,813,577 DRLG 12-1/4" HOLE AT 4848'.13-3/8"@ 3494' MW: 9.4 VIS: 38 LD 17-1/2" STAB, MU BHA93 AND BIT#4, RIH, TEST MWD, TEST 13-3/8" CSG TO 3000 PSI, DRLG FC AND FS AND 10' OF NEW 12-1/4" HOLE, PERFORM LOT=14.3 PPG EMW, DRLG 12-1/4" HOLE FROM 3525' TO 4848'. DAILY:S64,418 CUM:$777,995 ETD:S920,000 EFC:$2,657,995 CBU PREP TO POOH FOR BIT.13-3/8"@ 3494' MW: 9.5 VIS:~39 ,~. ~ DRILL 12-1/4" HOLE F/ 4848' TO 5005', CBO, SHORT TRIP~'.%~D~ ~ T"' F/ 5005' TO 6355' CBU, PREP TO TRIP FOR BIT. ~' DAILY:S61,048 CUM:$839,043 ETD:S920,000 EFC:$2,719,043 DRILLING AT 6923'. 13-3/8"@ 3494' MW: 9.8 ViS: 48i/~;'~; POOH CHANGE BHA AND PUT ON PDC BIT, RECOVER SURVEY,.mRI~, ~ .. DRXLL 6355-6448, DYNA-DRILL LOCKED UP, POOH, XO"MOTOR,:~:~IH%i~!~}~:'~--'~' CUT DRLG LINE, DRILL 6448-6923. /~;'~R~qj~.i.:~_~ DAILY:S55,038 CUM:$894,081~ ETD:S920,000 EFC:$2,774,081 ~" CIRC & COND HOL~ ~; CSG 13-3/8"@ 3494 'MW: 9.9 VIS: 40 DRLD F/ 6923' TO 8178'. PREP HOLE F/ C$G. CIRC A~ND COND & SHORT TRIP. DAILY:S57,168 CUM:$951,249 ETD:S920,000 EFC:$2,831,249 The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B-459-1-D JNumber all daily well history forms consecutively as they are prepared for each well. Page no. ARCO oi, _.,d 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 County or Parish IState ARCO ALASKA INC. NORTH SLOPE Field Lease or Unit PRUDHOE · BAY WGI-5 Complete record for each day while drilling or workover in progress DOYON 9 Date and deptl~ as of 8;00 a.m. 02/25/90 ( TD: 8178' ( SUPV: HMP 02/26/90 ( TD: 8265' ( SUPV: HMP 02/27/90 ( TD: 8728' ( SUPV: HMP 02/28/90 ( TD: 8728' ( SUPV: HMP 03/01/90 ( TD: 8728'( SUPV:MWW AK 13) 0) [) 87) 63) ) o) ) o) LD AND MU BHA 9-5/8"@8164' MW:10.0 VIS: 46 SHORT TRIP. POOH. CHNG AND TEST RAMS. RU AND RUN 203 JTS OF 9-5/8", L-80, BTC, MOD CSG W/ FS AT 8164' AND FC AT 8077' CMTD W/ 450 SXS OF CL "G" CMT AT 15.8 PPG. CIP AT 01:45 HRS, 02/25/90. PUMP PLUG W/ 3000 PSI. LD 12-1/4" BHA. DAILY:S261,740 CUM:$1,212,989 ETD:S920,000 EFC:$3,092,989 DRLG 9-5/8"@8164 MW: 9.2 VIS: 45 FIN LD 12-1/4" BHA. PU AND MU 8-1/2" BHA. ND BOPE. CHNG RAMS AND TEST SAME. NU BOPE. TEST CSG, SPOOLS AND BOPE. OK. RIH AND DRLD FC, CMT AND FS AND CLEAN OUT TO 8178'. CIRC AND COND MUD. PERFORM LOT TO 12.8 PPG. DRLD F/ 8178' TO 8188'. C & C MUD. PERFORMED FIT TO 11.4 EMW. DRLD F/ 8188' TO 8265' DAILY:S58,821 CUM:$1,271,810 ETD:S920,000 EFC:$3,151,810 FINISHING OH LOGS. 9-5/8"@8164 MW: 9.2 ViS: 40 DRILL 8-1/2" HOLE FROM 8265 TO 8728', CIRC, DROP SURVEY, POOH, RU WESTERN ATLAS LOGGING GR/ACOUSTIC/ZDL/CNL/CAL FROM 8164' TO 8729'. DAILY:S52,858 CUM:$1,324,668 ETD:S1,330,000 EFC:$2,794,668 LD HWDP. 7"@ 8728' MW: 9.2 VIS: 39 FINISH OH LOGS, RD WESTERN ATLAS, RIH, CIRC AND COND MUD, POH, RUN 7"LINER, CIRC AND COND MUD, CMT LNR W/325 SX CLASS G POOH, LD RUNNING TOOLS, RIH W/ HWDP, POOH LD HWDP. DAILY:S192,313 CUM:$1,516,981 ETD:S1,517,000 EFC:$2,799,981 DRLG CMT AT 8677 7"@ 8728' MW: 9.4 VIS: 50 LD HWDP, CUT DRLG LINE, PU, BHA ~6 W/ 8-1/2" BIT, RIH, TAG FIRM CMT AT 7709', DRLG TO TOL AT 7849', CBU, POOH, LD BHA96, TEST LINER TO 4000 PSI, MU BHA#7 W/ 6" BIT, RIH, DRLG HARD CMT FROM 7849' TO LC 8646', TEST LINER TO 4000 PSI, DRLG CMT TO 8677 AT REPORT TIME. DAILY:$48,167 CUM:$1,565,148 ETD:S1,517,000 EFC:$2,848,148 Well no. . The above is correct -, Signat e ~ For form pYepar~ion'~nd ~istribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 AR3B-459-2-B Number all daily well history Iorms consecutively as hey are prepared for each well. Page no ARCO ,..,~ 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 cofflpletlon and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting cost center code District ARCO ALASKA INC. ' ~State AK / Field PRUDHOE BAY auth. or W.O. noAs2017 Operator ARCO Spudded or W.Os~e~n Date and depth as of 8:00 a.m. Old TD 03/02/90 ( 1 TD: 8686'( SUPV:MWW C°unty°rP~TH SLOPE Lease or Un~DL: 28302 WGI-5 well no. Title DRILL API: 50-029-22015 A.R.Co. W.121.0000 Date 02/16/90 Complet ...... ~)6o~.(~c h ~ ay reported Iotal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well our 13: 30 Prior status If a W,O. RELEASE RIG, MOVE TO WGI-6. 7"@ 8728' MW: 9.3 VIS: 0 DRLG HARD CMT FROM 8677 TO 8686, CBU, DISPLACE MUD TO BRINE, POOH, LDDP, FREEZE PROTECT TOP 560' OF HOLE W/ DIESEL, SET TBG HGR i~ND BPV, ND BOPE, NU TREE, RELEASE RIG AT 0400 HRS ON 02-MAR-90. DAILY:S69,700 CUM:$1,634,848 ETD:S1,700,000 EFC:$2,734,848 New TD Released rig Date Classifications (oil, gas, etc.) PB Depth K nd of rg Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production ,Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P, Water % GOR Gravity Allowable Etfective date corrected Signa '~J~ For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively as they are prepared for each well. jPage no. DIvlNon of AtlanflcRIchtleldCompany l~Casi~ Set ~; ,.~q : __~t. ~.~~ S, YS~,_ ..:-:_ .'. ~11 ~ge ~e~e__ ~ .... ., ._psig ~ ~cr. ¢]~s. pres. 200 9sig ..... . ...... ~.~ ~{ I.,>:,='!~*I,,~,/,~,,'.- -,*' -'x-:'_ Choke line Va.lv~ l~,C.l~, valve .... . ........ ..-:. ~e~ ~1. ......... _ ........, It I ~~. - ~ ....... _ ', Failures-: .... , ..... ARC:O AL. A3,'KA, INC, ' F',O, BOX ~003;60 ANCHORAC~E:', AL. A8'KA 995~0 R I.=.] F i.=.] R'E!i N C E · A R C 0 D t R E C T I 0 N A L D A T A W G I -5 2- 2 5 "' 9 0 M W D D I R E C T I 0 N A L ,.9 U R V E Y ANA F:'I...EA,.?E SI(:;N AND RE1UF.N THE ATTACHED COPY A~' F~:ECEIPT OF' DATA I"IAVE A NICE: DAY! ~. ~VtAR ¢ 7 !990 ALLY HOFF:'E:CKER .,,,, A T o-. i .~ 2 e A~ask~ Oi~ & G~s Cons. C, APPROVED ~ TRAN$:~. 90~:!~ .... DI~'TRIBUTION ,ENTRAL FILES CHEVRON D & M EiXTE:NS' I ON EXF'LORATION EXXON MARATHON MOB ii: L F' H I L. L I F:' P B W E L.. L. F I L. E,S'( 2 C 0 P I E .%~ ) R & D B F'X ,~I"ATE OF AI..A~gKA TEXACO ARCll) AL.A~;KA, INC~ P,O, BOX t0,3S6.0 ANCHORA£;E, ALA~'K A 995t'0 DAT.E: S--t 5-9G RE:.F'E. RE:.NCE:.' ARCO CA,S'ED I"IC)LE FINAL.~' 'i '"'S S .... I 0-90 COL. I...AF;:/PERF RUN t .... 7 S-9-9() CCJL. I_AI"~/F'EF;:F RUN t '"'24 3-4 .... ~.0 COL. L. AR RLN" I' t""34 t t '-t 7-8? PITS RI. JN · ~'"'28 t 0-t S""89 .EF:'I LC)G RI.IN .5-9 S-S-9.0 bOLLAR I:;:UN I t-S 3-5-9.0 COL. L. AR/P .F.'.'RF:' RUN ~ 4-49 2-27-90 F:'F:ODUCT I ON RUN t "];-t t 2-..3t -89 GAMMA ]DSN RLIN t5.-1 GA 3-t .... 90 DUAl_ BUR,S'T TDT-P RUN t 7-..3 3-9-90 COLLAF;: RUN WG I -IS 3--6-- 9 G CBT [RUN WC;I--5 3-6-90 CET RUN PI. EASE SIGN AND RETURN THE A'rTACHED COF'Y AS RECEIF'T OF DATA A T L. A ,S' A"I"I_ A ~' A T I... A,?;,' C A M C 0 ATL. A,.? A'l' I.. A,.~; ATL. A,S' ,S'CH HL,S' $CH ATLAS $CH ,S'C;H DISTRIBUTION · ,,.'"' CI:~NTRAL FILES ,,"' F'HII_LIF',.~' ... CFIEVRC)N PB WELL FILE,S' D & M R & D' ~. EXTENSION EXPLORATION .,.'"' BF'X · ,- EXXON .~ STATE OF ALASKA MARAI'HON .,.'"' TEXACO ~~ MOBIL ARCO ALASKA, INC, P,O, BOX t(~)36~) ANCHORAGE, ALASKA DATE · 3-9-98 REF:ERENCE: ARCO OPEN HOLE FINAL. S 5-26 t t-25-89 5-27 ~ ~)/ t 4-30/89 5-27 t 0/~ 4-38/89 WGI-5 2-26-98 SHDT FROM F'MS GR/RESISTIVITY GR/RESISI'IVII'Y GR/RE$ISTIVITY RLJN t, 5' 2 ' TVD 2' 2' F:'L. EAXE[ SIGN AND RETLJRN I'HE ATI'ACHED COF'Y AS RECEIF'T OF: DATA. RECEIVED BY HAVE: A NICE DAY! SALLY HOFFECKER AT(]'-' t 529 5° C H ANA ANA ANA DISTRIBUTION '"* CEN'FRAL FILES '"' '.' ',r F'H ILl_ IF'X .11o · ,,' CFIE:VRC)N F:'B WELL. FILES ',,' D & M '"' . R & D · ' EXTENSION EXPL. OF~ATION ~ BF:'X · ' EXXON ~ STATE OF" ALASI(A , MARAI'HON ~ I'EXACO ~ MOBIL. ARCO ALAS:KA., iNC,. : :. .... · &., ,..: .... · A N E H 0 i~;.: A 5 E., A L A ~!,~ K A 9 9 5 i (') R iii: !::' iii: F;,' iii: N C E ' A R C O H A 6. N E T I C 'T'A P iii; ( 3' ) W i 'T' i-'i L.. ]: S 'T' I N E.;- ( S ) D t :~';.' T R :I; :ri': U T ]; 0 N C':EN'rF;.:AL t::' :I: I...E~; ( C:H ) CHIEVRON D & M ]"ANNA,!.;' E.'.i:;..'ODN ( OH ) EXXON NARATHON HOB :[ i... WC;i .... i:.!::2 .... 26 .... 9:3: WG- i .... ".!:,"2 .... 2 7 .... 9 W [.'.; ]; --' 5: 2 .... '7 '7 .... '::;' ,';', W (;. ;il .... ~.i!::2 .... 2 '7 - 9 (') B i.-t C ;:':', .... G A N M A t"' '. ..... Z-.'C, EN,S;/CNL.-.--C.A~ii'~A (F;..'AW) Z .... D E N ;!;; /C N L "- [;. A M M A ( P 0 F;.: 0 ;' RUN i , 2"&"}:" R U N I ,..9" &..;.'::'" J:;..' E C E i V E D B Y .... ~/.'... Z S ............................................. HAVE: A NiCE DAY, j~C~,,~~D__ ,,'7 : ¥~P,~ ,~ ....... .,..,. ,.., ,, '.; .... A'¥' 0 .... '; ::.:...: ?. 9~iaska Oil & Gas Boas, {;;gm~xsa Z~ ~ ~,..,.~.,;:.-,,..;, ,., :;, .:. ,::. ::J: C iii; N'!" F;.: A L F' i L. iii] :$. ,....... :...;'" i"J i::' \/j:;.., 0 N :J~: g & H .it. · .- E X 'i" E:,..:";ii; i 0 .... i"..~ ~::',... ,.,v j::.-L.. 0 R A T I[] N · .-~" E X X 0 N. 4h · .. i'"'j A F:..' A 'i" H ill) N · ". .;',4 ~"'~ C.! T i · 11' ~ , ...- ;....~. · ,.'"' .I::' H Ii,._ L I J::', F:' B W iii; L. L F ]; L. Ii!;,? "" R & i} ,ii. · .. B F:' X · ,,-;ii/'T'A '} E i"'t F:' .", i ..... :." .,' .',, .~ ! ~... r'I ,.:. J': I", · ,,. "r j::' ::...;' A ": f'i · t1' ~ ............ A T J... A S A'i' LAS AT'L.A A 7' J... A J.';: February ~g, 1990 J D Gillespie Regional Drilling Engr ARCO Alaska, Inc P O Box 100360 Anchorage, AK 99510-0360 Telecopy No. (907) 276-7542 P~dhoe Bay Unit WGI-5 ARCO Alaska,~ Inc Permit # 90- 25 Surf Loc 1080'FNL, 1034'FEL, Sec il, TllN, R]4E, UM Btmhole Loc 1080'FNL, 1034'FEL, Sec 11, TllN, R14E, UM Dear Mr Gillespie: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. 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 drill~d. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so ~hat the Commission may witness testing before drilling below the shoe of the conductor pipe. V~ trulyz~you~r~, ~ C V Chatterton ~ Chai~an Alaska Oil and Gas Conservation Co~ission BY ORDER OF THE COmmISSION ~O Enclosure ~c: Department of Fish & Game, Habitat ~ion- w/o encl D~partment of Environmental ConservationTM-.~ w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 - la. Type of work Drill ~' Redrill lb. Type of well. Exploratory -' Stratigraphic Test ~ Development Oil '" Re-Entry - Deepen Service ~' Developement Gas - Single Zone ~' Multip!eZone :-~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P.0. Box '100360, Anchor`age, AK 99510-0360 4. Location of well at surface 'I080'FNL, 1034'FEL, Sec.'il, TI'IN, R14E, UM At top of productive interval 1080'FNL, 1034'FEL, Sec.11, TI'IN, R14E, UM At total depth 1080'FNL, 1034'FEL, Sec.ll, TllN, R14E, UM 12. Distance to nearest ! 13. Distance to nearest well property line 4200' feet .cjreater' than 200' feet 16. To be completed for deviated welts Kickoff deptl~or~ ~egh'~eet Maximum hole angle 0 18. Casing program size Spec i ficat ions Hole Casing Coupling 30" 20" We] d 5. Datum Elevation (DF or KB) Pad 18' RKB 50 feet 6. Property Designation ADL 28302 ALK 2313 BHL 7. Unit or property Name Prudhoe Bay Unit 8. Well number wc i-,5 9. Approximate spud date 02/10/90 14. Number of acres in property 10. Field and Pool Prudhoe Bay Fie~.d P"udhoe Bay 0ii Poo~. 11. Type Bondts~o 2o AAC 2.50251 Statewide Number No. U-630610 Amount $200,000 15. Proposed depth~MD and TVU, 8740'MD 2560 8740'TVD 17. Anticipated pressure (see 20 AAC 25.035 feet Maximum surface 2812 psig At total depth (TVD) 8444 ' ps,,; Setting Depth Top Bottom Quantity of cement MD TVD (include stage data) 39 ' I '1 9 ' 2000# Pol eset , S II I & 60~ sx" C[G 8 - 1 / 2" 7" 55 BTC BTC 37' 3500' 2000 C 8180' '1000 sx G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth' measured feet Junk (measured) true vertical feet Casing . Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True Vertical depth 20. Attachments Filing fee [] Property plat ~ BOP Sketch ~ Diverter Sketch ~, Drilling program ~ Drilling fluid program [] TFme vs depth plot ~ Refraction analysis ~ Seabed report ~ 20 AAC 25.050 requirements ~,. 21. I hereby certify that the foregoing is true and correct to the beSt of my knowledge Signed /~/~ ~7 ~//~¢~f.~ Title Regional DriP, ting Engineer u Commission Use Only ("3PS) PD3/104 Permit Number ! APl number I Approval date I See cover letter .<:~O -,Z~' 50-o.~. ~'- .z. ~o/.5" 02/06/90 for other requirements Conditions of approval Samples required FR,, Yes ~No Mud log required ~ Yes ~8' No Hydrogen sulfide measures ~ Yes ~ No Directional survey required ,.' Yes ~. No Required working~ure f/o~ BOP/E/'/~x21~ ~ 3M; ,~ 5M; [] 10M; [] 15M Other: by order of Approved by [,. "__ ~, L~/~~ Commissioner the commission ---- ' t I / ' .q~lhmit i~ trinJir'nfn PRUDHOE BAY DS WGI-5 PRELIMINARY DRILLING PROCEDURE 1. MIRU drilling rig. NU diverter and function test same. 2. Drill 17-1/2" vertical hole to 3500' TVD/MD. 3. Set 13-3/8" casing and cement same. Nipple up BOPE and test to 5000 psi. Test casing to 2500 psi for 30 minutes. 4. Pick up 12-1/4" BHA and RIH. Drill 10 ft of new hole and perform leakoff test. 5. Drill 12-1/4" vertical hole to 8180' TVD / MD. 6. Ddll to the 9-5/8" casing point at 8180' TVD / MD. 7. Set 9-5/8" casing and cement same. 8. Pick up 8-1/2" BHA and RIH. Test casing to 4000 psi. 9. Drill 10 ft of new hole and perform EMW test. 10. Drill 8-1/2" hole to 8740' TVD / MD vertical hole. 11. Set 7" liner and cement same. 12. Clean out the 7" liner and 9 5/8" casing and test liner / casing to 4000 psi for 30 minutes. Circulate well to brine and freeze protect with diesel. 13. Release drilling rig. Run cased hole logs 7 days after rig release. 14. MI and RU completion rig. Run 7" tubing and packer assembly. NU 7" tree and test to 5000 psi. Test tubing and casing to 4000 psi. Release completion rig. 15. Rig up wireline unit and perforate. NOTE; PRUDHOE BAY DS WGI-5 PRELIMINARY DRILLING PROCEDURE CONT. a. Excess non-hazardous fluids developed from the well operations and as necessary to control the reserve pit fluid level will be pumped down the 9-5/8" x 13-3/8" annulus. The annulus will be left with a non-freezing fluid during any extended period. The annulus will be sealed with 300 sx of cement followed by Arctic Pack. b. There are no wells within 200 ft. of the proposed well. c. The drilling fluid program and surface system will conform to the regulations set forth in 20AAC25.033. d. Maximum surface pressure is based on BHP and a full column of gas to TD (0.10 psi/fi). e. Based on previous logs, no potential productive zones are anticipated above 3500' TVD. f. No potential hazardous levels of H2S are anticipated in this well. SOLIDS CONRROL EQUIPMENT Shale shaker Mud cleaner Centrifuge Trip tank Degasser Pit level indicators (visual and audio) Fluid flow sensor Fluid Agitators PBU DS WGI-5 MUD PROGRAM DEPTH DENSITY VIS YP INT 10MIN FL OIL SOLIDS (TVD) (PPG) GELS GELS CC/30MIN (%) (%) MUD TYPE SPUD 8.8 300 70 30+ 50+ 25 0 2 to to to to to 13-3/8 9.2 100 40 6 csg pt. SET 13-3/8" CASING GEL-BENEX SPUD MUD DEPTH DENSITY PV YP INT 10 min FL OIL SOLIDS MUD (TVD) (PPG) (CP) (#/ft GEL GEL cc/30min (%) (%) TYPE 13.3/8" 9 10 6 2 4 25 0 2 LIGHTLY to to to to to to to to to TREATED K-10 9.7 15 10 4 10 10 6 POLYMER K-10 9.8 10 6 2 4 10 2 4 LIGHTLY to to to to to to to to to TREATED 9-5/8" 10 15 10 4 10 6 5 9 POLYMER SET 9-5/8" CASING DEPTH DENSITY PV YP INT 10 min FL OIL SOLIDS MUD (TVD) (PG) (CP) (#/ft) GEL GEL cc/30min (%) (%) TYPE . 9-5/8" 8.7 10 6 2 8 8 2 4 LIGHTLY to to to to to to to to to TREATED 7" Liner 9.1 15 10 4 10 6 5 6 POLYMER SET 7" LINER THIS MUD PROGRAM IS ONLY A GUIDELINE. ACTUAL HOLE CONDITIONS WILL DICTATE THE ACTUAL MUD PROPERTIES. ANY MAJOR CHANGES SHOULD BE DISCUSSED WITH THE ARCO ANCHORAGE OFFICE. SURFACE HOLE DIVERTER SYSTEM SCHEMATIC ARCO ALASKA, INC. FILL-UP LINE I RISER I FLOWLINE ! ! 20" 2000 PSI DIVERTER 10" BALL VALVE I CONDUCTOR 10" BALL VALVE 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 WELL ! r- , RIG MODULES I NOTE' 100' FROM ANY IGNITION SOURCE ALL TURNS 90 DEGREE TARGET TEES RESERVE PIT JG 7/27/87 13-$/8" 000 PSI BOP S,TACK DIAGRAM ACCUMULATOR CAPACITY TEST !, i IANNULAR 1 PRFYFNTER 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. ASSURE THAT ACCUMULATOR PRESSURE IS :5000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3;. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TI ME AND PRESSURE REMAI NI NG AFTER ALL UNITS ARE CLOSED WITH CHAROI NG PUMP OFF. 4. RECORD ON IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. PIPF RAMS BLI ND RAMS DRILLING SPOOL PI PF RAMS DRLG SPOOL CSG SPOOL 13-3/8" STARTINI~ HEAD ALL BOP EQUIPMENT 5000 PSI RATED 11. 12. 18. 13-5/~" BOP STAC:K TEST -1. FILL BOP STACK AND MANIFOLD WITH A NON-FREEZING LIQUID. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACTED. MARK RUNNING dOINT WITH PREDETERMINED PLUG SEATING DEPTH. RUN TEST PLUG ON DRILL PIPE AND SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS. 3;. CLOSE ANNULAR PREVENTER AND UPSTREAM VALVES. 4. FUNCTIONALLY TEST CHOKES. 5. 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. 6. INCREASE PRESSURE TO :5000 PSI AND HOLD FOR A MINIMUM OF 3; MINUTES. BLEED PRESSURE TO ZERO. ?. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PI PE RAMS. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR AT LEAST 3; MI NUTES. BLEED PRESSURE TO ZERO. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES AND OPEN CHOKES. INCREASE PRESSURE TO SO00 PSI AND HOLD FOR AT LEAST 3; MINUTES. BLEED PRESSURE TO ZERO. 9. 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 $ MINUTES. 10. TEST REMAINING UNTESTED MANIFOLD VALVES (IF ANY) WITH 5000 PSI UPSTREAM OF VALVE AND ZERO PRESSURE DOWN- STREAM. BLEED PRESSURE TO ZERO. OPEN BOTTOM SET OF PI PE RAMS. BACK OFF RUNNING dOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR AT LEAST :5 MI NUTES. 1:5.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. 1 4. TEST STANDPIPE VALVES TO 5000 PSI. 15. TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI. 16. CHECK OPERATION OF DEGASSER. 1 ?.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 TYPICAL MUD PIT SCHEMATIC TRIP TANKS SANDTRAP (30 BBLS) ISHAKER J ISHAKER I ISHAKER I DEGASSER (83 BBLS) DESILTER (97 BBLS) 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 100o 2000 3000 400o ~5000 6000 7000 8000 10000 ..................... 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 [ f I I I RKB F.I.EVATION : 50' ~. 20" Casing TVD=I l0 TMD=ll0 ~ .'=0 AR( O ALA SKA, Ill,lC. WGI-5 SCALE: I"= I000' SHL: U 1 IN 14E 11 1080' FI?{L 1034' FEL THL: U 1 iN 14E 11 1080' FIlL 1034' FEL BHL: U 1 IN 14E 11 1080' F]qL 1034' FEL S01'E 13-3/8" Casing T~.)=3500 TMD=3500 D] :P=0 TVD=4500 TMD --4500 DEP--0 K-5 TVD=7555 T /1I)=7555 DEP=0 LCU TVD=8120 MD=8120 DEP=0 9-5/8" Casing TV[ =8180 TMD=8180 DEI~=0 SAG River TVD=1 180 TMD=8180 DEP=0 Top_ Sadlerochit T~rD=8275 TMD=8275 E EP=0 T,aLRGET TVD=85)0 TMD=8500 DEP=0 G/O Contact TVD::8625 TMD=8625 DEP~=0 Base Sadlerochit T V'D=8720 TMD=8720 )EP=0 TD TVD=8740 TM I3=8740 DEP=0 0 1000 2000 3000 4000 5000 6000 7000 VERTICAL SECTION ARCO ALASKA, INC. wgi-5 S01'E 0 0 E - W COORDINATES -4000 -3000 -2000 - 1000 0 1000 2000 3000 4000 ............................. ? ~'"~ .......... i i i i i i i i i i i i i i i ii i i i i i i i i 9 ~ 100 wgi_o ~oo 4~8~ l~7 /~7 5630 ~B99 51~ 3850 ~ 8689 01 1552 [1-09 ........................................................................ -3000 2000 '1000 0 0 -1000 -2000 -2000 -3000 '-3000 -4000 -4000 -4000 -3000 -2000 -1000 0 1000 2000 3000 4000 CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE Fee 1. (2 thru (8) (3) Adm :in.Z,6'~. .~.~p~~ 9. (9 thru 13) ' 10. 5- (10 and 13) 12. 13. (4) Cas~ ~,~ (14 thru 22) OPE a (23 thru 28) Company./~/~,-, Is the permit fee attached .......................................... Lease & Well No. /~z~--___4' ,~b~ ~--Pr~?c~Pi YES NO REMARKS 2. Is well to be located in a defined pool ............................. y~ 3. Is we]] located proper distance from property line .................. ~__ 4. Is we,ll located proper distance from other wells .................... 5. Is suz~icient undedicated acreage available in this pool ............ . 6. Is well to be deviated and is wellbore plat included ................ ~_ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... 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. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Is conductor string provided ..... - ................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate ~ Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ,~~ psig .. Does the choke manifold comply w/API RP-53 (May 84) ............ ; ..... Is the presence of H2S gas probable ................................. ' ('29-thrJ. 3-'I)'- rev: 01/30/89 6.011 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE J,, Additional Remarks: O ~Z Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi .. No special 'effort has been made to chronologically organize this category of information. PROGR~M: ~ I $ ~ REVISION: 4.1 PART NUMBER: W5550-MICRO Start of execution: Tue 6 MAR 90 4:05pm WELL DATA FILE: C: \WDSDATA\SUZANNE~\W09206.WDF ECC: 9206.00 COMPANY NAME: ARCO ALASKA INCORPORATED WELL NAME: W G I - 5 FIELD: PRUDHOE BAY LOCATION: NORTH SLOPE Top of Well: Bottom of Well: Level Spacing: 8100. 000 8740.000 0.500 COMPANY:ARCO ALASKA INCORPORATED WELL:W G I - 5 FIELD:PRUDHOE BAY COUNTY:NORTH SLOPE STATE:ALASKA TAPE INFORMATION FILE INTERVAL:. START= 8738.000 END= 8106.000 DEPT 8738.000 8713.000 8688.000 8663.000 8638.000 8613.000 8588.000 8563.000 8538.000 8513.000 8488.000 8463.000 8438.000 8413.000 8388.000 8363.000 8338.000 8313.000 8288.000 GR SPD SP AC T2R2 T2R2 o.ooo o.ooo - o.ooo 50.000 350.00o o.'ooo 0.000 27.255 -1,329 86.036 462.562 626.625 53.732 43.996 -1.388 9 .e 5 6.5oo 47.271, 44.990 -1.399 96.805 471.750 657.812 31.498 44.995 -1.514 95. s3 48 . s0 6 5.500 48.137 44.995 -1.164 99.826 475.687 628.437 25.644 44.995 -1.414 90.835 475,375 657.750 32.426 44.995 -1.291 100.098 477.875 657.125 22.046 44.995 -1.302 83.504 455,812 608.937 20.513 '44.995 -1.397 88.432 461.375 624.187 17.625 44.995 -1,344 87.441 486.500 662.437 23.059 44.995 -1.460 94.715 512.687 690.937 18.560 44.995 -1.171 86.288 449.750 620.!25 17.439 44.995 -1.286 73.408 407.750 548.500 18.521 44.995 -1.341 70.643 378.375 513.187 21.832 44.195 -1.410 83.869 447.750 599.750 25.722 44,995 -1.338 94.216 482.187 655.812 90.608 44.995 -1.174 82.905 445.125 605.!87 22.212 46.553 -1.345 108.269 531.062 734,562 CHT T!R2 100.000 450.00O 549.817 631.562 551.914 581.437 559.261 667.000 558.191 675.500 560.521 630.312 564.472 659.250 592.646 668.750 597.283 600.812 602,534 632.625 63'3.275 665.000 623.644 693.812 631.507 627.687 632.273 547.125 641.755 511.312 657.945 584.562 646.812 653.375 618.125 607.937 598.607 726.375 CAL TlR1 6.000 350.000' 0.184 445.750 O.056 407.125 -0.018 465.500 -1.310 479.750 1.441 466.312 -0.226 470.062 0.329 467.562 0.071 424.687 -0.015 447.687 0.209 471.062 0.586 488.250 1.599 437.000 0.014 384.750 0.164 357.687 -0.784 414.812 0.259 457.250 1.927 429.687 0.560 509.000 TEMP 0. 000 0.000 151.187 151.256 151.501 151.776 152.037 152.295 152.308 152.381 152.529 152.506 152.286 152.219 151.918 151.941 151.805 151.643 151.549 TTEN 1500.000 2763.821 2757.277 2745.597 2745.190 2751.605 2734.234 2735.487 2723.300 2721.869 2740.593 2715.412 2713.021 2706.799 2689.362 2677.234 2681.352 2676.167 2665.984 8238.000 68.710 86.572 8213.000 47.353 107.623 8188.000 59.041 104.049 8163.000 50.501 90.503 8138.000 52.934 5O.0OO WG I - 5 DEPT GR 8113.000 0 5O .000 .000 8106.000 -999.250 -999.250 WELL DATA FILE: ECC: COMPANY NAME: WELL NAME: FIELD: LOCATION: TOp of Well: Bottom of Well: Level Spacing: NUMBER OF CURVES: 21 46.396 -t.237 585.984 490. 187 663. 000 669. 375 45.995 -1.340 593.049 517.500 718.875 730.750 46.031 -1.362 620.781 516.312 712.437 726.812 45.995 -1.382 644.161 496. 500 688. 500 703. 125 0.000 -80,000 100.000 3i4. 812 423. 750 425. 000 0.461 478.500 1.476 515.062 0.254 518.312 -1.653 478.500 6.000 307.250 151.209 150.926 150.732 150.435 150.047 2647.604 2637.648 2631.127 2644.323 1500.000 SPD SP CHT CAL TEMP TTEN T2R2 T2R2 TlR2 TlR1 O.000 -80.000 100.000 6.000 149.719 1500.000 350.000 450.000 450.000 350.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 HRD1 SPD C: \WDSDATA \ SUZANNE \W09208. WDF 9208.00 ARCO ALASKA INCORPORATED WG I - 5 8120.000 8740.000 0.5O0 DEV SFT2 DEPTH CAL CHT CN CNC HRD2 LSN PE PORZ RB SSD SSN TTEN ZCOR ZDEN GR SHR FILE:MAIN .002 FILE INTERVAL: DEPT GE TTEN CN START= CAL SPD .CNC 8738,00O SSD SFT2 ZDEN END= SHR HRD 1 ZCOR 8122.000 RB ~: HRD2 PE 9'% ~%F% DEV LSN PORZ CHT SSN o. ooo ooo ooo -o. zoo O. 0°o o. ooo 8713. 000' 0.000 3148.286 0.000 9.152 23.998 0.000 6901.617 600.823 2.665 0.605 765.702 0.120 -1.841 931.740 2.952 368.335 0.000 -0.900 1024.487 0.000 8688.000 94.127 3124.61t 22.6i3 9.447 22.998 26 .,613 6574.941. 619.018 2. 604 0.652 761.181 0.066 -1.841 963.413 2.53O 368.335 79.894 2.761 1032.740 225.608 8663.000 58 3036 24 .597 .913 .458 9 22 28 .060 .998 .458 764'7. 324 1311.033 2.272 0.656 1452.906 0.023 -1.841 1814.485 2.493 368.335 80.468 22.934 960.683 239.262 8638.000 39 3011 25 .401 .209 .865 8 .89O .998 .865 7706,160 1208.309 2.302 0.570 1416.749 0.040 -1.841 1757.010 3.317 368.335 64.225 21.080 956.871 198.210 8613. 000 48 3126 23 .703 .616 .612 10 23 27 .142 .998 .612 7382 672 2 .012 .075 .60O 0.572 884.131 0.134 -1 1140 3 .841 .014 .301 368.335 84.516 3.050 1079.927 245.520 8588.000 25.005 3025.252 18.600 9 24 22 .109 .997 .600 8665 1524 2 .742 .278 .258 0.705 1781.882 0.092 -1.841 2132.129 2.117 368.335 77.907 23.733 979.771 194.391 8563.000 32 3024 16 .938 .517 .323 8 24 2O .976 .997 .323 8036 1523 2 .937 .889 .181 0.661 1762.597 0.016 -1 2163 2 .841 .531 .451 368 107 28 .335 .472 .413 1001.440 248.001 8538.000 24 3000 12 .716 .150 .378 9 24 16 .084 .997 .378 7862 1268 2 .699 .347 .299 0.726 1467.245 0.051 -1 1799 1 .841 .792 . 967 368 149 21 .335 .275 .272 10t6.166 295.695 8513.000 22 3030 14 .295 .013 .872 9 24 18 .113 .997 .872 7742 1287 2 .742 .987 .259 0.689 1529.581 0.025 -1.841 1845.552 2.236 368 116 23 .335 .611 .680 1040.465 255.120 8488.000 2O 3024 13 .30O .510 .665 9 24 17 .O02 .997 .665 78O8 1406 2 .035 .601 .217 0.700 1647. 145 0.013 -1 1959 2 .841 .638 .150 368 145 26 .335 .OO8 .248 1025.992 302.752 8463.000 23 2991 16 .75i .167 .484 9 24 2O .213 .997 .484 8622 1782 2 .672 .634 .162 0.773 2060.919 0.051 -1 2346 1 .841 .116 .663 368 95 29 .335 .636 .589 1013.176 221.963 8438.000 19.172 2964.109 11. 920 9 24 15 .190 .997 .920 7342 1159 2 .3O5 .5il .319 0.643 1330.015 0.018 -1 1581 2 .841 .628 .604 368 144 20 .335 .370 .071 1006.441 280.462 8413.000 19 2969 8 .327 .856 .129 9 24 12 .113 .997 .129 7303.273 1006.471 2.442 0.694 1087.746 0.064 -1 1367 2 .841 .606 .196 368 205 12 .335 .000 .598 1013.995 332.628 8388.000 21 2976 5 .314 .749 .013 9 24 9 .140 .997 .0t3 6568 706 2 .508 .106 .517 0.660 843.946 0.031 -1 ~089 2 .841 .488 .465 368 270 8 .335 .142 .037 1018.749 364.497 8363.000 21 2956 8 .155 .430 .644 9 24 12 .559 .997 .644 7542 1254 2 .230 .584 .265 0.652 1465.920 0.020 -1 1827 2 .841 .827 .530 368 207 23 .335 .625 .330 1023.843 346.044 WG I - 5 TTEN SPD SFT2 HRD 1 HRD 2 LSN SSN CN CNC ZDEN ZCOR 8338.000 29.455 2948.250 19.378 8313.000 88.113 3018.375 26.090 8288.000 19.635 2913.469 17.955 8263.000 166 2967 35 .934 .766 .469 8238.000 67 3082 27 .942 .001 .315 8213.000 54 2913 22 .748 .166 .216 8188.000 62 2915 17 .127 .193 .185 8163.000 48 3O88 34 9.334 7789.441 24.997 1221.895 23.378 2.303 8138.000 51 1500 0 0 1438 0 8122.000 .578 .476 .047 10.006 6678.738 25.956 647.901 30.090 2.581 0 783 0 .596 .585 .066 9.448 8534.535 25.956 1815.073 21,955 2.!18 0 2088 0 .761 .249 .027 9.784 7483.207 0.598 25.434 1062.364 1234. 855 39.469 2.366 0.048 11.073 5960.496 25.033 471.803 31.315 2.565 0 669 -0 .376 .750 .007 9.559 8278.363 25.003 1593.441 26.216 2.159 0 1911 0 .676 .0O3 .025 9.559 8535.!I3 24.997 2056.773 21.185 2.022 0 2369 -0 .680 .524 .011 .083 11.873 8937.805 0.636 .906 24.997 1171.368 !416.794 .3!6 38.316 2.437 0.183 PE -1.841 1776.693 3.228 -1.841 1034.253 3.045 -1.841 2516.641 1.740 -1.841 1571.761 3.025 -1.841 930.799 6.642 -1.841 2287.151 2.336 -1.841 2858.901 2.302 -1.841 1810.127 2.670 . 508 6. 000 O. 000 O. 000 O. 000 . 000 O. 000 O. 000 0. 000 0. 000 .000 0.000 2.000 -0. 100 0~000 .250 °250 .250 -999. 250 -999.250 -999. 250 -999 -999. 250 -999. 250 -999.250 -999 -999. 250 -999.250 -999.250 -999 WELL DATA FILE: ECC: COMPANY NAME: WELL NAME: FIELD: LOCATION: C: \WDSDATA\SUZANNE\W09207 .WDF 9207.00 ARCO ALASKA INCORPORATED W G I - 5 8090.000 8740. 000 0.500 Top of Well: Bottom of Well: Level Spacing: -999.250 -999.250 -999.250 PORZ 368.335 91.464 21.031 368.335 60.271 4.204 368.335 93.991 32.254 368.335 45.311 17.215 368.335 65.946 5.158 368.335 68.227 29.729 368.335 85.496 38.077 368.335 39.602 12.900 0.000 0.000 0.000 -999.250 -999.250 -999.250 1027.307 234.067 1054.008 187.092 1020.917 229.539 1037.243 172.421 1120.909 211.103 1030.969 190.456 1023.458 203.371 1156.331 147.529 300.000 0.000 -999.250 -999.250 NUMBER OF CURVES: '18 DEPTH AC ACQ RILD RILM SP TEMP TTEN CAL SPD CHT TlR! CILD TlR2 GR T2R1 RFOC T2R2 FILE:REPEAT.003 FILE INTERVAL: START= 8739.000 END= 8091.000 DEPT 8739.000 8714.000 8689.000 8664.000 8639,000 8614.000 8589.000 8564.000 8539.000 8514.000 8489.000 8464.000 8439.000 8414.000 8389.000 8364.000 8339.000 8314.000 GR AC 0.000 5O.O00 0,000 84.721 78.896 87,861 47.161 95.503 32.372 95.911 84,538 92~061 21,357 96.904 26,173 98.919 25.910 83.883 21,262 87.702 17.860 92.329 22.619 96,919 17.127 85,714 19.927 74.529 19,705 69,914 25,662 91,182 21.663 92.804 90.275 SPD T2R2 0.000 350.000 30.680 469.125 41.438 419.125 41.996 474.312 42.996 486,000 43.996 465.062 43.996 461.750 43.966 462.825 44.402 454.937 44.002 457.37~ 44,995 484.437 44.589 506.437 44,990 459.937 44,995 409.937 44.995 388.562 44,995 423.625 45.396 472,250 45.037 SP T2R2 -80.000 450.000 -1.314 623,000 -1.447 564,812 -1,483 646,062 -1.261 672,875 -1.265 605.750 -1.362 650,375 -1.288 639.812 -1.292 609.375 -1.557 622.125 -1.315 660.812 -1.310 672.500 -1.373 635.937 -1,306 563,437 -1,503 516.187 -1.403 576.187 -1.332 632,562 -1.089 CHT TlR2 100.000 45O.O00 591.974 628.500 651.824 564.562 675.583 649.062 700.720 678.500 707.899 619.375 652,750 720.760 649.500 730,339 604.625 735.729 631.500 733.125 665.812 742,731 686,625 748.504 647.437 746.427 570,375 746.139 515.500 752,190 563.875 753.425 635.375 761.486 CAL TlR1 6.000 350,000 0,072 461,687 -1.259 394.812 1.017 463.562 0.258 477.125 0,131 456.562 0.733 457.187 0,852 454.875 0,170 425.187 0.461 447.937 -0.013 472.250 0.762 500.875 0,204 455.062 0.186 399.750 0.920 367.187 -0,112 386.937 0,319 455,812 2.404 TEMP 0.000 0.000 151.545 151.558 152.133 152,659 153.094 153.501 153.793 153.895 153.984 153.985 153.989 153.745 153.599 153.394 153.028 153.027 TTEN 1500.000 2757.965 2758.969 2754.993 2749.598 2755.675 2744.641 2737.234 2733.388 2728.015 2718.331 2721.052 2710.743 2709.989 2704.856 2687.542 2683.211 2668.154 8289,000 22.!97 108.548 8264,000 143.576 106.360 8239.000 95,!14 90.318 8214. 000 54,948 107,656 8189.000 54,177 104.250 8164,000 74. 147 107.355 8139,000 47.892 57,878 WGI -5 DEPT GR AC 8114.000 129.572 50.0OO 8091. 000 -999 -999 .250 ,250 WELL DATA FILE: EcC: COMPANY NAMe: WELL NAME: FIELD: LOCATION: Top of Well: Bottom of Well: Level Spacing: 46.559 -1,396 759.343 525.125 730,125 726.375 44.879 -1,405 749.071 501,562 706,000 715,000 46.437 -1.312 750.403 506.937 681. 937 690. 437 46.589 -1.336 749.760 518.500 719,937 732,500 46.960 -1,276 755,656 513. 312 707. 437 721,187 46.402 -1.349 754.330 529.812 730.500 707.125 46.402 -1.214 757.584 314.750 418,187 424,437 0.843 508.500 0.487 489.625 -1.145 496.375 0,952 513,000 -0.091 509.500 0.290 490.750 0.806 306.375 152.885 152.758 152.588 152.344 152.116 151.875 151.507 2670.666 2659,583 2654.595 2646.339 2629,463 2639.977 2630.573 SPD SP CHT CAL TEMP 5~EN T2R2 T2R2 TlR2 TlR1 0.000 -80.000 100.000 6.000 151.213 1500,000 350.000 450,000 450.000 350.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999,250 C: \WDSDATA\SUZANNE\W09209. WDF 9209.00 ARCO ALASKA INCORPORATED WG I - 5 8120.000 8740.000 0.500 NUMBER OF CURVES: 21 DEPTH CAL CHT CN CNC HRD2 LSN PE PORZ RB SSD SSN TTEN ZCOR ZDEN DEV SFT2 GR SHR HRD1 SPD FILE: REPEAT, 004 FILE INTERVAL: START= 8738.000 END= 8122.000 DEPT GR C~25 SSD SHR RB DEV CHT CN.. CNC ZDEN ZCOR PE PORZ 8738-000 "0. 000 6. 000 0. 000 0 . 000 0. 000 0 . 000 300. 000 1500. 000 '0. 000 0. 000 0. 000 0. 000 0. 000 0. 000 0. 000 0. 000 2 . 000 -0. 100 0. 000 0 . 000 8713.000 0.000 9~108 6914.551 0.668 -1.841 368.335 1013.119 3176~.261 22.998 678.635 822.752 1018.654 0.000 0.000 0,000 0.000 2.605 0.097 2.395 2.717 8688.000 68.648 3119.367 23.001 9.445 6804.777 0.666 -1.841 22.998 740.524 842.586 1081.562 27.001 2.556 0.067 2.417 368.335 1121.482 79.837 227.964 5.695 8663.000 49.032 3033.548 23.854 9.037 7729.633 0.654 -1.841 22.998 1277'.820 1474.213 1794.111 27.854 2.282 0.034 2.508 368.335 1083.290 83.628 244.580 22.290 8638.000 35.823 3019.165 26. 842 8.890 7844.383 0.570 -1.841 22.992 1260.145 1486.631 1779.549 30.842 2.298 0.049 3.321 368.335 1078.537 63.310 200.304 21.327 8613.000 8588.000 59.269 3190.868 22.352 23.053 3038.602 19.314 10.250 7272.152 0.563 -1..841 22. 004 681. 981 854. 833 1116. 729 26.352 2.604 0.127 3.403 9.220 8459.512 0. 722 -1.841 22.998 1534.352 1715.184 2075.952 23.314 2.258 0.078 1.997 368.335 1195.256 90.001 252.237 2.758 368.335 1080.519 81.738 208.752 23.735 8563.000 36 3019 17 .838 .354 .556 8.899 7935.676 0.657 -1.841 23.998 1556.879 1759.271 2163.061 21.556 2.169 0.004 2.487 368.335 1080.664 101.698 245.014 29.139 8538.000 24 2997 il .793 .223 .810 9. 036 7791. 426 0. 726 -1. 841 24.997 1283.802 1468.452 1816.034 15.810 2.286 0.040 1.969 368.335 1068.244 163.394 315.930 22.070 8513.000 2O 3030 15 .219 .948 .440 9.039 7766.117 0.692 -1.841 25.962 1272.227 1518.739 1807.588 19.440 2.273 0.033 2.209 368.335 1084.323 113.156 252.873 22.825 8488.000 17 2998 14 .735 .589 .699 9.001 7834.945 0.667 -1.841 25.997 1406.565 1623.380 1911.984 18.699 2.236 0.023 2.401 368.335 1052.084 139.461 303.114 25.104 8463.000 24 2985 16 .237 .899 .434 9.224 8553.039 0.763 -1.841 25. 997 1779.0tl 1964. 335 2395. 555 20.434 2. 162 0. 046 1. 721 368.335 1032.650 97.426 225.715 29.590 8438.000 18 2980 12 .449 .378 .915 9.213 7295.082 0.650 -1.844 26.433 1137.640 1267.669 1607.675 16.915 2.322 0.015 2.545 368.338 1023.820 132.698 268.783 19.892 84!3.000 19 2974 7 .425 .395 .119 9.113 7197.387 0.664 -1.844 25.997 960.378 1107.704 1371.485 11.119 2.421 0.047 2.432 368.338 1032.438 214.465 329.301 13.900 8388.000 18.208 2993.556 5.141 9.188 6293.715 0.671 -1.844 25.997 658.619 775.759 989.045 9.141 2.544 0.016 2.376 368.338 1038.966 273.693 372.451 6.454 8363.000 21.611 9.585 7540.875 0.692 -1.844 368.338 1031.747 WGI - 5 DEPT GR CAL SSD SHR RB DEV CHT 8338.000 TTEN SPD SFT2 HRD1 HRD2 LSN SSN 8313.000 CN CNC ZDEN ZCOR 27.957 2931.562 17.747 8288.000 88 3022 27 .637 .964 .729 8263.000 2O 2923 17 .505 .806 .972 8238.000 158 3001 36 .205 .275 .262 8213.000 72 3051 24 8188.000 8163.000 .303 .530 .293 51.858 2910.106 23.133 .213 .515 .307 .707 .9O5 .652 8138.000 61 2904 17 .912 .000 .000 8122.000 48 3101 36 5O 1500 0 -999.250 -999.250 -999.250 WELL DATA FILE: C ECC: 9.438 77t9.410 0.584 25.997 1209.041 1448.279 21.747 2.288 0.035 10.232 6622.785 0.613 25.997 628.738 790.083 31. 729 2. 586 0. 063 9.559 8355.242 0.768 26. 962 1783. 804 2061. 021 21.972 2.109 0.011 9.746 7468.652 0.625 26. 962 1030. 543 1258. 163 40.262 2.366 0.047 11.126 5637.855 0.377 26.003 409.267 604.169 28.293 2~562 -0.040 9.659 8147.148 0.656 26.033 1560.227 1871.681 27.I33 2.154 0.014 9.556 8437.027 0.679 26. 033 2024. 694 2391. 609 21.307 2.003 -0.025 11.533 7436.223 0.634 26. 033 1126. 810 1352.840 40.652 2.281 0.010 6. 000 0. 000 0. 000 0.000 0.000 0.000 0.000 2.000 -0.100 -999. 250 -999.250 -999. 250 -999. 250 -999.250 -999. 250 -999. 250 -999. 250 -999. 250 : \W SnA A\SUZAN \W09210.WDF 9210.00 ARCO ALASKA INCORPORATED WGI--5~ 3440.000 8200.000 0.500 PE -1.844 1794.435 3.166 -1.836 994.834 2.881 -1.836 2467.377 1. 693 -1.836 1540.332 2.765 -1.836 893.003 6.632 -1.838 2271.229 2.497 -1.838 2892.965 2.311 -1.838 1761.968 2.681 0.000 0.000 0.000 -999.250 -999.250 -999.250 COMPANY N~E: WELL NAME': FIELD: LOCATION: PORZ 368.338 99.559 21.968 368.329 58.084 3.878 368.329 93.497 32.760 368.329 45.563 17.200 368.329 72.659 5.310 368.332 67.008 30.069 368.332 89.613 39.199 368.332 38.383 22.393 0. 000 23.174 0.000 -999.250 -999.250 -999.250 Top of Well: Bottom of Well:' Level Spacing: 1019.776 241.430 1061.000 187.822 1017.646 228.464 1055.401 175.833 1091.025 215.075 1002.548 192.054 990.855 214.061 1121.989 149. 126 300.000 0. 000 -999.250 -999.250 DEPTH CAL0 CHT0 CN04 CNC0 HRD2' LSNO PE04 PORZ RB04 SSD0 SSN0 T~EN ZCOR ZDEN DEV0 SFT2 GR04 SHR0 HRDI SPD0 FILE:CHCN .005 FILE INTERVAL:~ START= 8200.000 END= 3448.000 DEPT 8200.000 8175.000 8150.000 8125.000 8100.000 8075.000 8050.000 8025.000 8000.000 7975.000 7950.000 7925. 000 TTEN CN -999.250 -999.250 -999.250 0.000 2932.152 30.007 64.718 2939.598 54.103 68.750 2919.708 54.234 135.809 2931.305 65.677 121.084 2938.436 65.133 108.374 2924.759 67.157 100.383 2884.224 60.702 116.954 2918.588 61.251 100.151 2912.850 51.977 105.688 2903.057 58.158 66.892 CAL SPD CNC -999.250 -999.250 -999.250 1.643 58.958 29.445 1.643 57.994 50.842 1.641 57.994 5O.958 1.708 57.994 61.120 1.643 57.994 60.637 1.683 58.395 62.434 1.642 58.400 56.702 1.708 58.988 57.189 1.643 58.030 48.954 1.642 57.994 54.443 1.643 SSD SFT2 ZDEN -999.250 -999.250 -999.250 9774.996 2054.283 2.177 2131.172 136.990 2.194 2339.758 192.308 2.081 2314.165 173.425 2.186 1188.474 84.278 2.125 2182.7!9 162.269 2.058 2122.331 143.417 2.147 2093. 667 152.948 2.141 2248.681 182.931 2.096 2282.460 160.647 2.173 2378.555 SHR HRD1 ZCOR -999.250 -999.250 -999.250 0.674 2310.606 0.132 0.153 272.262 -0.730 0.161 376.944 -0.720 0.173 346.546 -0. 687 0.131 135.075 -1.085 0.220 326.539 -0. 769 0.184 291.148 -0.750 0.201 305.344 -0.760 0.181 338.690 -0.737 0.152 344.159 -0.699 0. 144 RB HRD2 PE -999.250 -999.250 -999.250 -1.838 2779.895 2.345 -1.836 458.282 21.892 -1.836 582.962 18.220 -1.838 472.801 14.925 -1.838 249.466 17.428 -1.838 581.678 24.937 -1.838 483.690 22.227 -1.838 463.222 18.189 -1.838 555.765 18.295 -1.838 474.941 17.388 -1.838 DEV LSN PORZ -999.250 -999.250 -999.250 368.332 40.876 28.668 368.329 27.756 27.659 368.329 25.913 34.465 368.332 24.476 28.136 368.332 24.029 31.812 368.332 22.839 35.883 368.332 24.277 30.469 368.332 26.781 30.867 368.332 25.959 33.567 368.332 24.876 28.881 368.332 CHT SSN -999.250 -999.250 975.635 139.998 1015.920 123.091 1033.068 123.460 1039.272 123.919 1029.124 130.372 1033.052 129.216 1035.895 125.398 1039.547 128.591 1026.045 123.704 1032.729 126.842 1030.294 7900.000 80,446 2874,698 51.162 1,708 58,000 48,231 1854.724 152,803 2.239 0,202 2i3,309 -0.791 -1.838 362,338 11,334 368.332 29.159 24,913 1024,214 128.805 7875,000 68,357 2893,354 55,290 1 57 51 ,643 ,994 ,896 2213,667 149,198 2,172 0,209 276,237 -0,717 -1.830 513,339 23,076 368.323 25.721 28,971 1029.567 127.824 7850,000 46,791 2866,399 38.012 1 57 36 ,643 ,994 ,554 23!5,853 186,247 2,148 0,208 342,197 -0.701 -1,830 522.117 15,736 368,323 35,296 30,443 1027.660 133,032 7825,000 60.550 2850,007 48,686 ! 59 46 ,643 ,030 .032 2213,273 126,101 2,266 0,219 286,723 -0,681 -1.837 406,385 20,418 368.331 29,252 23,272 1016,379 131,407 WGI-5 DEPT GR CAL SSD SHR DEr CHT TTEN SPD SFT2 HRD 1 HRD2 LSN SSN CN CNC ZDEN ZCOR PE PORZ 7800,000 61,954 2858.792 60,148 1,643 59,036 56,211 2241 162 2 ,261 ,063 ,160 0,211 318,818 -0,715 -1 496 18 ,830 ,944 ,613 368 25 29 .323 ,504 ,716 1011.664 126,708 7775,000 70,335 2845,206 85,451 1 59 78 ,643 .000 ,680 2354,273 157,910 2.241 0,198 326,877 -0.656 -1 448 16 ,830 ,723 .144 368 24 24 .323 .300 ,785 1010,052 133,681 7750,000 94 2832 52 ,314 ,043 ,713 t 59 49 ,643 ,988 ,608 2307 i79 2 ,649 ,339 ,203 0,168 302,922 -0,682 -1 493 15 .83O ,956 .218 368 27 27 ,323 ,447 ,077 1000.328 127,4'81 7725,000 77 2827 47 .180 ,974 ,267 1 59 44 ,643 ,024 ,772 2251 153 2 ,023 ,332 ,171 0,244 304,467 -0,708 -! 502 21 .830 ,537 ,069 368 3O 29 ,323 .730 .006 994,339 129,800 7700.000 102 2815 58 .990 ,764 ,176 1 58 54 ,643 ,994 ,459 2228 140 2 .024 ,303 ,234 0.207 264.897 -0,690 -1 465 21 ,830 ,715 ,575 368 29 25 ,323 ,262 ,215 984,881 126,854 7675,000 97.421 2830,789 49,890 1 58 47 ,643 ,994 ,101 2147 129 2 .318 ,309 ,179 0.159 274,016 -0.732 -1 478 26 .830 .866 .540 368 26 28 .323 .135 ,560 972,218 129.262 7650,000 108 2822 52 ,343 .209 ,313 1 58 49 .643 ,994 ,253 2259 156 2 ,961 ,947 ,148 0,180 318-960 -0,714 -1 518 21 .830 ,557 ,389 368 27 3O .323 ,416 ,405 972.615 129,092 7625,000 87 2820 49 ,082 ,756 ,305 1 59 46 ,643 .552 .582 2255 150 2 ,076 ,519 .!27 0.180 322,686 -0.724 -1 538 24 ,83O ,119 ,810 368 26 31 ,323 .993 ,725 961,468 131,232 7600.000 93 2791 67 ,345 ,536 ,955 1 59 63 ,643 ,036 ,143 2340,947 164.713 2,252 0,203 288,899 -0,655 -1 469 16 ,830 ,327 ,227 368 23 24 ,323 ,473 ,110 967,024 128,962 7575,000 67 2788 ,781 ,989 1,643 59,000 2226,333 - 143,990 0,189 275.253 -1 482 ,830 ,923 368 26 .323 ,678 968.751. 132.295 7550,000 7525.000 79. 409 2810.101 53.740 89,469 2794.314 44.917 1.643 59.994 50.52O 1.643 59.588 42.685 2344. 684 156.171 2.160 2328.505 171.788 2.250 0. 164 334.389 -0,689 0.208 257,999 -0. 659 -1.830 528.823 22.395 -1.830 497.231 16.712 368.323 25.528 29.693 368.323 31,203 24.234 970.176 126.027 959.927 133.696 75O0.0OO 105.571 2773,418 50.152 1.643 59,030 47.33'4 1440.338 78,003 2.177 0,146 175.379 -0.957 -1,838 280.617 25.107 68.332 25.932 28,660 964.457 127.104 7475.000 54.316 2768.980 45.253 1 58 42 .643 .994 .984 2400,465 178.340 2.267 0.249 304.216 -0.635 -1.830 462.022 13.527 68,323 32.479 23.190 965.456 136.196 7450.000 7425.000 50.253 2750.107 43.078 59.735 2760.419 42.739 1 58 41 t 58 4O .643 .994 .053 ,643 .994 .751 2324.821 148,325 2,232 2099,062 124.004 2.274 0. 144 306.818 -0.667 0. 161 244,196 -0.708 -1.830 466.582 19,519 -1.830 397.272 20.195 368.323 33.458 25.349 368.323 34.073 22.807 968.917 139.443 965.482 141.405 WG I - 5 DEPT GR C~L SSD SHR RB DEV CHT TTEN SPD SFT2 HRD1 HRD2 LSN SSN CN CNC ZDEN ZCOR PE PORZ 7400.000 50.351 2754.057 40.708 1 59 38 .643 .036 .948 2205.452 126,564 2,325 0,186 243.125 -0.661 -I 393 19 ,83O .204 .073 68 33 19 .323 .307 .726 974.157 133.023 7375,000 49.5-94 2738.075 41.486 1 58 39 .643 ,994 .63'8 2128,029 130,289 2.304 0 248 -0 .249 .486 ,689 -1.830 377.362 16.733 68.323 33.511 20.980 966.543 137.593 7350,000 47.940 2747.763 36.464 1 59 35 .643 ,400 ,179 2215.461 176.879 2. 184 0 307 -0 ,171 .682 .712 -1 469 14 .830 .237 .164 368 34 28 .323 ,771 .218 968,439 138.148 7325,000 52.5O5 2731.726 38,653 1 59 37 .643 ,365 ,123 2139.928 111,283 2,265 0 255 -0 ,250 .931 .700 -1 408 26 .832 .819 .134 368 35 23 .325 .699 .3O8 967.084 143.863 7300.000 54.721 2734,625 36,708 1,643 60.030 35,395 2153.001 119.223 2.264 0 256 -0 ,180 .861 .697 -1 414 23 .838 .287 .510 368 37 23 .332 .970 ,385 968. 827 149.456 7275.000 54.631 2741.840 37.350 1 60 35 .708 ,000 .966 2218.215 161.689 2,292 0 261 -0 .142 .877 .670 -1 408 12 .838 .445 .874 368 40 21 .332 .226 .686 973.909 143.348 7250.000 55.017 2747,942 34,818 1 6O 33 .643 ,952 .717 2261.835 14t.996 2,237 0 308 -0 .180 .166 .680 -1 432 18 .838 .912 .415 368.332 41.344 25.001 974.696 143.131 7225,000 43.288 2711.738 40,665 1 6O 38 .643 .958 .909 2201.196 158.328 2,152 0 290 -0 .193 .131 ,728 -1 515 20 .830 .656 .823 368 33 3O .323 .328 .172 966.127 142.042 272t.752 38.713 7175.000 55 2711 42 .724 .677 .529 1.643 2424.051 0.171 -1.830 368.323 981.545 60.994 157.792 312.063 517.813 32.719 137.770 40.565 2.219 -0.648 21.119 26.130 7150.000 52 2714 36 .147 .659 .981 1.683 2271.122 0.208 -1.830 368.323 975.913 60.030 157.253 321.442 474.765 33.364 138.830 35.638 2.189 -0.696 18.083 27.921 7125.000 52 2696 39 .968 .451 .910 1.643 2277.878 59.994 137.524 38.239 2.230 0. 159 -1. 830 368. 323 969. 766 291. 133 464. 934 36. 736 143. 052 -0.679 22.327 25.484 7100.000 39 2708 35 .831 .434 .761 1.643 2214.818 59.994 143.008 34.555 2.285 0.206 263.336 -0.674 -1.830 368.323 982.867 412.772 36.755 145.159 16.625 22.150 7075.000 52 2687 36 .201 .202 .650 1.643 2108.140 60.394 144.959 35.344 2.185 0.172 272.398 -0.740 -1.830 368.323 968.559 457.050 39.754 144.012 19.603 28.197 7050.000 52.863 2653.706 40.893 1.643 2238.939 60.000 149.909 39.112 2.225 0.187 304.368 -0.690 -1.831 368.324 984.633 440.253 33.559 138.461 17.173 25.774 7025.000 71.114 1.643 2283.848 2677.768 60.958 162. 385 49.353 46.624 2.177 0.180 329. 102 -0.697 -1.830 368.323 971.536 486.100 26.348 129.187 17.798 28.642 WGI-5 DEPT GR CAL 'SSD SHR RB DEV CHT TTEN SPD SFT2 HRD1 HRD2 LSN SSN CN CNC ZDEN ZCOR PE PORZ 7000.000 65 2649 47 .410 .053 .712 1.643 2177.408 60.988 141.379 45.167 2.190 0.209 289.749 -0.719 -1.830 368.323 982.812 464.590 30.705 139.025 21.174 27.883 6975.000 50 2635 41 .603 .152 .627 1.643 2313.994 60.030 138.367 39.764 2.315 0.153 275.996 -0.637 -1.830 368.323 985.232 408.759 35.443 143.418 17.364 20.280 6950.000 57 2640 40 .277 .213 .252 1.643 2315.430 60.558 148.636 38.542 2.278 0.175 296.575 -0.651 -1.838 368.332 976.245 425.261 34.061 140.045 16.352 22.557 6925.000 56.462 2640.261 39.732 1.643 2343.460 59.994 134.911 38. 081 ~2.240 0.201 294.867 -0.659 -1.838 368.332 982.200 477.046 34.065 136.632 24.298 24.828 6900.000 59.851 2644.926 40.461 6875.000 57.671 2627.781 41.334 1.643 2292.162 60.0.36 148.043 38.728 2.254 .. 1.643 2420.946 60.000 152.142 39.503 ~.9 316 0.176 284.717 -0.662 0.176 279.435 -0.612 -1.830 368.323 983.156 441.328 33.992 139.395 17.660 23.369 -1.830 368.323 979.270 444.962 34.929 135.193 17.041 20.251 6825.000 6800.000 61.459 1.643 2215.600 0.201 -1.830 368.323 2595.143 61.030 132.057 218.672 399.998 36'738 35.115 33.981 2.349 -0.649 18.193 18.245 53.024 1.643 2827.830 0.187 -1.808 368.323 2597.473 60.994 264.220 466.551 720.740 31.739 40.744 38.979 '2.100 -0.607 14.941 33.326 991.831 147.871 988.897 133.575 6775.000 58.754 1.643 2845.280 0.192 -1.651 368.323 2601.607 61.994 246.-551 470.368 758.779 27.706 47.825 45.267 2.081 -0.611 18.740 34.504 990.338 127.446 6750.000 60.946 1.643 2819.202 0.197 -1.496 368.323 2573.556 61.030 268.142 499.555 794.115 32.516 43.900 41.782 2.035 -0.633 17.445 37.263 988.377 134.032 6725.000 45.337 2535.709 54.293 1.643 3075.097 61.994 341.235 51.011 1.876 0 737 -0 .226 .228 .645 -1.349 1059.804 19.061 368.323 23.320 46.912 994.781 121.005 6700.000 51.299 1.643 2808.576 2555.531 61.994 223.345 45.696 43.377 2.148 0 420 -0 .221 .737 .592 -1.189 680.273 18.382 368 28 3O .323 .278 .395 981.387 129.940 6675.000 57.700 256!.960 48.888 1.643 2785.417 60.994 203.737 46.211 2.194 0 414 -0 .209 .776 .579 -1 608 17 .039 .834 .741 368 27 27 .323 .828 .651 983.683 129.252 6650.000 58.303 1.643 3223.188 2561.545 61.558 322.365 50.332 47.493 2.069 0 567 -0 .203 .660 .545 -0 894 15 .889 .357 .429 368 25 35 .323 .286 .234 984.033 120.699 6625.000 52.344 2573.445 34.772 1.643 2092.788 61.588 108.291 33.677 2.318 0.240 237.992 -0.693 -0 363 21 .733 .147 .991 368 39 20 .323 .299 .135 970.847 ~52.978 WGI-5 DEPT GR CAL SSD SHR RB DEV CHT TTEN SPD SFT2 HRD1 HRD2 LSN SSN CN CNC ZDEN ZCOR PE PORZ 6600.000 49 2551 44 .992 .793 .151 1.643 2t44.470 61.994 120.782 42.005 2.309 0 226 -0 .163 .271 .682 -0 401 21 .588 .292 .612 368 32 2O .230 .872 .666 972.887 147.535 6575.000 52 2'549 38 .879 .194 .514 1.643 2458.950 61.994 197.034 37.000 2.199 0 338 -0 .231 .737 .647 -0 529 14 .436 .457 .518 368 41 27 .057 .262 .331 973.760 149.536 6550.000 46 2534 4O .354 .397 .638 1.643 2723.978 61.030 199.771 38.885 2.207 0 389 -0 .197 .417 .587 -0 587 17 .287 .423 .214 367 36 26 .886 .448 .833 971. 992 147. 290 6525.000 35.343 2523.676 47.239 1.643 1553.355 61.958 175.148 44.747 1.942 0 298 -t .169 .343 .004 -0 396 10 .137 .027 .258 367 29 42 .716 .282 .900 979.639 133.793 6500.000 38.598 1.643 2547.397 0.164 367.545 977.553 6475.000 31.595 1.643 2560.894 0.247 0.153 367.388 2522.747 61.994 224.454 354.446 522.013 31.604 43.863 41.749 2.229 -0.613 10.887 25.506 980.703 137.464 6450.000 56 2503 41 .764 1.643 2451.839 0.191 0.308 367.216 .260 61.958 163.714 255.185 410.607 35.222 .205 39.389 2.388 -0.577 12.693 15.862 975.369 147.404 6425.000 40 2504 4O .319 .914 .351 1 61 38 .643 2407.751 0.200 0.449 367.040 .588 163.236 363.192 538.969 33.788 .630 2.152 -0.677 21.362 30.164 988.474 139.163 6400.000 36 2487 43 .483 .702 .011 t 61 40 .643 .000 .993 2481 143 2 .246 0.235 0.601 366.875 .027 304.791 471.403 33.348 .288 -0.608 21.291 21.918 987.468 149.807 6375.000 50 2450 41 .809 .082 .503 1 61 39 .643 .952 .653 3174 397 1 .447 .478 .933 0.215 0.746 366.712 714.872 1012.677 35.764 -0.605 13.092 43.425 981.107 134.482 6350.000 44.595 2491.665 51.640 1 61 48 .643 .994 .655 2905 282 1 .848 .189 .976 0.187 0.894 366 574.816 882.571 24 -0.639 19.311 40 .545 .911 .819 985.919 119.188 6325.000 43.875 2472.024 66.622 1.643 63.516 61.959 3442 690 1 .906 .026 .542 0.222 1.037 366 1326.066 1945.685 20 -0.709 15.910 67 .386 .445 .162 987.045 105.908 6300. 000 6275.000 49 2421 46 27 2471 41 .626 .002 .412 .518 .929 .971 1 62 44 1 62 40 .643 .588 .013 .643 .593 .069 3006 302 2 2883 301 2 .690 .982 .062 .454 .577 .038 0.231 1.177 366 535.064 817.466 25 -0.587 14.631 35 0.197 1.325 366 525.969 799.485 30 -0.619 14.145 37 .223 .845 .666 .061 .940 .087 984.351 118.006 993.793 128.026 6250.000 36 2437 40 .940 .163 .495 1 62 38 .643 .994 .759 2048 130 2 .993 .224 .204 0.238 1.470 365.903 251.769 433.182 39.371 -0.748 21.661 27.018 990. 172 151.509 6225.000 50.361 2446.619 42.146 1 62 4O .643 .994 .225 2340 114 2 .029 .335 .389 0.215 1.609 365 246.977 380.463 31 -0.603 21.675 15 .742 .225 .839 988.665 138.894 WG I - 5 DEPT GR TTEN CAL SPD SSD EFT2 SHR RB DEV CHT HRD1 HRD2 LSN SSN CN CNC ZDEN ZCOR PE PORZ 6200.000 27 2418 40 .268 .300 .O52 1 62 38 .643 .994 .365 2048.479 163.664 2.171 0. 185 1 281.478 435 -0.761 14 .750 .752 .263 365 33 29 .589 .681 .047 986.472 142.395 6175.000 6150.000 61,365 2441.014 52.571 38.338 2402.836 1.694 62.030 49.482 1.643 62.436 2499.650 178.723 2.177 2828.167 282.487 0.182 1 345.372 568 -0.647 19 0.207 2 484.615 633 .894 .876 .952 .037 .166 365.426 27.706 28.678 365.271 34.667 992.715 128.610 993.194 139.358 6125.000 23.950 2417.872 40,626 1.543 62,958 38,875 2808 o 998 289.488 2.048 0.274 509.661 -0,630 2.180 755.428 11.629 365.116 35.082 36.500 984.816 135.302 6100.000 33,001 2424,312 36,063 1.643 62.436 34. 823 3023,702 271,040 2,073 0,219 507.421 -0.579 2,315 834.064 18.737 364.966 32.448 34.987 998.963 126,072 6075.ooo 26.477 2412.760 48,993 1,643 62.988 46,305 3218.461 574,470 1,643 0,195 1012,700 -0.708 2.456 1605.723 15.649 364.813 23,542 61,014 996.886 109.758 6050,000 33,517 2393.630 42.640 1,643 62,400 40,663 2194.865 174.403 2,221 0,194 298,658 -0,703 2,592 431.512 12.354 364,654 34.017 26,019 1006.221 150,729 6025.000 28,695 2397.739 43.513 1,643 62,952 41,438 3256.166 448.783 1,825 0,189 800.304 -0.632 2 1269 16 .733 .484 .006 364,510 27.464 49,977 997.354 113.134 6000.000 47,735 2379.342 48.984 1.643 62,994 46,296 1987 203 1 ,277 .300 ,975 0 371 -0 .179 .321 .853 2 533 13 .874 .402 .865 364.352 24.348 40,894 998.106 124.265 5975.000 41,006 2376,446 52.465 1,643 62,958 49,388 3339 350 1 .904 .884 .963 0 678 -0 .217 .553 ,565 3 1089 19 .015 .582 .055 364,198 25.588 41,629 988.930 120.722 5950.000 24 2397 41 .898 .534 .680 1.643 62,588 39,811 3555 781 1 .692 ,450 .534 0 1418 -0 ,216 ,436 .694 3 2022 13 .148 .641 .503 364 27 67 .046 .635 .626 999.611 110.540 5925.000 22 2362 60 .!63 .4t7 .914 1.643 62,958 56.890 3308 428 1 .015 .735 .839 0 8O7 -0 .2O0 .126 3 1264 17 .287 .812 .319 363 23 49 .899 .811 .148 1001.868 111,343 5900.000 42 2365 63 .620 .653 .658 1.643 62,958 59,327 3503 655 1 .693 .983 .613 0 1192 -0 .229 .502 .672 3 1839 15 .429 .868 .751 363 20 62 .745 .113 .828 i000.215 107.508 5875.000 39 2354 42 .446 .762 .419 1,708 62,994 40,467 2424 380 1 .199 .636 .719 0 679 -0 ,161 ,187 .839 3 975 13 .563 .788 .252 363 25 56 .594 .385 .435 992.543 110.428 5850.000 27 2344 61 .202 .298 .713 1,643 62,994 57.599 3406 570 1 .282 .860 .733 0,206 t014,190 -0,642 3 1472 13 .704 .908 .420 363 22 55 .448 .847 .604 1008. 700 110.151 5825. 000 44.814 2347.187 67,200 1,643 61.994 62,472 3397 793 1 .821 .281 .469 0 1379 -0 .199 .948 .745 3 2176 15 .837 .864 .111 363 22 71 .300 .7O0 .606 1001.611 97.787 WG I -5 DEPT GR CAL SSD SHR RB DEV CHT TTEN SPD SFT2 HRD1 HRD2 LSN SSN CN CNC ZDEN ZCOR PE PORZ 5800.000 31,294 2338.122 48.118 1.643 63.400 45.528 3261.792 510.770 1.750 0,200 934,394 -0.660 3,971 1365.926 14.384 363.154 28.522 54.547 1000.074 112,429 2318 58 .580 .801 63.952 55.014 1.517 1394.019 -0.699 17.822 68.658 98.632 5750.000 32 2303 44 .548 .242 .384 1 63 42 .643 .988 .212 3052.709 355.652 1.886 0.178 6-66. 466 -0.645 4.243 1090. 088 18.599 362.865 23.745 46.308 1002.367 113.277 5725.000 34 2339 46 .528 .963 .408 1 62 44 .643 .994 .009 3365.397 426.536 1.802 0.218 880.633 -0.622 4.375 1346.842 19.657 362.718 24.674 51.389 1013.682 107.003 5700.000 30 2299 42 .437 .487 .726 1 63 40 .643 .958 .740 2927.601 312.824 1.997 0.231 576.361 -0.627 4 854 14 .506 .060 .965 362.574 30.028 39.600 1012.389 119.245 5675.000 30 2303 41 .772 .377 .196 1 62 39 .643 .994 .381 2801.831 267.350 2.067 0.188 513.231 -0.625 4 715 14 .644 .970 .423 362.431 35.708 35.358 1010.785 129.738 5650.000 27 2251 57 .07O .431 .540 1 63 53 .643 .988 .894 3167.525 417.619 1.784 0 841 -0 .234 .397 .664 4 1275 18 .779 .374 .473 362.288 20.437 52.500 1015.593 105. 970 5625.000 38 2308 47 .485 .174 .351 1 63 44 .643 .029 .846 2360.149 226.031 2.027 0 397 -0 .195 o215 .736 4 648 16 .907 ,452 .436 362.145 24.552 37.747 1007.071 112.137 5600.00O 35 2268 54 .257 .367 .580 1 63 51 .643 .000 .266 2338.252 224.520 1.982 0 431 -0 .174 .774 .759 5 668 17 .038 .880 .639 362 22 40 .000 .761 .504 1020.457 122.931 5575.000 46 2284 48 .880 .634 .952 1 62 46 ,643 .994 .268 2485.451 176.057 2.101 0.169 404.280 -0.679 5 603 22 .170 .484 .914 361 25 33 .861 .480 .257 1022.582 119.764 5550.000 44 2273 52 .142 .860 .339 1 63 49 .643 .994 .275 2935.822 0 375.494 626 1.93! -0 .209 .105 .650 5 945 12 .305 .054 .780 361 24 43 .721 .508 .574 1012.542 118.647 5525.000 34 2295 73 .546 .161 .OO5 1 62 67 .643 .994 .627 3251.353 0 489.825 882 1.766 -0 .205 .487 .656 5 1359 15 .434 .677 .445 361 23 53 .582 .034 .595 1020.858 110.542 5500.000 25.068 2259.717 149.859 1 62 135 .643 .994 .873 2507.969 0 482.011 900 1.470 -0 .193 .015 .915 5 1529 19 .566 .320 .833 361 12 71 .445 .574 .486 1022.392 92.668 5475.000 46 2227 48 .007 .477 .768 1.643 63.430 4-6. 104 3475.493 0 668.964 1355 1.529 -0 .204 .129 .709 5 2016 18 .698 .172 .024 361 22 67 .306 .024 .957 1027.982 106.053 545O.O0O 4O 2234 52 .405 .962 .333 1 63 49 .643 .994 .270 3131.417 357.301 1.955 0.209 683.609 -0.605 5 965 14 .828 .070 .661 361 23 42 .168 .740 .117 1019.027 113.349 5425.000 48 2239 51 .564 .568 .183 62 48 .643 .994 .249 3160.307 358.409 1.924 0 706 -0 .198 .306 .611 5 1035 16 .969 .436 .653 361 23 44 .O28 .424 .021 1014.500 113.123 W¢I-5 DEPT ~R CAL SSD SHR DEV CHT ~gc~'TTt I6L'§IOT 6/./.. ' 900 '8 88~'L68 L6T '0 000 '~EO~ Z~£ '~OI 6~9'600t ~4'49 I£0 ~09 4G~ '060Z 1A8'4 I89 "O- 6G1~'69tI ~6I '0 I~ '9~'8 E66'0§ E6~'99 ~g9 '6~Ig 000 '0~0~ 6§8'§0I AEg'~ooI gE9 '99 ~96 ' £I 6§I ~6§ '406I 6~4'4 969'0- §80'G6£I TzOE '0 6I~'E0~£ 86E'~0I ~6~'S9 £~9'I 869 000 '~40~ 996'90I 6II '~IOI OG6 '9~ 9§9'gE 68g'6~£ 69I Pg9'L 0/.§'0- 400'698 80E '0 ~LS'I 696'§I~E 886 '~9 666'9~ 09£'9~IE O00'OOI~ 068'9It 88L'0IOI 9gE 'II9 I0~'4 E89'O- E6I '0 LSO'Z ~OZ'IEE 909 ' §Z8 't~ 8~6'~9 ~9 'I ~z6I 'IgIz ~'86 1SI 'OgOI 4Eg'cIOI 0SA '0£ 088'LI g§~ '6§£ tO0'g~ ITS 'EE 089 '6GE 06Z'~I ~9~ '61 48£ '0~8 PTA '0- 480'$$$I ~Og'O ~89'0- 6I£ 'IE§ A6I '0 ZS~' 'I 8Et'~I8 A~6 'I §~8 '99g t§~ 'I9 £E0';9 ~9 'I LiO'6~ ~'66 '$9 £~,9't EgI '99 ~E'SLIg ZO§ 60£'£9 ~4~ '9Z O00'O~t~ O00'~AI~ E4~'~OI ~80 ' 800t /-£§'I9 EIB L49'~I §0§'089I E£I 'L 089'0- 8E8'09ti 60E '0 ~9'I 0~8'IE9 L99'EO~£ 044 '6~ 00~'~9 Z~9 'I 4~I '~9 OGO'ELtE IIO '6~ O00'OOg~ ~86'I~I OEg'LIOI ~9~'§~ L$6'6~[ £IS'Gt gL9'LZ§ IIO'4 409'0- EOE'I6t 8~0 '68;E I86'L£ 9~"~9 £~9 'T 0g9'6~ 8~£ '09Ig 1~£ 060 'Eli 08E 'IgOI 698 'It GLO'O9E 6gL'8I I~O'g06 ~88'9 g~9'0- §I4 'I09 ~8I'0 6~6 'l '~6t'£6E 6£O'£g6E 6~L '9~z ~66 "~9 £~9'I ~'6~"6~' 9t§'90~E 6t~ '6~ 000 'OSg§ ~§Z'8II 6£6'IIOI O~'g~ IIg'09~ ~60 '~I 886'999 ~£ '9 ESL '0- £9£'4~ ~LI "0 O§6'I I90'E§Z 666'~6E~ 66~'EG L8§'~9 £Iz9 'I E80~9~ 'C6£ '~z8Ig £96'6E I£O'§II 808'9~ L~E'095 LL6'SI ~fz '6§0I ~Z9"9 E99'0- 98~"~99 ~8I'0 848 'I 8E6 'I~ ZLL'186E §9I 9E'T~ E~9'I 99~ 90I 000'00£~ 09~'§II I9g'~gOI Z85 '09£ 409 '8I L£L'~6§ ~6~'9 ~99'0- £E~ '60~ £6t '0 9II 'Z 066'£6I ZI£ '09 ~66 ~9'I 494 '~9 §96'9EZE 006 '09 O00'§g£§ 619'9II §§9'910I 88I'££I $8~'LIOI Cj§L '9~ 619'09£ 1Z4'9£ 610'£~ 6~L '09£ 9£L"£I 69£'E£8 9§£'9 ~L '0- 969 "66§ 06I '0 £~L'O- gO8 ' 40~ 80g'O 648'I 44L O~I 866'E9EE 886'~9 £~9'I 90~'~§ 000 I6£ '9S OOS'6EEZ 66~ 9§~'6§ IEL"LE 000'0§£§ 000'~4£~ GS~'OOI §48'89 t~9'8I £68'09£ ~9I '9I 89I '96LI 860'9 £84'0- 9LI 'IgIt L8I '0 ~I~'I 904 'I~9 8£9'L40£ 8g0'99 8~§'£9 £~9"I $Og 'tL 000'00~ ZEOE :EcI EOOZ M~tQZ OMD MD ~'~ 8~0'600t 86~'~ O§I '/.,§~ 1:E6'£[~'I: 8~'/.,°6 ~§9'0- ~/. '~6 aS']: ' 0 8L6'98~ ~8'0£ [66'~9 ~99't 0~9 '9£ 86G 'G90E ~9£ '9§ 000 9§9 '6EI ~68 ' EIOt O£~'LGE EI£'LI OLI '919 0[9 '6 669 '0- 0~6'C8£ 80E'O ~£8 '9E~E L99'~ ~66'~9 [1~9't 665 'Z~OZ £~t '9§ 000'00£1;' 9E['~II 69I '£00t 969'I£ G6£ 'EE /-6£'£§£ ~9I '£I 0t§'6 019'0- ~IL';~ ~6I '0 LEI '~ OBi'OgLE 66G"L~ E66'§9 ~9 't It['§9 000'~£~ ~09'~II I69'LOOI E9L '6I ~8t '~8~ 68£ '6 OIL 'O- [IZ'O ~E~'690~ '09 O00'O~L~ 8§E 'OEt 6E~'L66 99§'L£ 669'0£ ZL['9I 88I '~L ~9E'6 L~9 '0- O~O'Z Z~6'6§E 99I'09LE 9gg'/.~z 00~ ' ~9 £~9'I 0£0'0~ L60'E90E LLS'~[ O00'~LL~ 8LO'LOI L90 'IIOI 9LI '8I 69L'L§[ 698'Pt t1~6 'OG8 ~£I '6 0t9'0- ~9~'99~ 6Ig'O LIO'E I~L 'Et[ 960'[L6E 86§ 660'~£ ~I£ '9£ 000 *008~' §9§'60I 9~8'[t0I 98£'~ O08'OE 988'/.GC 09L '8t I98 '~80I fzIO '6 IE9'0- [80'899 I6I '0 I06 't 0E0'660~ a6~'~L ~'66 '~9 ~1~9'I ~8~ 'eL 6;~"8S0g 9S~ '09 O00';ZS~ 8~t '80I 9£9'L66 ~OI '0§ 6c3~ '9~ 910'8~[ 69I'St E~O'99EI §88'8 099'0- ~£'898 8£L 899 'I~ 00~ OE8 '90tE GEL '9tz 000'0~8~ ~6E'80I 600'LOOI [96'gg 86E'EE L88 '8I I9L'8 £L9'0- 0~8'006 86I '0 LEL'I §6E'OL~z 89I '9§ LS~ '~9 IOI '09 O00'~LS~ E6I"60t ~69'8t0I 008'~ 800'F,E L9E'8§£ IgI '9§6 6E9 '8 L69'O- CSE'6L§ E6I'O ~'68 't L~" L6E 660 '89Ag ~66'~9 '89 '80tg '9~ 000 '006~ G68 '86 6C9'CIOI ~L'69 ~LL'OE 68['8§C O~9'GI 60G'8 [IL '0- 810 ~OE"O 669'I 0~9'6~A LO£'tL 0£~'~9 £~9't O.§t'LL 000 ~OI'IOI 9Lt'9IOt ~6£ 'L9 §L~ '6I LI~'8~£ I86'816I 8L['8 LtL'O- I8£ 'gEct 66t '0 OEO'~£L §6I'90~E 660'9§ 00~'~9 £~9'I EEO '09 000 '0§6~ EE9'~zOI §O~'g9 9I[ '6t Z~9 '8~£ L§9'EI ~8E'LLLI £~'8 999'0- 8LE'§~EI EtE'O oEg'I ~O~'L~ EEO'§9 £~9'I E:6~ 'I9 E88'~EtZ O00'SL6~ 6LG'[Ot 8~§'600I [IL '9L 6I§'GI ~'LL O§L '~I LEG ICI '8 69L '0- 98~'LI9t 80E'O ~8E't 8EL ' 006 98£ '~E 689'L8 ~66 '~9 £~9'I 86~; '$6 960'8Et~ 88L"EE 000'000§ ZEOct EODZ O~IO ~D ~SHD A~tG %ID ~ - i OM 8LE'85 OEE'gl 609'0- LIO'E §~O'EIt 6§~z'£E ~06'~§8 EOI'Lg~ EOt'O0~ 9[0'6§ 98E'EIOI 86['§~E 919'II 6[~'0 ~O0'6L6E ~I~9'I £86 ' E9 lOt '9~6t 000 6LI'~ L[L'§t ~£9'0- ~06'I EL['09 80§'90I 819'IE 6£g'gIOI LG6'~tL Egg'Igg 000 968'£IOi LE§'§§g 86Z'It 86t'0 9~S'GLO[ 09§'L96I O00'O§g~ E£~'tS ££9'§I 9~9'0- 66£'I ~80'0~ E9§'III £08'EE 89§'9§EI ~OL'§E8 ~8i'655 OEO'6§ ~6~'OEOI £§9'~§[ ELI'II E6I'O ~E~'SLI~ ~9't 8~E'~.~ ~09'gL6I gL~ 'SE £I~'~I~ 695'~t It9'0- OE6'I 88F,'E§ 6I~'OII EOt'~Z EO~'l~90I 69T7'069 L'9~'~8~ 00~'6~ OIO'LIOI 98L'§~[ 990'11 §OE'O 089'891~ £~9'I t~L'~ E96 '8G6t 9a9 '6a 000 '00~ GO~'E9 [~'~I 909'0- ~6'I E~8'L~ 9~L'O§ LEg' LII £§9'£E I08'~86 ~LE'~L9 ELS'g§[ 886'8G IEo'gIot f716'~£ ~g6'OI ~LI'O 9E9'8£I£ ~9"I [LO'E~ ~['§I ~6~'0- 9S6'I 06§'G~ EaO'§II 9[L'~E 899'0~0t ~60'~9 t8~'EL~ ~66'ff 809'E~0I £§0'9§~ §6L'OI 98t'0 £LL'68t~ ~9'I 88t 066'966I 000 "0~'~' 8~E'~tI 80~'GE 6~E'99A E09'6§§ ES£'E§E 9§E'ItOI £6t '9~g 8~9'0I 90E'O IgE'80~E L~9 '~L6I 1.61.. 'g~ 000'~£~ ~L'O§ 600'~I gI9'O- [IS'I g~g'gG 9E§'09 g9~'90I £OL'IE g~E'09[I ~E0'£98 L99'L69 E66'~9 ~89'~786I IOI'8IOI 9I~. '9§£ §~§'OI 6EE'O tO~'IO~g ~9't ~zE6'8g 000"00§9 6~8'~ 68i'9I 9£9'0- ~L't 6E~'L~ 1~[9°t9 O~L'EOI OOL'LI 0E9'6~9I £LL'~OOt ~E6'~§ ~66'§9 0E['~66I ~O0'£IOI I~'9~ 8~'0I tO~'O II6'9t~ ~fz9'I 000 8IL'ES [ES' LI I~9'0- 08L't 9tg'g9 90L'EOI I60'6I I6E'99~,I OLI'SL8 9~E'09~ 6E0'99 ~LE'~'tOI L§§'9§£ LE['OI ~OE'O 6179'~0£~ gI6'99 I99'810~ 8IE'09 000'0§~;~ IL['§§ g96'~I 9E9'0- 5[£'I ~£I'8~ 866'90I L69'EE £LL'IE§t §ZL'~OI ££8'LG§ g66'G9 ~99'EEOI 699'9§~ GEE'OI 80E'O [~§'90~ £1z9'I ~0 'tS 68t 000'~4~ £0£'£§ I89'GI Ct9'O- OLL'I LSE'~G 99t'60I 6~0'9E L6I'GOGI g8~'E£6 9L§'I~S £66'§9 E§0'gtoI L64'9§[ §OI'OI ~Ig'O 8§G'~6~£ C~9't E86'LS 896'§EOE 616'~ 000 ' 009~ ZRO8 aa § - I Db~ 919'0G 9E6'9I £~9'0- §IS't 60~'0~ 818'~0I OE['tE I££'84Zt IgI'Lg8 008'8~ L8§'S9 899'CIOE IEE'800I EI6'gG5 986 '6 IOE'O 6£9'~£E[ £99't 9~9'9E 000'~99 ~I£'9~ 66~'8t 609'0- 988't 80~'[G 919'80I ~I~'~J OE6'I~It OEO'~SL 060'L9C £66'~9 §OI'L~ 60.203 ~259 1.963 -0.624 16.731 41.637 4275.000 50.834 1.643 2517.568 0.185 11.656 355.143 1016.967 1952.927 59.994 184.929 360.714 611.980 26.335 121.527 47.914 45.347 2.138 -0.657 21.453 31.000 4250.000 45.461 1.643 2861.301 0.168 11.779 355.017 1010.772 1924.299 59.994 276,019 544.666 821.918 27.255 116.287 51.447 48.483 2.009 -0.635 17.624 38.844 4225.000 43.195 1.643 2437.565 0.188 11.894 354.895 1014.427 1925.451 59.988 210.770 367.761 542.331 27.762 127.431 48.458 45.829 2.157 -0.668 13.349 29.874 WGI-5 DEPT GR CAL SMD SMR RB DEV CHT TTEN SPD SFT2 HRD1 HRD2 LSN SSN CN CNC ZDEN ZCOR PE PORZ 4200.000 49 1901 5O .762 .975 .152 !.643 2425.040 0.201 12. 018 59.400 193,048 358.8!2 554.441 47.334 2.150 -0.674 16.470 354.767 1013.753 23.264 119.265 30. 310 4175.000 36 1923 46 .212 .006 .904 1. 643 3042. 914 0. 240 12. 134 354. 642 1013. 350 60.594 347.131 635.792 968.148 26.734 115.486 44.449 1.949 -0.623 15.584 42.501 4150.000 43 1867 6O .592 .695 .697 1.643 3010.332 61.552 308.031 56.697 1.907 0 68O -0 .208 12.251 354.523 1022.999 .446 995.884 21.372 111.168 .645 20.541 45.022 4125.000 27.530 1891.988 66.267 1.643 3140.378 60.400 515.690 61.644 1.715 0 915 -0 .206 12.374 354.397 1010.847 .961 1386. 152 20. 361 109. 972 ,695 14.526 56.685 4100.000 32 1881 65 .280 .429 .634 1.643 3239.861 60.994 353.834 61.081 1.968 0 659 -0 .228 .387 .580 12 1029 16 .491 354.270 1024.684 .802 23.455 110.601 .886 41.306 4075.000 4050.000 32 1869 66 31 1853 51 .311 1.643 3392.851 0.212 . 376 60. 994 558.720 965. 206 .642 61.977 1.743 -0.641 .094 1.643 2736.686 0.207 .089 60.994 307.513 567.921 . 762 48. 763 1.947 -0.683 12.606 354.153 1011.244 1475.170 20.204 106.171 14.034 54.987 12.724 838.714 14.937 354.029 1008.828 27.263 118.650 42.588 4025.000 31 1879 60 .051 .056 .603 1.643 3410.050 60.994 502.723 58.614 1.791 0 930 -0 .197 .039 .619 12 1369 14 .840 353.906 1018.889 .620 20.083 102.928 .905 52.071 4000.000 32 1844 5! .066 .169 .721 1.643 2371.937 60.994 215.854 48.727 2.035 0 395 -0 .181 .505 .731 12 645 17 .960 353.782 1020.779 .697 26.091 127.269 .774 37.280 3975.000 36.041 1.643 2889.218 0 1845.783 60.958 337.223 683 50.120 47.305 1.902 -0 .203 .233 .670 13 920 14 .074 353.665 1025.213 .837 24.712 113.413 .970 45.360 3950.000 43.958 1.643 2934.458 0. 210 13. 183 353. 543 1027. 197 080'8II ~C0£'9~ 3/..E'88~ §9/.'£0~ 04~'8IE T~66'I9 ~O~'OEOI 988'1::~3£ /.,OL'~'l: /,/.,1:: '0 Z,£~'£~E: £~9'1: 6t~'~:~ O00'O09E IEt'9~ 60E'Gt I69'0- 688'I 6~'6G £L£'~9 9£0'~0I IZE'6I EEa'E~6 £88'~9 6IO'I~ £E9'I9 9£0'~£0I ~O0'a~ £6~'~t ~6t'0 £t9'II~ E~g'I £0£'~ 99§'§9 t££'9I 9£9'0- 89g'I §?O'IOI 8t8'6I 796'866t 090'O~TI E89' £9L 966'09 E§t'g~OI OZI 'Eg£ §8~'~I ~IE'O 66~'~£ 60I'G~ 000 '0~9£ ~8E'99 [~I' 4t 8t£'0~ ~§G'I §~9'~9 60~'89 9£['EOI GOO'IE 6§O'Ei6I 84Z'80ZI 6A~'t§9 ~66'09 8£§'89LI 8~'E~OI C~EE*EcJ£ §4~'~I ~IE'O 4~"I9~E ~Iz9't ~EI'I~ 000'S49~ L§9'~9 988'~I £89'0- £8g't ~At'89 GS~'OOI £O0'OE 6~E'0§8I 88§'LI£I £6g'6£9 0~0't9 £§£'§~0I £§E'E§E 8~E'~I .I6I'O 9~['60~£ 804't tEg'£L 08§ '98AI 08~'f~ 000 '004£ ~87'8~ 89t' £I £G9'0- ~89'I 69~'EOI E~8'6I 96E'E99I 89E'EtOt ~t'99§ ~66'09 00~'68£I E89'0~ 000'~4~ E§L'E9 ZOL'EI £89'0- ~19't S0/.'0£ ~££'§0I 676'AI IEE'f~4I ~8'69tI ~6E'E£9 8§~'09 9E6'8£0I 96§'Z§~ tZO'~t ~IE'O [E8"90~£ ~9'I 14~'9L ~§L'444I 66~'§[ 000"0~ 000'~9 98§'9I I69'0- ~6~'t E~6'09 ~L6'£0I EtL'OE E~6'~ISt 6L6'ZEEt £8G'6E9 ~66"09 £~L'SEOI ~I£'E§E 8t6'~I £OE'O 99E'~E ~9'I 69£"46LI 66~'L~ O00'~£L~ 9EL'09 ~8~'80I ~0£'8I E~L' LOLt 8II'86II GOS'SG9 ~66"09 I09'G~SI.. ~I8'£I OI~"O E84'9I~£ ~9't 9~ 000'008£ Z~IOJ AE~ ~ - I Dr4 E£~'POI I~§'SI I94'IIEE I~'~91~I 098"9G£ ~66'09 891 ' 4£0I ~6'E~ £t4'£t 66I'0 484'~ £~9'i ~?~ '6L 618"0~81 8~9'0~ 000'~8~: ~89'8/. E80'Gi 808'0- ~§£'t 90~'I8 EE~'88 LLE"IOI G~I'9I 6I~'~6£E IS~'IIgI 88~'~48 9~'I9 ~I'I~SI 914'4[0I I90'£§~ I09'[I 68I'0 ~49'68~ E~9"I ~E~'.8~ 000'0~8£ 60~'~9 960'SI ?L9'O- E09't 199'~§ ~0~'8S 9tE'£OI gtI'Ig 06£'498t EO9'§ggI 6LE'999 ~66'09 OLO'O§SI L~'~£OI 8LI'E§E §6~'~I LOE'O ~6£'~I~ £~9'I E6~'EOI ~06'9I 9~8' 48EI ~tE'6E6 LSL'09~ 00~'09 §II'6£8I 6E~'~ZOI ~O£"E~ ~6E'~I tOE'O ILE'OSE£ E~9'I 6~§"9~ O00'~LS~ 000'006~ 4~6'E~ 419'~I IIg'o- g~6't 8I~'0~ LgI'90I 09§'EE 9£0'~00I G~9'699 ~["EL£ 88~'I9 000'~6~ 3575.000 46.461 1.643 2438.939 0.197 1752 . 408 62 . 000 270.77.1 480. 668 53.014 49.876 1.977 -0.737 355O.OOO 36.125 !.643 2597.314 0.201 1751.202 61.588 274.956 577.822 55.069 51.700 1.903 -0,730 3525.000 33.675 1.643 2890.015 0.200 1741.945 62.394 307.859 616.905 66. 731 62.056 1. 898 -0. 672 3500.000 27. 640 1.643 2754. 495 0. 196 1739.548 62.000 441,622 858.612 58. 409 54.666 1. 666 -0. 787 3475.000 15.474 1.643 2790.782 0.158 1731.667 61.030 263.003 510.094 135.538 123.156 2,002 -0.651 3450.000 25. 552 6. 000 0.000 0.000 1500. 000 0. 000 0 . 000 0. 000 108.432 105.847 2.000 -0. 100 3448.000 -999. 250 -999. 250 -999. 250 -999. 250 -999. 250 -999. 250 -999. 250 -999. 250 -999. 250 -999.250 -999. 250 -999. 250 End of execution: Tue Elapsed execution time = SYSTEM RETUP~N CODE = 0 6 MAR 90 4:07pm 1 minute , 14.2 seconds. 14.812 688.064 13.025 14.926 823.211 17.803 15.028 996.701 20.593 15.144 1230.429 15.554 15.251 826. 807 19.497 0.000 0.000 0.000 -999.250 -999.250 -999.250 351.770 27.425 40.817 351.656 24.903 45.295 351.547 22.461 45.602 351.433 23.805 59.640 351.322 14.045 39.258 0.000 16.443 0.000 -999.250 -999.250 -999.250 1029.701 124.638 1029.551 120.618 1024.225 120.275 1023.809 111.763 1022.661 94.857 300.000 109.155 -999.250 -999.250