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191-119
Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. t (~ ]~' l l q File Number of Well History File PAGES TO DELETE RESCAN Color items- Pages: ,.~' '~ r~ Grayscale, halftones, pictures, graphs, charts - Pages: Poor Quality Original - Pages: Other - Pages: DIGITAL DATA OVERS[ZED Diskettes, No. Other, No/Type Logs of various kinds Other Complete COMMENTS: Scanned by: ianna Vincent Nathan Lowell TO RE-SCAN Notes: Re-Scanned by: Bevedy Dlanna Vincent t~owell Date: ~"~'~'~ /si ~ PLUGGi~iG & ? ,0 ~AT ! ON CLEAL~~, _WCE REPORT State cf A!ask~ Rev" aw ~e well fi!a, ~d c u~~, well haa~ ,, V Well hear c".x'c c:~-~: · . · · . · · . · STATE OF ALASKA ALASKA elL'AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Plugged Back for Sidetrack ,, 1. Status of Well Classification of Service Well [~ Oil F1 Gas F1 Suspended !~ Abandoned [:] Service , 2. Name of Operator 7. Permit Number BP Exploration (Alaska) inc. 191-119 91-277 & 301-206 3. Ad'dress .................. 8. APl Number .................. P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21148-01 ............ :.~ ~" '. ............. ," 9. Unit ~r Lease Name ......... ~. Location of well at SUrface 2204' SNL, 712' EWL, SEC. 35, T12N, R12E, UM !i At top of productive interval ';~'! ~ ~i Prudhoe Bay Unit 2257' SNL, 1862' WEL, SEC. 34, T12N R12E, UM -! '~ '!i 10. Well Number At total depth '? ~.~ S-17A 2024' SNL, 1975' WEL, SEC. 34, T12N, R12E' UM '~~~ '~'1. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field / Prudhoe Bay Pool KBE - 67.47' ADL 028258 12. Date09t21/1Spudded991 il 3. Date1011T'D'0/1991Reached 114. Date Comp.,2/8/2002Susp., or Aband. 15. Water depth, if offshoreN/A MSL 16. No. of ZeroC°mpleti°ns 17' T°tal DePth (MD+TVD)i 18' Ptug Back Depth (MD+TVD)10060 9201 FT 9450 8728 FTII 19' Directi°nal Survey 120' Depth where SSSV setl 21' ThicknesS °f Permafr°Str"l Yes I~ No N/A MD, 1900' (Approx.) 22. TYpe Electric or Other LOgs Run ' MWD, GR, 23. CASING, LINER AND CEMENTING RECORD , CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BoTToM SIZE CEMENTING RECORD AMOUNT PULLED 20" x,30" Insulated Conductor Surface 11,0' 36" 8 cu yds Co,ncrete ..... 13-3/8" 72# L-80 Su~ace 2663' 17-1/2" 3255 cuff AS II1., 465 cu ~t AS II ...... 9-5/8" 47,# , L-80 , ,,Surface, 8300' 12-1/4", 1,,935, cu ft"dlass,'G', ,279,,cu ft A,,S..,II" , ....... 7" 26# NT13Cr-80 8035' 10060' 8-1/2" 451 cu fl Class 'G' , ,, , , ,, ,, , , , ,, ,, , , , ,, ,, ,, ,, ,,, ,, ,,, , ....... , ........ , , , , ,.. ~ , ~ .. ~ ~ ~ ~ , .,,,~ ~ . ,, ,, .,,., , , . ,, , .... ,,, , ..... 24. Perforations open to Production (MD+T~/D of Top and ' ~5. ' TUBING RECORD ......... Bottom and interval, size and number) ..... SIZE DEPTH SET (MI~) " PACKER SET (MD) ' None 4-1)2'', 12.6#, NTI:~CrS0 ' 8084' ' 80'0'2' ......... MD 'I'VD MD TVD '"26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. .... .. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Driginal Peds were Sqzd, but not abandoned, 1995 9445' Set Whipstock , 9450' P&A with 26.5 Bbls Class 'G' , 27. PRODUCTION TEST , DateNotFirSton Pr°ducti°nproduction IMeth°dN/A°f OperatiOn (Flowing, gas li~t, etc.) Date of Test Hours Tested, TEsTPRODUCT1ONpERIOD FOR O1L-BBL GAS-MCF WATER-BBL CHOKE S,ZE I GAS-O,L RATIo 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 liihology, porosity, fractures, apparent dips 'and presence of oil, gas or water. Submit core chips. ' ........ ,,:.-.,- i 9' 20111) No core samples were taken. Anchoraae Form 10-407 Rev. 07-01-80 Submit In Duplicate , Marker Name ,~.. ,~,, .~, ,. Sag River Shublik ivishak Geologic Markers ,, , Measured Depth , , · ,.1, i,, , i i , 9482' 9531' 9652' True Vertical Depth · 11111 , ~rllll ,, i,i · iiii i i, 8753' 8791' 8886' 30. Formation Tests Include interval tested, Pressure data, all fluids recovered and graviht. GOR, and time of each phase. ,, , ,,,, , ,, ,, ,-, ,, , ........ ,,, , ,,, , , , , ,, , ,, ,,,,,, , ,, ,, 31' List of AttaChments: ...... summary,of ~pa~l;0n~,e~.op~.ati0n. s. ,,. .................... - ..................... 32. l'~ere'l~Y' certify. tha{ ihe fo;'eg'oi'ng'is t'r'ue ~,d"cor;ect 'io th"e best ~f' m~ knowledge ................................. Signed TerrieHubble ~ ~ T,tle Techn,¢alAss,stant Date S-17A 191-119 91-277 & 301-206 Prepared By Name/Number: Terrie Hubble, 564-4628 .. Well Numbe,,r , ,Perm!! N0. t A, pp, r, oval ,Nor .............................. 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 cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Well: S-17C Rig Accept: 02/14/02 Field' Prudhoe Bay Unite Rig Spud: 02/16/02 APl' 50-029-21148-03 Rig Release' 03/02/02 Permit: 202-007 ...... Drillinc.:.:j Ricj: , , Nabors 3S PRE-RIG WORK 01/20/02 DRIFT TUBING W/3.625 DUMMY WHIPSTOCK. 01121/02 DRIFT TUBING W/3.65" DUMMY WHIPSTOCK TO 9435' WLM. LEFT WELL SHUT IN. 01/27/02 MITIA PASSED TO 3000 PSI. 02/07102 PRESSURE TEST SURFACE EQUIPMENT. PERFORM WEEKLY BOP TEST. MU AND RIH WITH PDS MEMORY GR/CCL. 02/08/02 RIH WITH MEMORY LOG TO 9410' CTMD. FLAG PIPE. POH AND LOG TO 7850'. FLAG PIPE. POH. VERIFY DATA. GOOD. MU AND RIH WITH 2 7/8" MOTOR, JARS AND 3.80" MILL. RIH. CORRECT AT FLAG, TAG OPEN HOLE KICKOFF TOOL AT 9467' (DN), 9462' (UP). POH. PU 3" COMBO NOZZLE. RIH. COOL DOWN @ 9000' WHILE MIXING CEMENT. INJECTIVITY: 0.8 BPM AT 180 PSI. LAY IN 26.5 BBLS 17 PPG CEMENT FROM 9460' TO 9138'. LOST 14 BBLS TO OH WHILE LAYING IN. PULL TO SAFETY AND HESITATE SQUEEZE. UNABLE TO MAINTAIN WHP ABOVE 250 PSI. CEMENT TOP AT APPROXIMATELY 9350'. POH. DID NOT CIRCULATE OUT DUE TO LOW SQUEEZE PRESSURE. FREEZE PROTECT COIL AND PRODUCTION TUBING WITH MEOH. RDMO. NOTIFY PAD OPERATOR THAT WELL IS TO BE LEFT SI. 02/10/02 DRIFT W/3.25 CENT & SAMPLE BAILER. TAG CEMENT @ 9253' WLM (9284' CORRECTED). SAMPLE OF CEMENT. PRESSURE TUBING TO 1000# PSI TO TEST CEMENT. MONITOR FOR 30 MIN. GOOD TEST. RDMO. LEFT WELL SHUT IN. NOTIFIED PAD OPER. STATE OF ALASKA ALASK~L AND GAS CONSERVATION COMSION APPLICATION FOR SUNDRY APPROVAL ~~~~~ 1. Type of Request: ®Abandon ^ Suspend ®Plugging ^ Time Extension ^ Pertorate ^ Alter Casing ^ Repair Well ^ Pull Tubing ^ Variance ®Other ^ Change Approved Program ^ Operation Shutdown ^ Re-Enter Suspended Well ^ Stimulate Plug Back for Sidetrack 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. ®Development KBE = 67.47' ^ Exploratory 7. Unit or Property Name 3. Address ^ Stratigraphic Prudhoe Bay Unit P O Box 196612 Anchorage Alaska 99519-6612 ^ Service . . , , 8. Well Number 4. Location of well at surtace S-17A 2204' SNL, 712' EWL, SEC. 35, T12N, R12E, UM 9. Permit Number At top of productive interval 191-119 2257' SNL, 1862' WEL, SEC. 34, T12N, R12E, UM 10. API Number At effective depth 50- 029-21 1 48-01 ' ' 2371 SNL, 1810 WEL, SEC. 34, T12N, R12E, UM 11. Field and Pool At total depth Prudhoe Bay Field / Prudhoe 2024' SNL, 1975' WEL, SEC. 34, T12N, R12E, UM Bay Pool 12. Present well condition summary Total depth: measured 10060 feet Plugs (measured) Whipstock /Window for S-17AL1 at 9450' (02/95) true vertical 9201 feet Cement Squ eezed below Whipstock (07/95) Effective depth: measured 9450 feet Junk (measured) true vertical 8728 feet Casing Length Size Cemented MD TVD Structural Conductor 110' 20" x 30" 8 cu yds Concrete 110' 110' surtace 2634' 13-3/8" 4000 cu ft Arctic Set III & II 2663' 2663' Intermediate 8274' 9-5/8" 2214 cu ft Class'G' 8300' 7761' Production Liner 2015' 7" 450 cu ft Class 'G' 8035' - 10060' 7530' - 9201' R~~~~~~~ Perforation depth: measured None -Squeezed JUL 1 8 2001 true vertical None Alaska ail & Gas Cons Commi i Tubing (size, grade, and measured depth) 4-1/2", 12.6#, NT13Cr80 to 8084' . ss on Anchorage Packers and SSSV (type and measured depth) 9-5/8" Otis 'HVT' packer at 8002'; 4-1/2" Camco SSSV LN at 2111' 13. Attachments ®Description Summary of Proposal ^ Detailed Operations Program ^ BOP Sketch 14. Estimated date for commencing operation 15. Status of well classifications as: July 20, 2001 ®Oil ^ Gas ^ Suspended 16. If proposal was verbally approved Service Name of approver Date Approved Contact Engineer Name/Number.• Thomas McCarty, 564-5697 Prepared By Name/Numbar Terrie Hubble, 564-4628 17. I hereby.-c-erti~that the for~e~gcoin is true and correct to the best of my knowledge Signed CT D illi E /°"'~ ~ Titl ~ ~ j ~ B D t ~ / ~ ~/ r ng ngineer e Tnoma s Mcca y e a Commisstort lJs+a Only Conditions of Approval: Notify Commission so representative may witness Approval No. ~ ~ ~ ~0 Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10-~ A roved b order of the Commission -ORIt3iFlAL SIGNED SY Commissioner Date /~ Form 10-403 Rev. 06/15/88 ~- ~ r ~ F Submit~fn ~plic'ate ~ f~ /~ by • • .-,•,;. :Z: :~i i~~•~;,~ July 16, 2001 BP Exploration Alaska Inc. Drilling & Wells To: Alaska Oil & Gas Conservation Commission Coiled Tubing Drilling Team 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Tom Maunder Petroleum Engineer Subject: Well S-17a CTD Sidetrack Prep Well S-17AL1 is scheduled for a through tubing sidetrack drilled with coiled tubing. S-17A will also be abandoned as part of this operation. The following summarizes the procedure required to prep S-17A/S-17AL1 for drilling and is submitted as an attachment to Form 10-403. A schematic diagram of this proposed completion is attached. 1. Operations will pressure test the tree, wing & master valves. 2. Slickline will drift the tubing and dummy off the gas lift mandrels. 3. Operations will liquid pack the IA and pressure test. 4. Eline will cut the 2-/7/8" liner at approx. 9525'. Prep work is expected to commence July 20. Coil tubing drilling operations, as detailed below will commence July ~,6', 2001. Z? 1. N3S will pull the upper section of 2-7/8" liner. 2. An open hole kick-off plug will be set at approx. 9475'. (If the entire liner is successfully pulled the well plan will be revised as a toe drill out to the same target.) 3. A 3-3/a" sidetrack, approximately 1900' long will be drilled out of the open hole into Zone 4. 4. The sidetrack will be completed with a 2-7/8" x 3-1/2", solid, cemented & perforated liner. Thomas McCarty CT Drilling Engineer Tel : 564-5697 Fax: 564-5510 CeII: 240-8065 mccarttmQbp.com Well File Petrotechnical Data Center Terrie Hubble TREE = 4" CNV McEVOY BAKER KE3. tltV = b /.5' BF. ELEV = 38.83' _ KOP = .~..~.~.._.,, ,,_,,,..~.__.~. 2700 Max Angle - `".. 93 @ 9757 _...-- Datum MD 10104 Datum ND= 8800' SS S-17B ~OPOSED CTD SIDET~CK 2111' 4-1/2" CAMCO SSSV NIP, ~ = 3.813" GAS LET MANDRELS 13-3/8" CSG, 72#, L-80, ID = 12.347" ~-~ 2663' 'TOP OF 7" 13CR LNR H 8035' Top of Proposed 3-1/2" Liner 804 4-1/2" TBG, 12.6#, 13CR, 0.0152 bpf, ~ = 3.958" ~ $~ 083' ~- 9-5/8" CSG, 47#, L-80, ~ = 8.681" 8300' 1st Welled Window section 8300' - 8380 2nd W~Iled Window off Mech Whipstock ~-~ 9450' - 9456' 9445' TOP OF WHIPSTOCk PERFORATION SUMMARY REF LOG: Radius Log 7/26/1995 ANGLE AT TOP PERF: 88 @ 9916' Note: Refer to Production DB for historical oerf data SQE SPF INTERVAL Opn/Sqz DATE 1-9/16" 4 9916 - 9936 O 08/05/95 1-9116" 4 10030 - 10050 O 08/05/95 1-9/16" 4 10170 - 10190 O 08/05/95 PBTD 9981' 7" LNR 26#, NT80S,13CR, 0.0383 bpf, ~ = 6.276" 10060' ST MD ND DEV TYPE VLV LATCH SQE DATE 5 3062 2993 9 OTIS RA 4 5254 4974 29 OTIS RA 3 7181 6688 24 OTIS RA 2 7895 7339 27 OTIS RA 1 7961 7398 28 OTIS RA 7989' J~4-1/2" PARKER SWS NIPPLE, ID = 3.813" 8002' OTIS BATCH LATCH 8002' 9-5/8" OTIS HVT PKR, ID = 3.880" 8052' H 4-1 /2" X NIPPLE, ID = 3.813" 8071' ~4-1/2" XN NIPPLE Welled out, ~ = 3.800" 8084' 4-1/2" W/LEG 8078' ELMD LOGGED 10/19/91 2-7/8" LNR, 6.16#, ST-L, .00579 bpf, ~=2.441" ~ 10196' 9475' Mill Window off Mech Whipstock in Open Hole 9525' Existing 2-7/8" Liner Cut & Pulled f/ 3-3/4" OH 9535' -~3-1/2" x 2-7/S" x0 Proposed 2-7/8" L-80 Liner -Cemented & Perf'd 11375' GATE REV BY COMMENTS DATE REV BY COMMENTS 08/20/84 HF ORIGINAL COMPLETION 07/18/01 pcr S-176 Proposed Sidetrack 10/19/91 PAB CTD SIDETRACK COMPL. 07/29/95 JAM 2ND CTD SIDETRACK 03/15/01 SIS-MD FINAL 07!07/01 RWtlh CORRECTIONS PRUDHOE BAY UNR WELL: S-176 Proposed PERMfT No: 95-048 API No: 50-029-21148-01 Sec. 35, T12N, T12E BP 6cploration (Alas fl t ~7~.~-7/o i ; ,. ~G - 2C~, l U 4b3 C ~ c d1,~,~ re-~~,fi f ~~r i f p P~_ /~ s- 17.61 a. h~+ ~»~ t,~,f...P -i'I-~tt t,~c~- ~,v~i cc(,l,Cc~ u,}aq ~crl' ~~ u~ -N-~,; ~ u '40 ~- (~~r cU~c.~.cm c,~l ~fi-~.~-e-~ l'i'~c mcr..r..~ vJ 5 -_i ~,'~ Cozekct r~ ~- !tee- ~~P ~C wcLCt.,~.~ (-1`t~~ r 1 ~ - l~ ~ L1- -ex1n~ - abar~E'vt1eE ~~-~!Cx.-e-t2~ Lcvi'e.,r~ ~cti~~ ~n-~d't,~c~ti C~1'~ is ) ~~nk~~ ~ -l'he~ ~-tic~le.1~'C~-c:lz-- -~- a~cci-t,cn,~i`r~ a~r~~ ~prt~ ate.; c~#- -~-~~,~ f irn~ ~fi~ ~F _ fJ- ~-rt,~~C. t~~.~.#-- l o -4 U3 , 5-176 Rush Perms & Sundry • Subject: S-178 Rush Permit & Sundry Date: Fri, 20 Jul 2001 11:02:55 -0500 From: "McCarty, Thomas M" <McCartTM~BP.com> To: "Tom Maunder (E-mail)" <Tom_maunder@admin.state.ak.us> CC: "Johnson, Mark O" <JohnsoMOt~BP.com>, "Stanley, Mark J (ANC)" <StanleMJ~BP.cam> Tom: Thanks for your efforts on this well so far. S-176 Permit and Sundry need to be rushed for two main reasons: 1) S-20A has gone excellent S-20A finished 5days ahead of schedule and MPI-04A /L1 was completed 9days ahead of schedule. As a result, Nabors 3S is now 14days ahead of the original schedule. 2) The Kuparuk river Bridge construction is ongoing and stilt has some unknowns which could possibly impede N3S from crossing. Originally we planned on crossing the Bridge on Aug. 3rd, but with uncertainty in the Cement curing and grouting this could be pushed back to Aug. 8th. The expectation was #ha# sidetracking MP 104 and S-20, perforating S-08, and one week of Rig maintenance would carry us until the Kuparak river bridge was passable and construction of the bridge complete. In order to avoid having Nabors3S go on Standby we decided to try and expedite the sidetrack of S-17t_1. The Permits and Sundrys for the wells across the bridge have been submitted already. 1 appreciate your help, if you have any questions or concerns please feel free to give me a call. I apologize far the change in schedule and hope we can minimize these in the future. Thank You, fie-` ~~}'~ GcCJ ~~,~~~ a~ a S~~~S <30.~_ acs ~ ~ a ~ ~ Thomas McCarty Colt Tubing Driving Engineer ~-~ 5 - ~`~ 1~ ~ - 1~11~1-- ~ . ~ ~~cGSL ~-~~'~ ~ ~ Alaska Driving & wells ~o.~.S , ~',x G eGCS -it ~...~ ~ ~'` \ - ~'~ p,~--1 ;S Office: 907-564-5697 u ~c*c-~c.~ ~ Q cev: 907-240-so65 0 ¢. ~ ~ n~~~~~~ , ~s~- cZ c-cJ\v.-~ s o~ Q~~\e.w~S ~.~\~ ck~~` ~~ Pcec.r9ccS' ~~eP~~ `°~S ~\c~n~ . Rjp ~\sfl ~Cs~ n~\~ ~~ \r ~l~fc ~'~ \~, ~~c Pc~~t~w©c-~.. ~ ~ V Q ~ ~ _ 5 '~~ ~~~~ lX~-t's~~ ~~~ o h ~ ~~t\\ ~J~c vJ r[ ~S~o~~ G ~ l~~C ~~ ~\~ G~~n`c~`~_ S~r~- 4`r s~c~~-Irk ~ ~ \~~e c- ~~ww~-~ ~1r~~ .b, S~r~~ tsh-\ '~~~~~~J . 1 of 1 ~~~c~ ~\ ~ 5 gc.~~~ ~~ ©~ J~t~~S2 ~~ C~~ ~~.J u"~~ ~\ S~~~ \ ~ /~ 7/20101 8:05 AM 07/2U/2001 08:23 PAX. 907 564 5510 by .•004 OAT-3C-95 MON 11; 36 Ali AO FAX N0. 907.._ 7542 P. C1IG1 ~ • ~Vlemorandum State of Alaska Oil and Gas Conservation CommL4sion ?o: Well Files 91-119 October 27, I995 95- 48 Fm: Jack Hartz ~~- Subj: Multi Lateral Drilling - PBU S-]7A (API # 02921148-O1) Permit 91-119 PBU S-17AL 1 (API # 0292 1 1 48-60) Permit 95-48 S-17AL1 was permitted to add a lateral to the original completion of S-17A attd produce both the original completion and lateral. Production was to be reported to S-17A (02921148-01 API completion ID). While drilling the lateral, lost citenlation and other problems occurred causing the lateral and existing perfs to be squeezed with cem~t The operator did not apply with a 10-463 to PBtA S-17A, therefore, the perfotaaaotas are considered squeezed and not P&A. This is similar to Case VI !n the Multi-lateral (W elibore Segment) DrI111og Permit Procedures. The logical approach is to give S-I7A a CWBS (Completed Wellborn Segments) status, and eontmue to report production to the original weilbore S-17A API # 02921148-01. ~_ The S-17AL l lateral was eventually completed and should be entered in our History Database as a multilatet~l with API # 02921 I48-60. cc: Ted Stagg BI'X CTU Drilli~tg a 5, 1.~ ~ ~ :x...' ~~ ~~ ~~ ~~ ~~ r°~.~~ ~°/~~~ ~ ~-~ ~'~ r ~~~ f U7/20/2001 08:22 FAX 907 564 5510 p by • BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorape,Alaska 99519-6612 1907) 561-5111 • ~~~'' , G a l~"~ • ~'Y/ c C~9-~ 1 ~/ ~~~ fool ~~iv~fi-T~orY , in/ ~~-:.rte ~ 7~lICS~ ~a,~~s ayo-eons THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE NOVEMBER 2, 2000 P M E E L E W A TE R IA L U N D ER THIS MARKER Memorandum State of Alaska Oil and Gas Conservation Commission To: October 27, 1995 Em: Subj' Well Files 91-119 95- 48 Jack Hartz ~gky Multi Lateral Drilling - PBU S-17A (API# 02921148-01) Permit 91-119 PBU S-17AL1 (API# 02921148-60) Permit 95-48 S- 17AL 1 was permitted to add a lateral to the original completion of S- 17A and produce both the original completion and lateral. Production was to be reported to S-17A (02921148-01 API completion ID). While drilling the lateral, lost circulation and other problems occurred causing the lateral and existing perfs to be squeezed with cement. The operator did not apply with a 10-403 to P&A S-17A, therefore, the perforations are considered squeezed and no__.lt P&A. This is similar tO Case VI in the Multi-lateral (Wellbore Segment) Drilling Permit Procedures. The logical approach is to give S-17A (~Eompleted Wellbore Segments) status, and continue to report production to the original wellbore S-17A APl02-¢g# 1148-01. The S-17AL I lateral was eventually completed and should be entered in our History Database as a multilateral with API# 02921148-60. cc: Ted Stagg B12X CTU Drilling ,: ' STATE OF ALASKA ALAS'r¢~ OIL AND GAS CONSERVATION UOMMISSION TEl L COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPEt~ED [] ABANDONED [] SERVICE [] ¢,Plugged back for CT redrill 2. Name of Operator 7. Permit Number BP Exploration 91-119 3. Address 8. APl Number P. O. Box 196612, Anchora~Te, Alaska 99519-6612 5o-029-21148-01 4. Location of well at surface .~.~.,.~-*~' j~,C,~l~&~ 9. Unit or Lease Name , ~ Prudhoe Bay Unit 2204' SNL, 712' EWL, SEC.'34~ T12N, R12E 10. Well Number At Top Producing Interval · S-17A(33-34-12-12) 2496'NSL, 2042'WEL, SEC. 34, T12N, R12E ~-..,,~~,~ 11. Field and Pool At Total Depth Prudhoe Bay Field/Prudhoe Bay Pool 2021 SNL, 1971 WEL, SEC. 34, T12N, R12E 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE= 67. 48 ADL 28258 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 9/21/91 10/10/91 7/09/95I N/Afeet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 120. Depth where SSSV set [21. Thickness of Permafrost 10060MD/9137 TVD 9450MD/8662SS YES [] NO []I 2110 feet MDI 1860' 22. Type Electric or Other Logs Run None 23. CASING, LINER AND CEMENTING RECORD SE-'FI'ING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO-FI'OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20x30 Insulated Conductor Surf 110 36 8 cu yds concrete 13 3/8 72 L-80 Surf 2662 17 1/2 4000 cuft 9 5/8 47 L-80 Surf 9488 12 1/4 2214 cuft 7 26 NT80S 13cr 8045 10060 8 1/2 450 cu ft 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 IMD} A!lperforations cement squeezed in preparation for coiled tubing 4 1/2" 12. 6# 8083 8002 sidetrack 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9450-9668 95 cuft Class G 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 10/27/91 Flowin¢/ Gas lift Date of Test lHours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESlZE IGAS-OIL RATIO I TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. Submit in duplicate Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE ,'9. 30. GEOLOGIC MARK~_r~S FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Sag R. Sst. 9482 8664 Shublik 9531 8701 Ivishak 9652 8794 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (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 TREE: 4" CIW WELLHEAD: 13-3/8" McEVOY ACTUATOR: BAKER 13-3/8", 72#/ft L-80 BTRS S-17A Cement Squeeze CMT'd --1 KB. ELEV = 67.5 BF. ELEV --- 38.83 I I -- SSSV LANDING NIPPLE I 2110 I 41/2 CAMCO (3.813 ~ D) GAS LIFT MANDRELS Otis (1 1/2 RA Latch) NoJvlD(BKBI JTVDss DEV. 5 /3°62 12993 J9* 4 /5254 14974 129' 3 /7181 16688 124, 2 /7895 17339 127. J 4-1/2", 12.6#/ft, 13CR, TDS TUBING TUBING ID: 3.958" CAPACITY: .0152 BBL/FT Top of 2.7/8 Liner (uncemented) 8,030' MD TOPOFT" 13CR I DJ LINER HANGER ~ 8000 M ~ 9-5/8", 47#/ff, L-80, BTRS 9-5/8" KOP J~ 8300' MD I 4 1/2 SWS Nipple 3.813 I.D tlS RATCH LATCH OTIS HVT PACKER 3.88 I.D 4-1/2" X NIPPLE (3.813" I.D.) 4-1/2" XN NIPPLE (3.725" I.D.) r 7989 J J 8o52J J 8071J 4-1/2' WLEG J 8083J 3.958 ID I Whipstock @ 9,450' 17 bbls cement squeezed into 7" liner bbl cement layed in 3 3/4" hole PERFORATION SUMMARY SIZE SPF INTERVAL OPEN/SQZ'D 3 3/8 6 9620 - 9635 SQZ'D 7/9/95 3 3/8 6 9641 - 9647 SQZ'D 7/9/95 3 3/8 6 9650 - 9665 SQZ'D 7/9/95 3 3/6 6 9665 - 9701 SQ;~D 7/9/95 3 3/8 6 9705 - 9709 SQZ'D 7/9/95 3 3/8 6 9711 - 9720 SQZ'D 7/9/95 PBT[ 7", 26#/ff, NTSOS I 1 0,060 13CR NSCC I Daily Operations Wel I: S- 17A Accept: Field: Prudhoe Bay Spud: APl: 50-029-21148-01 Release: Permit: 91-119 CTD Unit: Camco #4932 O7/O9/95 - - RU CTU #4932. RIH WITH NOZZLE TO TD AT 9518. DISPLACED WELL TO SEAWATER WITH BIOZAN SWEEPS. MIXED AND PUMPED 18 BBL CEMENT FROM 9518 TO 9337 WHILE MAINTAINING 125 PSI ON WELLHEAD. (THIS PROCEDURE FILLED THE 3.75" OPEN HOLE WITH 1.1 BBLS CEMENT AND DOWNSQUEEZED THE 7" LINER BELOW THE WHIPSTOCK WITH 17 BBLS CEMENT. CALCULATED CEMENT FILL IN 7", BELOW WHIPSTOCK, IS 445 FT.) CONTAMINATED WITH BIOZAN DOWN TO 9466' MD. CIRCULATED WELL TO SEAWATER FROM 9466'. RD. BP EXPLORATION To: Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention' Steve McMains Date: September 13, 1995 Subject: Well S- 17A and S-17AL1 Well S-17A was selected as a candidate for testing a through tubing whipstock for use with coiled tubing drilling. On Jan. 13, 1995, a Form 10-403 was approved for setting a whipstock in the 7" liner then drilling 50 ft. of Sag R. formation with coiled tubing. This work was done from Feb. 10-26, 1995. On April 13, 1995, a Permit to Drill, form 10-401, was approved for deepening the coil drilled hole to the Ivishak. The original perforations in the S-17A liner were to be left open to provide for simultaneous production from the original S-17A perforations and the new CT drilled sidetrack which was to be completed open hole. The sidetrack was named S-17AL1 because some of the perforated interval in S-17A was to be left open to production. The suffix "60" was added to the APl number of the well. On May 2, 1995 coiled tubing drilling equipment was rigged up to deepen the sidetrack, S-17AL1 Drilling tool problems were encountered along wi~$.L__~---~£/° ~,-o circulation when th~ sidetracked hole was displaced to a drill-in fluid~On May 13, 1995, the drilling equipment was rigged down with no footage drilled. A letter advising the A. O. G. C. C. of the temporary suspension of operations was sent on May, 18 1995. On July 9, 1995, a coiled tubing service unit was rigged up to plug back the coiled drilled lateral and squeeze perforations in the original S-17A liner below the whipstock. The plug back and squeeze operation was performed with 18 bbl's of cement. Cement was washed out to the top of the whipstock to facilitate future coil drilling. No notices were filed with the A.O.G.C.C. at the time the operation was done. A form 10-407 addressing this abandonment of S-17A perforations is being filed with this letter. Coil drilling resumed on S17-AL1 on July 15, 1995 and the sidetrack was completed with a 2 7/8" uncemented liner on July 29,1995. On August 7, 1995 the well was perforated for production. A completion report, Form 10-407, was filed on August 30, 1995. Yours Sincerely, CTU Drilling Engineer c.c. Well File Petrotechnical Data Center 07/19/2001 09:24 FAX 907 564 5510 by ~J002/002 U7/19/ZU01 09:24 FAX 907 564 5510 by • ' ~`~/ bP @1001/002 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage,Aiaska 99519-6612 (907} 561-5111 ~d~ %UU}2 ~(~ C j~ ~ LC ~~ ~~No ~/ ~ r= y0 ~ ~~~ c~ ~ ~ s ~ ~o~s ~~N c ~-r~iv S, yi/~ L ~/~/~ O ,~ ~~~ ~/ ~ i ~~ ~ ~ ~G Y- s69~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate Plugging Pull tubing Alter casing Repair well Perforate Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2204' SNL, 712' EWL, SEC. 35, T12N, R12E, UPM At top of productive interval 2496' NSL, 2042' WEL, SEC. 34, T12N, R12E, UPM At effective depth 2534' NSL, 2150' WEL, SEC. 34, T12N, R12E, UPM At total depth 2568' NSL, 2246' WEL, SEC. 34, T12N, R12E, UPM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical (Sag R) 9940 feet BKB 9201 'feet 9725 feet BKB 9012 feet 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE= 67.48 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-17A(33-34-12-12) PBU 9. Permit number/approval number 91-119 / 95-003 10. APl number 50- 029-21148-01 11. Field/Pool Prudhoe Oil Pool Plugs (measured) Junk (measured) fill on top of perf gun fish at 9725' (06/88) Casing Length Structural -- Conductor 110 Surface 2633 Intermediate 9459 Production -- Liner 732 Perforation depth: measured Size Cemented Measured depth True verticaldepth BKB 139 139 2662 2662 9488 8804 20x30 8 c.y. 13 3/8 4000 c.f. 9 5/8 2214 c.f. 7 278 c.f. 9208-9940 9620'-9635', 9641 '-9647', 9650'-9665',9665'-9701 ',9705'-9709', 9711 '-9 720' 8558-9201 true vertical subsea 8795'- 8873' (six intervals) Tubing (size, grade, and measured depth) 4 1/2" L-80 to 9158' with 4 1/2" tailpipe to 9267' Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary See Attachment Intervals treated (measured) Treatment description including volumes used and final pressure 95/8"BOTpackerat9158'; 41/2"SSSVat2296' ~ ~C~ ~O 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations ,,~ 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby cf)rtify that theforegoing is true and correct to the best of my knowledge. Signed ~?,,{ ,,-, · 0¢"~1 Title Senior TechnicalAssistant II Form 10-404[ F~ev 06J15/88 SUBMIT IN DLg'PL~ATE 2/9/95 2/10/95 2/20/95 2/21/95 2/23/95 2/24/95 2/25/95 2/25/95 2/26/95 WELL S-17A(33-34-12-12) Sidetrack Operation Approval #95-003 Run 20 ft dummy gun Run and set whipstock with e-line Run 20 ft dummy gun Mill window with CT - In progress Mill window with CT Start up OPS after down for weather. Mill window with Mill window with CT Mill window with CT Drill out sag with CT Complete drill out of SAG with CT - 62 Feet!!!! LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 21 April 1995 RE: Transmittal of Data Sent by: PRIORITY MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION CN/GR FINAL BL+RF PFC/PERF FINAL BL+RF PLS FINAL BL+RF CN/GR FINAL BL+RF ECC No. Run # 1 5073.04 Run # 1 6078.02 Run ~ 1 6365.02 Run # 1 64'07.00 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX ~o (907) 563-7803 Received' ~.-~' ~~~. Date: Piesse sign and return Petro~,eohnieal Data Cen%eF SP Exploration (Alaska) 900 East Benson Boulevar~ Anchorage, Alaska Reeeivedby - - ' =- --~"' ___ . -' Al~:~'l~~~' Coris. commissl.on Anchoral]e LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 14 February 1995 RE: Transmittal of Data Sent by: ANCH.EXPRESS Dear Sir/Madam, Enclosed, please find the data as described below: WELL S-17A DESCRIPTION 1 PLS/STP FINAL BL+RF 1 PLS FINAL BL+RF 1 GR/CCL FINAL BL+RF 1 POL/CCL FINAL BL+RF ECC No. Run # 1 1214.05 Run # 1 6340.01 Run # 1 6365.00 Run # 1 6365.01 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: EIVED 1 7 1995 Alaska Oil & Gas Oons. Commission Anchorage STATE OF ALASKA ALA~~'' OIL AND GAS CONSERVATION COMMISSlC APPLICA'I ,ON FOR SUNDRY AP[-'rlOVALS 1. Type of Request: Abandon __ Suspend __ Operation Shutdown __ Re-enter suspended well Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program __ Pull tubing __ Variance __ Perforate __ Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2204' SNL, 712' EWL, SEC. 35, T12N, R12E, UPM At top of productive interval 2496' NSL, 2042' WEL, SEC. 34, T12N, R12E, UPM At effective depth 2534' NSL, 2150' WEL, SEC. 34, T12N, R12E, UPM At total depth 2568' NSL, 2246' WEL, SEC. 34, T12N, R12E, UPM (Sag R) 5. Type of Well: Development X Exploratory __ Stratigraphic __ Service ORIGINAL 6. Datum elevation (DF or KB) KBE = 67.48 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-17A(33-34-12-12) PBU 9. Permit number ~¢'/--//? 10. APl number 50- 029-21148.-~1 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural -- Conductor 110 Surface 2633 Intermediate 9459 Production -- Liner 732 Perforation depth: 9940 feet BKB 9201 feet 9725 feet BKB 9012 feet Size 20x30 133/8 9 5/8 Plugs (measured) Junk (measured) Cemented 8 c.y. 4000 c.f. 2214 c.f. 7 278 c.f. measured 9489~9525', (Sag R) , 9633 -9677, 9692'-9726, 9741'-9758' (ivishak) true vertical subsea 8738'-8752' (Sag R) 8864'-8974' (three Ivishak intervals) Tubing (size, grade, and measured depth) 4 1/2"L-80 to 9158' with 4 1/2" tailpipe to 9267' fill on top of perf gun fish at 9725' (06/88) Measured depth True vertical depth BKB 139 139 2662 2662 9488 8804 9208-9940 8558-9201 RECEIVED JAN - 4 1995 Ataska 0il & Gas Cons, Commission Anchorage Packers and SSSV (type and measured depth) 9 5/8" BOT packer at 9158'; 4 1/2" SSSV at 2296' 13. Attachments Description summary of proposal X Detailed operations program BOP sketch X 14. Estimated date for commencing operation 16. If proposal was verbally approved Oil X Name of approver Date approved Service 17. ! hereby certify that the foregoing is true and correct to the best of my knowledge. Signe Title Coil Tubing Engineer 15. Status of well classification as: Gas Suspended __ Date ')/~'-'&'-"' FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test__ Location clearance ~ Mechanical Integrity Test __ Subsequent form required 10-/Co q Original Signed By Approved by order of the Commission David W. Johnston IApproval .~pproved Copy Returned., '~C-orh(ni§sioher - Date Form 10-403 Rev 06/15/88 SUBMIT I'N TRIPLICATE BPX S-17a Sidetrack Summary of Operations: S-17a currently is a Iow productivity producer. This operation is being undertaken to supplement the existing production and develop new technology. All operations will be conducted thru-tubing with the tree in place. A whipstock will be set at the top of the Sag at 9,450'. Utilizing coil tubing, a window will be cut in the 7" and 50 ft of formation will be drilled to the bottom of the Sag without directional control. No logs will be run. This operation will provide open hole productivity from the Sag and another test of the thru-tubing whipstock. The existing perforations will not be isolated to preserve the existing production. At a future date, this hole will probably be extended into the Ivishak with a directional drilling coil tubing unit. This work will be permitted separately. Procedure Outline: - RU Slickline. Pull SSSV. RU electric line. Set thru-tubing whipstock at 9,450' (Top of Sag). Run video Icg and inspect whipstock. RU conventional coil unit. Mill window and drill 50 ft of formation. RD - RU electric line. Run video Icg and inspect whipstock. - RU Slickline. Run SSSV. - Put well on production. RECEIVED JAN - 4 1995 Alaska Oil & Gas Oons. Commission Anchoraj~ TREE: 4" CIW ./~-"'" WELLHEAD: 13-3/8" McEVOY ACTUATOR: BAKER 13-3/8", 72#/ft L-80 BTRS CMT'd -- i , MAX ANGLE: 29e KB. E = 67.5 BF. EL.- · = 38.83 sssv LANDING NmPLEI 2110 4 1/2 CAMCO (3.8131 D) GAS LIFT MANDRELS 1/2 RA DEV. 4-1/2", 12,6#/ft, 13CR, TDS TUBING TUBING ID: 3,958" CAPACITY: .0152 BBL/FT TOP OF7" 13CR Il~ LINER HANGER -8000 M ~ g-5/8", L-80, BTRS 9-5/8" KOP [- 8300' MD SECTION WINDOW j"' 8300',t,o 8380'` I Set Whipstock at 9450' PERFORATION SUMMARY I.NTERVAL 9620'- 9635' 9641'- 9647' 9650'- 9665' 9665' - 9701' 9705'- 9709' 9711' - 9720' 7", 26#/ft, NTSOS 13CR NSCC 10,060 4 1/2 SWS Nipple 3.813 I.D RATCH LATCH OTIS HVT PACKER 3.88 I.D 4-1/2" X NIPPLE (3.813" I.D.) 4-1/2" XN NIPPLE (3.725" I.D.) 179891 8052 , , so7 l 80831 8078 4-1/2' WLEG 3.958 ID ELMD IMAX ANGLE: 42° RECEIVED JAN - 4 1995 u, & Gas Cons. Commission Anchora,je * J BP Exploration (Alaska) ,, -~ Coil Tubing Drilling Wellhead/BOPE Conf~quration COILI~ TUBING ~'~,~,~....~.. ' ' ' "' .... I~IJB3TCR lEAD PACK-OFF The operating procedure for this BOP configuration will be to Install entire drilling assembly in lubricator and pressure test prior to opening ~wab valve. This will be performed on each trip. Coming out of hole, this configuraUon allows swab valve to be closed prior to disconnecting lubricator. Drilling Tools Connect SV, Hyd Blind/Shear Blind/Shear Slip Pipe 4 1/16" X 10,000 psi Coil Tubing BOPE Flanged Hose to Choke Manifold Swab Valve Ranged Hose to Pump Uno Existing Flow{ine ~ SSV-Hydraulic Actuated Rev 6/15/a4 RECEIVED ~ska Oil & Gas Cons. Commission Anchora. ~ ' STATE OF ALASKA ' ' ' ;-~,I.. -~ OIL AND GAS CONSERVATION COMM'.S. ,q REPORT OF SUNDRY WELL OPERATIONS Perforate Other X 6. Datum elevation (DF or K~ KBE= 67.48 AM~/,.~f'eet 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing Alter casing Repair well 2. Name of Operator BP Exploration (Alaska) inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 (Sag R) 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 2204' SNL, 712' EWL, SEC. 35, T12N, R12E, UPM At top of productive interval 2496' NSL, 2042' WEL, SEC. 34, T12N, R12E, UPM At effective depth 2534' NSL, 2150' WEL, SEC. 34, T12N, R12E, UPM At total depth 2568' NSL, 2246' WEL, SEC. 34, T12N, R12E, UPM 12. Present well condition summary Total depth: measured 9940 feet Plugs (measured) true vertical BKB 9201 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-17A(33-34-12-12) PBU 9. Permit numbe.r~er 10. APl number 50- 029-21148 11. Field/Pool Prudhoe Oil Pool Effective depth: measured 9725 feet truevertical BKB 9012 feet Junk (measured) fill on top of perf gun fish at 9725' (06188) Casing Length Size Structural -- Conductor 110 20x30 Surface 2633 13 3/8 Intermediate 9459 9 5/8 Production -- Liner 732 7 Perforation depth: measured true vertical Cemented Measured depth True vertical depth BKB 8 c.y. 139 139 4000 c.f. 2662 2662 2214 c.f. 9488 8804 278 c.f. 9208-9940 8558-9201 9489'-9525' (Sag R) 9633'-9677', 9692'-9726', 9741 '-9758' (Ivishak) subsea 8738'-8752' (Sag R) 8864'-8974' (three Ivishak intervals) Tubing (size, grade, and measured depth) 4 1/2" L-80 to 9158' with 4 1/2" tailpipe to 9267' Packers and SSSV (type and measured depth) 9 5/8" BOT packer at 9158'; 4 1/2" SSSV at 2296' 13. Stimulation or cement squeeze summary Intervals treated (measured) See Attachment 14. Treatment description including volumes used and final pressure Representative Daily Averaqe Production or Injection Data :~. ~.:. :,,...:.: ~. - :...~; ~ Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure ~uo~ng Pressure Prior to well operation 110 132 2 1520 264 Subsequent to operation 1740 1258 512 2590 284 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I he. leby certify that the fore,~g is true and correct to the best of my knowledge. S i g n e d~' ~ ~t,~ ~'/~,~" ~ ,~C~O'z,q~ Title SeniorTechnicalAssistantl Form 10-40~ Rev 06/15/88 / Date SUBMIT IN DL-1'PLI~ATE / 3/28/92 WELL S-17A(33-34-12-12) FRAC Performed a FRAC (IVISHAK) Treatment using the following fluids: FLUIDS PUMPED DOWNHOLE FRAC: 10 BBLS 50# GEL PREPAD 115 BBLS PAD W/160 GAL ESL 36 Dirty 1 PPG 7 2 PPG 12 3 PPG 15 4 PPG 17 5 PPG 19 6 PPG 22 7 PPG 220 8 PPG 174 50~-20# GEL FLUSH fjh 6/26/93 INDIVIDUAL WELL GEOLOGICAL PERMIT DATA INVENTORY REPORT DETAIL 09/14/1993 PAGE: 1 91-119 CL 91-119 CL 91-119 CNL 91-119 COMP 91-119 GAS LIFT 91-119 MWD 91-119 MWD 91-119 MWD 91-119 91-119 91-119 91-119 MWD-DGR/CNO/SFD MWD-DGR/CNO/SFD MWD-DGR/EWR PROD 91-119 407 91-119 DAILY WELL OP 91-119 SURVEY 91-119 5098 91-119 Are well tests required? Was well cored? Yes ~o~.. 5177 Yes R1,5",9400-9978 R1,5",9400-9978 R1,5",9400-9978 R1,5",7940-9946 R1,2",2000-9984 RI-2,2&5",7700-9200 RI-2,2&5",8200-10099 R1-2,5",8200-10100 RI-4,2&5",7718-9203 R1-4,5",8250-10060 RI-4,2&5",8250-10060 R1,5",9550-9821 COMP DATE:10/27/91 09/22/91-10/15/91 SS DIRECTIONAL CH,9338-10005.5 OH,8297-10099 If yes, was the core analysis & description received? Are dry ditch samples required? Yes ~ INITIAL Yes No COMMENTS: BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 04/15/92 T# 83408 BP OPEN HOLE FINALS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. S-17A MWD DGR/CN0/SFD 10/11/91 #1-4 7718.00- 9203.00 SPERRY 2/5" S-17A MWD DGR/CN0/SFD 10/11/91 #1-4 8250.00-10060.00 SPERRY 5 " S-17A MWD DGR/EWR 10/11/91 #1-4 8250.00-10060.00 SPERRY 2/5" Information Control Well Records Adrian J. Martin ~--~ STATE OF ALASKA r_ ALASi'i .)IL AND GAS CONSERVATION L,.~ MMIS WELL COMPLETION OR RECOMP LETION REPORT AND LOG i l. Status 'of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number BP Exploration 91-119 3. Address 8. APl Number P. 0. Box 196612, Anchorage, Alaska 99519-6612 50- 029-21148-01 4. Location of well at surface 9. Unit or Lease Name ! ;'*';"~'~'; F'~"*~- I10. Well Number At Top Producing Interval i ~~,2_.. !' ".',.~?,FIE'5* } S-17A(32-34-12-12) 2125 SNL, 1700 WEL, Sec. 34, T12N, R12E ? : :-.:~ ;'-~--~/'~-' 11. Field and Pool i~'2 Prudhoe Bay Field/Prudhoe Bay Pool At Total Depth 2021 SNL, 1971 WEL, Sec. 34 T12N, R12E ......... -~ ~ ~..? 5. Elevation in feet (indicate KB, DF, etc.) Ie. Lease Designation and Sedal No. KBE 67.47' I ADL 28258 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore J16. No. ol Completions 9/21/91 10/10/91 10/19/91J N/A feet MSLI ONE 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey ~::'0. Depth where SSSV set ~1. Thickness of Permafrost 10060'MD/9137'TVD 9981MD/9075' TVD YES ~ t,D []J 211Qeet MD J 1860' 22. Type Electric or Other Logs Run EWR/GR/CNI._/DSFD 23. CASING, LINER AND CEMENTING ~ SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'I-i'OM HOLE SIZE CEM~ RECORD AIVIO~ PULLED 20"X30' Insulated conductor Surface 110' 36" 8 cu yds concrete 13-3/8' 72# L-80 Surface 2662' 17-.1/2" 4000 cu ft Arcitc set II/iff 9-5/8' 47# L-80 Surface 9488' 12-1/4"...~ 2214 cu ft Class G 7' 26# NT80S 13 ct 8045' 10060' 8-1/2"~ .... 450 cu ft Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBI'C3RECORD interval, size and number) SIZE DEPTH SET (MDI PACKER SET (MDI SWS 3-3/8" 6spf 4-1/2" 12.6# 8083' 8002' MD TVD ss NT13Cr 80 TDS 9620;9635' 8794'-8806' ~:. 26. ACID, FRACTURE, CEMENT SQUEEZ~ ETC. 9641'-9647' 8811'-8816' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9650;9701' 8818;8858' 9705;9709' 8861;8864' 9711 ;9720' 8865'.8872' ;127 . PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 10/27/91 I Flowin~t/Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SEE JGAS-OIL RATIO TEST PERIOD ]~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MC, F WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. RECEIV D APR - ! 199~ Alaska 8[[ & 6as Cons. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC MARKERS PORMATION TESTS ,. · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Sag 9, 482' 8, 664' Shublik A 9,531' 8, 701' Zone 4 9,652' 8, 794' 31. LIST OF A'I-FACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signe_dz'~~~~ ~'~3'~-T-~le SeniorTechnica/A$$istant Date ,,/ / ~/''- INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg 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". ~ECEtV~ Form 10-407 APR - 1 3992 AlasEa 0il & Gas Cons. Commission ACTIVITY SUMMARY BP/AAI SHARED SERVICE NORTH SLOPE AK PRUDHOE BAY UNIT S-17A NABORS 2ES KILL: 6.5 NDNU: 0.5 OTHR: 15.0 09/22/91 ( 1) N/D TREE. MW: 9.4 WBM TD: 9940 MOVE RIG F/ N-10 TO S-17A. RIG ACCEPTED @ 23:00 HRS, PB: 9067 9/21/91. CIRC OUT DIESEL CAP. MIX MUD. DISP WELL W/ MUD. SUPV:BZJ DAILY:S24,663 CUM:$24,663 ETD:S24,663 EFC:$2,056,250 NDNU: 10.5 PTBG: 6.5 PROB: 7.0 PROB CODE: WH 09/23/91 ( 2) LD/ TBG. MW: 9.2 WBM TD: 9940 N/D TREE. N/U BOPE. TEST BOPE. N/D BOPE. N/U BOPE. TEST PB: 9067 BOPE. PULL TBG HGR. CIRC. POOH W/ 4-1/2" TBG. SUPV:BZJ DAILY:S43,721 CUM:$68,384 ETD:S68,384 EFC:$2,056,250 PTBG: 7.5 OTHR: 4.5 09/24/91 ( 3) RIH W/ EZSV CIBP. MW: 9.1 WBM TD: 9940 POOH, L/D 4-1/2" TBG. M/U KELLY. RIH W/ HOWCO EZSV CIBP PM PB: 9067 4-1/2" DP. SUPV:BZJ DAILY:S26,838 CUM:$95,222 ETD:S95,222 EFC:$2,056,250 NDNU: 2.0 COUT: 4.0 TCSG: 2.0 09/25/91 ( 4) CHANGE PACKOFF. MW: 9.1 WBM TD: 9940 RIH W/ CIBP ON DP. SET EZSV @ 8500' TEST CSG, CIBP. PB: 9067 CIRC. POOH. INSTALL NEW 9-5/8" PACKOFF. SUPV:BZJ DAILY:S217,315 CUM:$312,537 ETD:S312,537 EFC:$2,056,250 NDNU: 1.0 09/26/91 (5) TD: 9940 PB: 9067 SUPV:BZJ CIRC. MW: 9.1 WBM TEST PACKOFF. RIH W/ MILL. LOCATE CSG COLLAR @ 8279'. START MILL 9-5/8" CSG @ 8300' MILL WINDOW IN CSG F/ 8300'-8380' CIRC 45 BBLS HIGH VIS SWEEP. DAILY:$47,6i8 CUM:$360,155 ETD:S360,155 EFC:$2,056,250 PROB: 10.5 PROB CODE: DS 09/27/91 ( 6) RIH TO SPOT K/O PLUG. MW: 9.1 WBM TD: 9940 CIRC. POOH. RIH W/ BHA %3. RIH TO 7274'. ATTEMPT TO PB: 9067 CIRC. DP PLUGGED. -OOH. RIH. SUPV:BZJ DAILY:S58,547 CUM:$418,702 ETD:S418,702 EFC:$2,056,250 PROB: 7.5 PROB CODE: DS 09/28/91 ( 7) RIH. MW: 9.2 WBM TD: 9940 RIH. WASH F/ 8245'-8391' CIRC. SET @ 8380'. R/U DOWELL. PB: 9067 PUMP 11.5 BBLS XL SPACER, 55 BBLS 'G' CMT W/ 7% D65, .1% SUPV:RWO D800, .05 GPS D47 @ 17 PPG. DISP. POOH 15 STDS. SQZ CMT W/ 1500 PSI. POOH. RIH W/ BHA ~5. DAILY:S75,380 CUM:$494,082 ETD:S494,082 EFC:$2,056,250 RECEIVED -~,laska O~j & (~as Co;ts. uummissio¢ Anchorage ACTIVITY SUMMARY BP/AAI SHARED SERVICE NORTH SLOPE AK PRUDHOE BAY UNIT S-17A NABORS 2ES COUT: 5.5 OTHR: 2.5 09/29/91 ( 8) CLEAN PITS. MW: 9.2 WBM TD: 9940 RIH. WASH F/ 7527'-7750'. TAG CMT @ 7750' DRLG CMT TO PB: 9067 7920' CIRC. DRLG CMT F/ 7920'-8295' CIRC. DISP W/ 8.8 SUPV:RWO PPG OIL BASE MUD. CLEAN PITS. DAILY:S117,878 CUM:$611,960 ETD:S611,960 EFC:$2,056,250 S1P1 TRIP: 12.0 BOPE: 9.0 OTHR: 3.0 09/30/91 ( 9) RIH W/ BHA. MW: 8.8 VIS: 43 TD: 8295' ( 545) CLEAN PITS. CIRC. POOH. TEST BOPE. RIH W/ BHA %6. SUPV:RWO HOLE ANGLE:29 24 DAILY:S28,921 CUM:$640,881 ETD:S28,921 EFC:$2,668,210 S1P1 DRIL: 17.0 TRIP: 7.0 10/01/91 (10) DRLG. MW: 8.8 VIS: 44 TD: 8657' ( 362) ~ RIH. KICK OFF THRU WINDOW F/ 8295'-8345'. DRLG F/ SUPV:RWO 8345'-8657' KICK OFF (SPUD) WELL @ 13:00 HRS, 9/30/91. HOLE ANGLE:29 24 DAILY:S33,172 CUM:$674,053 ETD:S62,093 EFC:$2,668,210 S1P1 DRIL: 7.5 TRIP: 8.0 SURV: 1.0 OTHR: 3.5 PROB: 4.0 PROB CODE: EFC 10/02/91 (11) DRLG. MW: 8.8 VIS: 45 TD: 8922' ( 265) DRLG F/ 8657'-8847' POOH. M/U MWD. RIH. DRLG F/ SUPV:GTG/FH 8657'-8922' HOLE ANGLE:29 24 DAILY:S53,881 CUM:$727,934 ETD:S115,974 EFC:$2,668,210 S1P1 DRIL: 22.0 PROB: 2.0 PROB CODE: EFC 10/03/91 (12) DRLG. MW: 8.9 VIS: 45 TD: 9627' ( 705) DRLG F/ 8922'-9627' SUPV:GTG/FH HOLE ANGLE:29 24 DAILY:S41,944 CUM:$769,878 ETD:S157,918 EFC:$2,668,210 S1P1 DRIL: 13.0 TRIP: 2.5 PROB: 8.5 PROB CODE: TH 10/04/91 (13) POOH. MW: 8.9 VIS: 42 TD:10101' ( 474) DRLG F/ 9627'-10101' CBU. SHORT TRIP TO 8289' ATTEMPT SUPV:GTG/FH TO RIH THRU W~NDOW. WORK THRU WINDOW. CIRC. POOH. HOLE ANGLE:29 24 DAILY:S34,712 CUM:$804,590 ETD:S192,630 EFC:$2,668,210 S1P1 PROB: 24.0 PROB CODE: TH 10/05/91 (14) MIX CMT. MW: 9.0 VIS: 42 TD:10101' ( 0) POOH. RIH. TAG BTM @ 8344' ATTEMPT TO FIND SIDETRACK. SUPV:GTG/FH DRLG TO 8399' NOT IN SIDETRACK. CIRC. POOH. RIH W/ MULE HOLE ANGLE:29 24 SHOE TO 8344' R/U DOWELL. DAILY:S41,000 CUM:$845,590 ETD:S233,630 EFC:$2,668,210 ACTIVITY SUMMARY BP/AAI SHARED SERVICE NORTH SLOPE AK PRUDHOE BAY UNIT S-17A NABORS 2ES S1P1 PROB: 24.0 PROB CODE: TH 10/06/91 (15) WOC. MW: 9.0 VIS: 40 TD: 8218' ( 0) PUMP 15 BBLS SPACER, 8 BBLS XT SPACER, 49.1 BBLS 'G' CMT, 15 SUPV:GTG/FH BBLS SPACER. POOH 12 STDS. SQZ CMT W/ 800 PSI. POOH. TEST HOLE ANGLE:29 24 BOPE. RIH. WASH F/ 7615'- 7843' CBU. WASH F/ 7843'-8000' CBU. DRLG CMT F/ 8600'-8218'. CBU. WOC. DAILY:$79,3~8 CUM:$924,978 ETD:S313,018 EFC:$2,668,210 S1P1 PROB: 24.0 PROB CODE: TH 10/07/91. (16) · CBU. MW: 9.0 VIS: 40 TD: 8968' ( 750) X~DRLG CMT F/ 8218'-8345'. EST KICKOFF @ 8345'. DRLG F/ SUPV:GTG/FH 8345'-8968' CBU. SHORT TRIP 7 STDS. RIH TO BTM. CBU. HOLE ANGLE:29 24 DAILY:S40,491 CUM:$965,469 ETD:S353,509 EFC:$2,668,210 S1P1 PROB: 24.0 PROB CODE: TH 10/08/91 (17) REPLACE MWD. MW: 9.3 VIS: 40 TD: 8989' ( 21) CIRC. POOH. RIH. WASH 50' TO BTM DRLG F/ 8968'-8989' SUPV:GTG/FH NO MWD SIGNAL. POOH. REPLACE MWD. RIH. HOLE ANGLE:29 24 DAILY:S44,780 CUM:$1,010,249 ETD:S398,289 EFC:$2,668,210 S1P1 PROB: 24.0 PROB CODE: TH 10/09/91 (18) DRLG. MW: 9.2 VIS: 39 TD: 9554' ( 565) RIH. DRLG TO 9554' SUPV:DLW HOLE ANGLE:29 24 DAILY:S25,679 CUM:$1,035,928 ETD:S423,968 EFC:$2,668,210 S1P1 PROB: 24.0 PROB CODE: TH 10/10/91 (19) CLEANOUT FILL. MW: 9.2 VIS: 39 TD: 9835' ( 281) DRLG F/ 9554'-9835'_ POOH. RIH W/ BHA ~13 TO 8188' CIRC. SUPV:DLW RIH TO 9420' LOG F/ 9420'-9660' CLEANOUT FILL F/ HOLE ANGLE:29 24 9660'-9835'. NOTE: FOR THIS REPORT, THE CUMMULATIVE COST IS $1,068,478. DUE TO A PROBLEM WITH THE DATABASE, THE CUMMULATIVE COST REPORTED BELOW FOR THIS WELL IS WRONG. DAILY:S32,549 CUM:$1,068,477 ETD:S456,517 EFC:$2,668,210 SUPV:DLW HOLE ANGLE:29 24 S1P1 TRIP: 7.5 CASG: 1.0 BOPE: 2.5 PROB: 13.0 PROB CODE: TH 10/11/91 (20) RIH W/ 7" CSG. MW: 9.2 VIS: 38 TD:10060' ( 225) WASH F/ 9750'-9835'. DRLG F/ 9835'-10060' TD WELL @ 13:30 HRS, 10/10/91. CIRC. 19 STD SHORET TRIP. CBU. POOH. L/D BHA. TEST BOPE. RIH W/ 7" LNR. NOTE: CUMMULATIVE COST IS $1,316,854. DUE TO A PROBLEM WITH THE DATABASE, THE CUMMULATIVE COST REPORTED BELOW IS WRONG. DAILY:S248,377 CUM:$1,316,854 ETD:S704,894 EFC:$2,668,210 ACTIVITY SUMMARY BP/AAI SHARED SERVICE NORTH SLOPE AK PRUDHOE BAY UNIT S-17A NABORS 2ES 10/12/91 (21) TD:10060 PB:10060 SUPV:DLW COUT: 1.0 RCSG: 20.5 OTHR: 2.5 RIH. MW: 9.4 OBM RIH W/ 7" 13 CR LNR. CIRC. RIH W/ LNR TO 8228' CIRC. RIH TO 10060'. CIRC. PUMP 5 BBLS WATER, 40 BBLS MUDPUSH, 388 SX 'G' CMT @ 15.8 PPG. DISP W/ 3 BBLS WATER, 183 BBLS MUD. BUMP PLUG W/ 3500 PSI. SET LNR HGR @ 8035'. CIRC. POOH. TEST BOPE. RIH. DAILY:S327,202 CUM:$1,644,056 ETD:S1,032,096 EFC:$2,668,210 RCSG: 24.0 10/13/91 (22) TD:10060 PB: 9981 SUPV:DLW POOH. MW: 8.5 Seawater RIH W/ BHA #14. WASH TO TOL @ 8035'. NO CMT. CIRC. POOH. RIH W/ BHA #15. RIH TO 9911'. WASH TO 9981' CIRC. TEST LNT LAP. CIRC. REV CIRC. PUMP 50 BBLS GEL TONE, SEAWATER. TEST LNR LAP. POOH. DAILY:S42,111 CUM:$1,686,167 ETD:S1,074,207 EFC:$2,668,210 RPKR: 1.5 RCM]P: 10.0 RCSG: 12.5 10/14/91 (23) RIH W/ 4-1/2" TBG. MW: 8.5 Seawater TD:10060 POOH. RIH W/ CSG SCRAPER. REV CIRC. POOH. R/U OTIS. RIH PB: 9981 W/ GR/JB. R/U WEATHERFORD. RIH W/ 4-1/2" 13 CR TBG. SUPV:DLW DAILY:S40,494 CUM:$1,726,661 ETD:Si,ii4,701 EFC:$2,668,210 NDNU: 11.0 RCMP: 11.0 10/15/91 (24) RIG RELEASED @ 04:00 HRS. MW: 8.5 Seawater TD:10060 RIH W/ 4-1/2" 13 CR TBG & OTIS 'HVT' PKR. LAND TBG. REV PB: 9981 CIRC. SET PKR. N/D BOPE. N/U TREE. TEST TREE. DISP W/ SUPV:DLW 140 BBLS DIESEL FOR F/P. SET BPV. SECURE WELL. RIG RELEASED @ 04:00 HRS, 10/15/91. DAILY:S387,954 CUM:$2,114,615 ETD:S1,502,655 EFC:$2,668,210 PRUDHOE BAY DRILLING S-17A Alaska Oil .& GaS Cons. GREAT LAND DIRECTIONAL DRILLING, INC. REPORT OF SUB-SURFACE DIRECTIONAL SURVEY PRUDHOE BAY DRILLING · COMPANY S17A WELL NAME PRUDHOE BAY LOCATION AL1091D37A MWD 11/12/91 JOB NUMBER LYNN HENSLEY TYPE SURVEY DATE DIRECTIONAL ~ ~~ ~,'"~' SUPERVISOR ~~ NAME TITLE SIGNATURE 8300 FT. 10005 FT. DEPTH INTERVAL FROM TO 10/06/91 10/10/91 DATE SURVEY TAKEN FROM TO THIS IS A RECORD OF A SUB-SURFACE SURVEY OF YOUR WELL WE HAVE RETAINED A COPY OF YOUR SURVEY REPORT IN OUR FILES FOR YOUR CONVENIENCE; HOWEVER, SHOULD YOU SO DESIRE, ALL COPIES OF THE SURVEY REPORT WILL BE FORWARDED TO YOU ON WRITTEN REQUEST. ALL SURVEYS ARE KEPT IN A LOCKED FILE AND ARE HELD IN STRICTEST CONFIDENCE. GREAT LAND DIRECTIONAL DRILLING, Client .... : Field ...... : Well ...... : Section at: Engineer...' PRUDHOE BAY DRILLING PRUDHOE BAY S-17A N,33.40,W LYNN HENSLEY INC. Computation...: Survey Date...: RKB Elevation.: Reference ..... : Magnetic Dcln.: 11/12/91 MINIMUM CURVATURE 10/10/91 67.48 ft 30.00 E S MEAS INCLN C DEPTH ANGLE 8 8300 28.90 3 8417 27.50 3 8448 27.30 3 8479 27.30 3 8509 27.20 RECORD OF SURVEY (Calculated from a tie-in station at 8300 MD) VERTICAL-DEPTHS SECTION DIRECTION RELATIVE-COORDINATES BKB SUB-SEA DISTNCE BEARING FROM-WELL-HEAD CLOSURE DL DISTNCE BEARING /100 7761.0 7693.5 678.5 S 88.60 W 632.0 S 2191.0 W 2280.3 S 73.91 W <TIE 7864.2 7796.8 713.3 N 76.40 W 626.3 S 2245.6 W 2331.3 S 74.42 W 6.16 7891.8 7824.3 724.1 N 71.90 W 622.4 S 2259.3 W 2343.5 S 74.60 W 6.71 7919.3 7851.8 735.4 N 68.70 W 617.6 S 2272.7 W 2355.1 S 74.80 W 4.73 7946.0 7878.5 747.0 N 63.90 W 612.1 S 2285.3 W 2365.8 S 75.00 W 7.33 3 8542 27.10 7975.4 7907.9 760.1 N 60.50 W 605.1 S 2298.6 W 2376.9 S 75.25 W 4.71 3 8574 26.90 8003.9 7936.4 773.4 N 54.80 W 597.3 S 2310.8 W 2386.8 S 75.51 W 8.11 3 8608 26.60 8034.2 7966.8 787.8 N 49.80 W 588.0 S 2322.9 W 2396.2 S 75.80 W 6.68 3 8636 26.60 8059.3 7991.8 800.0 N 46.70 W 579.7 S 2332.3 W 2403.2 S 76.04 W 4.96 3 8667 26.20 8087.0 8019.6 813.5 N 41.80 W 569.8 S 2341.9 W 2410.2 S 76.33 W 7.14 3 8698 26.60 8114.8 8047.3 827.2 N 37.10 W 559.2 S 2350.6 W 2416.2 S 76.62 W 6.86 3 8729 27.10 8142.5 8075.0 841.2 N 34.90 W 547.8 S 2358.9 W 2421.7 S 76.93 W 3.59 3 8759 28.10 8169.1 8101.6 855.0 N 30.50 W 536.1 S 2366.4 W 2426.3 S 77.23 W 7.57 3 8790 28.50 8196.4 8128.9 869.7 N 27.30 W 523.3 S 2373.5 W 2430.5 S 77.57 W 5.06 3 8822 29.30 8224.4 8156.9 885.0 N 24.00 W 509.3 S 2380.2 W 2434.0 S 77.92 W 5.57 3 8850 30.70 8248.6 8181.1 898.8 N 22.70 W 496.5 S 2385.7 W 2436.8 S 78.24 W 5.51 3 8881 32.40 8275.0 8207.6 914.7 N 22.80 W 481.5 S 2392.0 W 2440.0 S 78.62 W 5.49 3 8910 34.10 8299.3 8231.8 930.4 N 22.37 W 466.8 S 2398.1 W 2443.1 S 78.98 W 5.92 3 8947 34.80 8329.8 8262.3 950.9 N 23.60 W 447.6 S 2406.3 W 2447.5 S 79.46 W 2.67 3 8976 34.80 8353.6 8286.1 967.2 N 22.30 W 432.3 S 2412.7 W 2451.1 S 79.84 W 2.56 3 9007 36.00 8378.9 8311.4 984.8 N 21.40 W 415.7 S 2419.4 W 2454.8 S 80.25 W 4.22 ^Survey Codes: 3/MWD 8/TIE-IN (PS17AD B1.24) S-17A S MEAS INCLN C DEPTH ANGLE 3 9036 35.90 3 9068 36.70 3 9099 36.60 3 9130 37.20 3 9162 37.90 3 9193 37.60 3 9224 37.70 3 9256 37.30 3 9289 37.40 3 9320 37.80 3 9350 38.70 3 9381 39.30 3 9414 39.40 3 9442 39.10 3 9475 39.20' 3 9504 39.10 3 9538 38.80 3 9571 38.30 3 9602 37.90 3 9634 37.70 3 9666 38.40 3 9696 39.60 3 9727 39.70 3 9757 39.70 3 9798 39.50 3 9830 39.50 RECORD OF SURVEY (Calculated from a tie-in station at 8300 MD) VERTICAL-DEPTHS SECTION DIRECTION RELATIVE-COORDINATES BKB SUB-SEA DISTNCE BEARING FROM-WELL-HEAD 8402.4 8334.9 1001.5 N 21.30 W 399.8 S 2425.6 W 8428.2 8360.7 1019.9 N 20.10 W 382.1 S 2432.3 W 8453.0 8385.5 1037.9 N 19.60 W 364.7 S 2438.6 W 8477.8 8410.3 1056.0 N 19.20 W 347.1 S 2444.7 W 8503.2 8435.7 1074.9 N 19.90 W 328.7 S 2451.3 W 8527.7 8460.2 1093.4 N 19.70 W 310.9 S 2457.7 W 8552.2 8484.8 1111.8 N 19.90 W 293.1 S 2464.1 W 8577.6 8510.1 1130.7 N 19.60 W 274.7 S 2470.7 W 8603.9 8536.4 1150.2 N 20.10 W 255.9 S 2477.5 W 8628.4 8560.9 1168.7 N 23.00 W 238.3 S 2484.4 W 8652.0 8584.5 1187.0 N 23.50 W 221.3 S 2491.8 W 8676.1 8608.6 1206.2 N 25.00 W 203.5 S 2499.8 W 8701.6 8634.1 1226.9 N 25.30 W 184.5 S 2508.7 W 8723.3 8655.8 1244.4 N 24.50 W 168.5 S 2516.1 W 8748.9 8681.4 1265.0 N 25.10 W 149.6 S 2524.9 W 8771.4 8703.9 1283.2 N 25.70 W 133.0 S 2532.7 W 8797.8 8730.3 1304.3 N 24.40 W 113.7 S 2541.8 W 8823.6 8756.1 1324.6 N 24.10 W 94.9 S 2550.2 W 8848.0 8780.5 1343.5 N 24.90 W 77.5 S 2558.2 W 8873.3 8805.8 1362.9 N 25.00 W 59.7 S 2566.4 W 8898.5 8831.0 1382.4 N 25.60 W 41.9 S 2574.9 W 8921.8 8854.3 1401.1 N 25.40 W 24.8 S 2583.0 W 8945.7 8878.2 1420.7 N 25.80 W 7.0 S 2591.5 W 8968.7 8901.3 1439.8 N 26.20 W 10.2 N 2599.9 W 9000.3 8932.9 1465.7 N 26.80 W 33.6 N 2611.6 W 9025.0 8957.6 1485.9 N 26.40 W 51.8 N 2620.7 W Page 2 11/12/91 CLOSURE DISTNCE BEARING 2458.3 S 80.64 W 2462.1 S 81.07 W 2465.7 S 81.49 W 2469.3 S 81.92 W 2473.2 S 82.36 W 2477.3 S 82.79 W 2481.5 S 83.22 W 2485.9 S 83.65 W 2490.7 S 84.10 W 2495.8 S 84.52 W 2501.6 S 84.93 W 2508.1 S 85.35 W 2515.5 S 85.79 W 2521.8 S 86.17 W 2529.3 S 86.61 W 2536.2 S 86.99 W 2544.3 S 87.44 W 2552.0 S 87.87 W 2559.3 S 88.26 W 2567.1 S 88.67 W 2575.2 S 89.07 W 2583.1 S 89.45 W 2591.5 S 89.85 W 2600.0 N 89.77 W 2611.8 N 89.26 W 2621.2 N 88.87 W DL /lOO 0.40 3.34 1.02 2.08 2.56 1.05 0.51 1.37 0.97 5.85 3.17 3.61 0.65 2.10 1.19 1.35 2.56 1.62 2.05 0.65 2.47 4.02 0.88 0.85 1.05 0.80 ^Survey Codes: 3/MWD S-17A S MEAS INCLN C DEPTH ANGLE 3 9858 39.50 3 9924, 39.60 3 9956 39.60 3 10005 39.40 RECORD OF SURVEY (Calculated from a tie-in station at 8300 MD) VERTICAL-DEPTHS SECTION DIRECTION RELATIVE-COORDINATES BKB SUB-SEA DISTNCE BEARING FROM-WELL-HEAD 9046.6 9097.5 9122.2 9160.0 8979.2 1503.6 N 27.00 W 67.7 N 2628.7 W 9030.0 1545.3 N 25.30 W 105.4 N 2647.2 W 9054.7 1565.5 N 25.70 W 123.9 N 2656.0 W 9092.5 1596.4 N 25.80 W 151.9 N 2669.6 W ^Survey Codes: 3/MWD · Page 3 11/12/91 CLOSURE DL DISTNCE BEARING /100 2629.6 N 88.52 W 1.36 2649.3 N 87.72 W 1.65 N 87.33 W 0.80 2658.9 2673.9 N 86.74 W 0.43 S-17A SUBSEA MEAS DEPTH Page 4 11/12/91 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL (Calculated from a tie-in station at 8300 MD) INCLN TVD MD-TVD VERT DIRECTION RELATIVE COORDINATES DEPTH ANGLE BKB DIFF CRRT BEARING FROM WELL HEAD 7800 8421 7900 8533 8000 8645 8100 8757 8200 8872 27.48 7867 553 553 N 75.87 W 625.93 S 2247.23 W 27.13 7967 566 13 N 61.41 W 607.07 S 2295.05 W 26.48 8067 578 12 N 45.25 W 576.81 S 2335.23 W 28.04 8167 590 12 N 30.76 W 536.86 S 2365.94 W 31.91 8267 605 15 N 22.77 W 485.90 S 2390.13 W 8300 8993 8400 9117 8500 9243 8600 9370 8700 9499 8800 9627 8900 9755 9000 9885 35.46 8367 625 21 N 21.81 W 423.29 S 2416.37 W 36.95 8467 650 24 N 19.37 W 354.49 S 2442.17 W 37.46 8567 676 26 N 19.72 W 282.04 S 2468.09 W 39.09 8667 702 27 N 24.46 W 209.84 S 2496.86 W 39.12 8767 732 29 N 25.60 W 135.85 S 2531.37 W 37.75 8867 759 28 N 24.98 W 63.78 S 2564.54 W 39.70 8967 788 29 N 26.18 W 9.28 N 2599.47 W 39.54 9067 818 30 N 26.30 W 83.09 N 2636.43 W S-17A Page 5 DATA INTERPOLATED FOR 1000 FT MEASURED DEPTH INTERVAL 11/12/91 MEAS INCLN VERT-DEPTHS SECT DIRECTION REL-COORDINATES CLOSURE DEPTH ANGLE BKB SUB-S DIST BEARING FROM-WELLHEAD DIST BEARING DL/ 100 9000 35.73 8373 8306 981 N 21.60 W 10000 39.42 9156 9089 1593 N 25.79 W 419 S 149 N 2418 W 2454 S 80.16 W 4.2 2668 W 2672 N 86.80 W 0.4 .... E~UDHOE BAY oR'~-[~--~ Narker I~entifica~lon ~O N/S ~ K8 0 0 N ~ TN 10005 i52 N 2670 CLOSURE ..... : DECLINATION.: SCALE ....... ORANN ....... : S-17A PLAN VlEN 2674 ft N 86.74 30.00 E .'L inch = 500 feet ii/i2/91 1750- i§O0- 1250- 1000- 750- 500- S-i? LST 250- 500- 750- 1000- t250- i500- ORIGINAL ~ELL S-:~7 -2750 -2500 -2250 -2000 -i750 -i500 -i260 -iO00 -750 -500 -250 0 250 <- NEST: EAST -> HaPker Identification MD ]VO SECTN INCLN A] KOP 8300 776! 678 28.90 B] TD 10005 9t60 i596 39.40 7700- 7850- $-17A VERTICAL SECTION VIEW Section at: N 33.40 H TVD Scale.: t inch = 300 feet Dep Scale.: i inch: 300 feet Drawn ..... : it/12/9! Great Land DirectJona] Drillin# 8300- 8450- 8600- 8750- 8900- 9050- 9200- 9350- BSO0~ §650~ 7 LST S-~7A :L~O t500 t650 Section Departure 600 750 900 t050 t200 t800 t950 2t00 2250 2400 BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (9O7) 561-5111 DATE: 02/11/92 T# 83245 BP CASED HOLE FINALS. Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. N-21 ,CCL/PERF 02/05/92 #1 F-41ST ?/'/"¥PFC 02/07/92 #1 S-17A ~-I~ PRODUCTION LOG 02/05/92 #1 Y-23 ~,~ TEMP 02/04/92 ~1 Y-23 ? SPINNER 02/04/92 91 10670.00-11278.00 ATLAS 5 " 11200.00-11698.00 ATLAS 5 " 9550.00- 9821.00 SCH 5' " 2010.00-10950.00 SCH 2 " 10990.00-11350.00 SCH 5 " Information Control Well Records Adrian J. Martin RECEIVED FEE) 2 5 1992 Alaska Oil & Gas Cons. Commission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 BP MWD LOGS DATE: 02/06/92 T# 83240 Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. S-17LS~ 12/11/91 #1-2 2/5" S-17LS~ 12/10/91 #1-2 1! S-17LS~ ~ 12/10/91 #1-2 2/5" 7700.00- 9200.00 SPERRY 8200.00-10100.00 SPERRY 8200.00-10099.00 SPERRY Information Control Well Records Adrian J. Martin RECEIVED FEE] 12 1992 Alaska Oil & Gas Cons. Commission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 02/06/92 T# 83239 Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. S-17~S-T-- OH/LIS 8297.00-10099.00 API#500292114899 8414->TP# FIN 01/27/92 #1 SPERRY 1600BPI REF#910921 Information Control Well Records Adrian J. Martin RECEIVED FEB 1 2 1992 Alaska 0ii & Gas Cons. Commission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 01/16/92 T# 83187 BP CASED HOLE FINALS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. 07 TE P _~ ~-~ PROD-F 05~Z'~]~ GAS LIFT SURVEY 25 0 -~ ~ TEMP ~~ ~ ~n PITS ~~ ~] '~ PITS ~-17A~[~ GAS LIFT SURVEY ~~ ~I'Vb TEMP 5 " -2 4 JE~LRY 12/29/91 #1 12/26/91 #1 12/28/91 #1 12/26/91 #1 12/26/91 #1 12/30/91 #1 12/28/91 #1 12/25/91 #1 12/29/91 #1 12/30/91 #1 9800.00-11774.00 CAMCO 5 " 7580.00-10455.00 CAMCO 2 " 8500.00- 9462.00 CAMCO 5 " 2000.00-10229.00 CAMCO 2 " 350.00- 9467.00 CAMCO 2 " 8500.00-10200.00 CAMCO 2/5" 8500.00- 9462.00 CAMCO 5 " 2000.00- 9984.00 CAMCO 2 " 8700.00- 9740.00 CAMCO 5 " 8500.00-10200.00 CAMCO 12/28/91 #1 8500.00- 9462.00 CAMCO Information Control Well Records Adrian J. Martin RECEIVED JAN 2 2_ 1992 Alaska 011 & Gas Cons. C0mmission Anchorage J f ' BP EXPLORATION BP CASED HOLE FINALS BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. # -17A ~/ CL 10/19/91 #1 9400.00- 9978.00 SCH S-17A ~' COMPLETION 10/19/91 ~1 7940.00- 9946.00 SCH S-17A ~ CNL 10/19/91 #1 9400.00- 9978.00 SCH il 5 " 5 " Information Control Well Records Adrian J. Martin BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO' ARCO EXXON PHILLIPS STATE OF ALASKA ARCHIVES DATE :10/29/91 T#: 82957 SYSTEM T~pe & Transmittal Only ' BP MAGNETIC LI~ TAPE ~ LI~TIN(~ Enclosed is your copy of the matedal listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. 0~X. X%O'X. S-17A ~H/CNT-D/FIN 10/19/91:~ 1600BPI APl#50-029-2114801 #1 9338-10005.5 REF#75072 ~CH TP#8016 Alaska Oil & Gas Cons. gommissior, /:,,ncilorage Information Control Well Records LR 2-1 Adrian J. Martin ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 September 19, 1991 Karen M. Thomas Senior Technical Assistant BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Well No. Prudhoe Bay Unit S-17A Company BP Exploration (Alaska), Inc. Permit No. 91-119 Sur. Loc. 2204'SNL, 712'EWL, Sec. 35, T12N, R12E, UM Btmnhole Loc. 1985'SNL, 1776'WEL, Sec. 34, T12N, R12E, UM Dear Ms. Thomas: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill 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. The Commission will advise you of those BOPE tests that it wishes to witness. Alaska Oil and s Conservation Commission BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. . , - - STATE OF ALASKA AlaSKA ulL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrill Dllb. Type of well. Exploratory[] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen[-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration KBE = 67.48'feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pooi P. O. Box 196612. Anchoraae. Alaska 99519-~;612 ADL 4. Location of well at surface 7. Unit or property Name 111. Type Bond(see 2o AAC 25.o25) 2204' SNL, 712' EWL, SEC. 35, T12N, R12E Prudhoe Bay Unit At top of productive interval 8. Well number Number 2124' SNL, 1702' WEL, SEC. 34, T12N, R12E S-17A (32-34-12-12) 2S100302630-277 At total depth 9. Approximate spud date Amount 1985'SNL, 1776' WEL, SEC. 34, T12N, R12E September23, 1991 $200,000.00 12. Distance to nearest 113. Distance to nearest well 4. Number of acres in property15. Proposed depth(uDandTVO) p re pe~/~L line 28277 @ 1776' feet S-16 @ 2000'/104' feet 2560 9952'MD/9211 'TVD~e et 16. To be compJetecJ for deviated wells ,~',o/ 17. Anticipated pressure (see 20 AAC 2S.035 Kickoff depth '~$°°~me,feet Maximum hole angle~,r.~ Uax~murn surface 3330psig At total depth (TVD) 8800'/4390psig 18. Casing program ~ -b';'.,/-f,r-,.~W,,~w'~,~/~.~4,:.t'~.~. Setting Depth s~ze ~pec.TiCations' Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 20" Cond. 80' Surface 110' 110' 17-1/2" 13-3/8" 72# L-80 Butt 2633' Surface 2662' 2662' 4000 cuft Arcticset III & II 12-1/4" 9-5/8" 47# L-80 NSCC 9459' Surface ~ 9488' 8804' 2214 cu ft Class G 8-1/2" 7" 26# ~3c,~.8o FL 4S 2402' 7550' 7060' 9952' 9211' 558 cu ft Class G R FCE. i\!E 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 9940'feet Plugs (measured) "~ P '~ 3 true vertical 9201'feet .Alaska.OjJ & Gas Cons. C0mr~is Effective depth: measured 9800'feet Junk (measured) Perfgun @ 9762' Anchorage true vertical 9078'feet Casing Length Size Cemented Measured depth True Vertical depth Structural bkb C o n duct o r 110' 20"x30" 8 cu yds 139' 139' S u rface 2633' 13-3/8" 4000 cu fl 2662' 2662' Intermediate 9459' 9-5/8" 2214 cuft 9488' 8804' Production L i n e r 732' 7" 278 cuft 9208'-9940' 8558'-9201' Perforation depth: measured 9489;9525',(Sag R); 9633;9677', 9692;9726', 9741;9758' (Ivishak) true vertical 8738;8752' (Sag R); 8864;8974' (three ivishak intervals) 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth pict [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirementsl-] 21. I hereby ce,~y that the foregoing is true and correct to the best of my knowledge Signed ~ ,,~ __/,. ,,, (-/'/q.4 · ~-7/,,(.,¢h ~ ~ _ Title Senior TechnicalAssistant Date T,/~ ¢---" ~ .... Commission Use Only / Permit Number JAPInumber IApproval date See cover letter ~:/-////~ 150' ~'<~--~- ~-'//'~-~%-~/I ~"'t~'~/ for other requirements Conditions of'approval Samples required [] Yes .,1~NO Mud Icg required [-IYes/[~ No Hydrogen sulfide measures [] Yes ~ No Directional survey requ~recl '~ Yes [] No Required workin e for BO~3M; 1~5M; 1-11 OM; []15M; other: · by order of Approve Commissioner [ne commission Date F°rm 10'401 Rev. 12-1--85~~..,I Submit in tril ~ [On PRQPQSED RILLING AND COMPLETION WELL $-17A [32-~14-12-12] :iOGRAM CURRENT STATUS: S-17 is currently a producer in the S Pad region. The well has severe formation damage, and a redrill has been proposed. The well was drilled to 9940' in 1984. The 13-3/8" surface casing is set from surface to 2662', the 9-5/8" intermediate casing is set from surface to 9488', and the 7" liner is set from 9208' to 9940'. The well is completed with 4- 1/2" tubing and a 9-5/8" permanent packer with a 4-1/2" tailpipe assembly. The well contains a 21.5" perforation gun fish at 9762', sand fill from 9680' to 9800', which covers the lower two set of perforations, and a 33' tubing tail fish above the sand fill. PROPOSED PRE-RIG PROGRAM; (Operation to be Approved Under Sundry Notice) Rig up coiled tubing unit. Cement squeeze all existing perforations and leave 100' of cement above upper perforation at 9489'. Pressure test squeezed perforations to 2000 psi for 15 minutes. RU slickline unit. RIH and confirm cement top. RIH with coil tubing and spot 9.2 ppg brine from the cement top to 100' below 7" liner top. RIH with inflatable bridge plug and set 100' below 7" liner top. Spot cement plug from bridge plug to 50' above 9-5/8" production packer. RIH with jet cutter and cut 4-1/2" tubing above cement top. Circulate well over to seawater and freeze protect well to 2000'. Set 4" BPV. PROPOSED DRILLING PROGRAM: (Operations to be Approved Under Drilling Permit) The milling fluid program will consist of a 8.55 ppg gelled seawater system during the milling of the window. The drilling fluid program will consj.st of a e~ - 9.5 ppg ~,¢et, ef base mud in the 8-1/2" hole. P',¢'~ P~, #~v,~,vd.¢~.,.~.4,,,,,..~,, 8.~ -~.~ ~,'/ Install blowout prevention equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer. Maximum possible bottomhole pressure is 4390 psi at 8800' ~Dss based on original rese~oir pressure. Maximum possible sudace pressure is 3330 psi based on a gas column to sudace from 8600' ~Dss and an oil column to 8800' ~Dss. ' ~~ ~¢~ ~80 Pull 4-1/2" tubing. Set bridge plug below proposed se~ion. Sectional mill a 80' window in the 9-5/8" casing. Set cement plug from bridge plug to 100' above window, Dress off cement plug and kickoff through the window. Dire~ionaily ddll 8-1/2" hole to TD. Run 7" 13CR liner from TD to 250' inside 9-5/8" casing kickoff point and cement using Class G cement. PRqIPOSE£' ~RILLING AND COMPLETIOl~ _ WELL ~-17A [32-34-12-12] 'R(~GRAM Clean out to 7" float equipment. Change over to NaCI completion fluid. Test casing and lap to 3000 psi. Run 9-5/8" production packer on 4-1/2" 13CR tubing. Set packer 30' above top of 7" liner. A subsurface safety valve with dual control lines will be placed 100' below base of permafrost. Install and test Xmas tree. Displace tubing to diesel. Set and test packer. The well will be perforated after the dg as been released. Fluids incidental to the drilling of a well will be hauled away and pumped down CC-2A. Tubing Size: 4-1/2", 12.6# NT13CR-N80, TDS tubing with 5 GLM's. PRELIMINARY WELL PLAN Well: S-1 7 A [32-34-1 2-12] PBU LOCATION: Surface: 2204' SNL, 712' EWL, Sec. 35, T12N, R12E Target: 2124' SNL, 1702' WEL, Sec. 34, T12N, R12E T.D.: 1985' SNL, 1776' WEL, Sec. 34, T12N, R12E ESTIMATED START: September 23rd, 1991 OPR. DAYS TO COMPLETE: 14 (5 days milling, 4 days drilling, 5 days completion) CONTRACTOR: Nabors 2ES MAX ANGLE/SECT COURSE/KOP/BUILD RATE: 28.62/N 28.0 W/7800/6° item TVDss MD(BKB) Mud Wt.. 20" CONDUCTOR 13-3/8" SHOE -BASE WEST SAK FORMATION 9-5/8" SHOE TOP SAG RIVER SANDSTONE CURRENT GOC TOP SADLEROCHIT TARGET TOTAL DEPTH 110 N/A 2594 2662 N/A N/A N/A N/A 8736 9488 N/A 8593 9324 9.0 N/A N/A 9.0 8724 9473 9.0 8855 9623 9.0 9144 9952 9.0 LOGGING PROGRAM: O[~en Hole - Record all logs on magnetic tape where applicable. 8-1/2" Hole: DGR/EWR/CNE~/SFD Cased Hole Gyro survey after rig release. MUD WEIGHT WELL $-17A CALCULATIONS (32-34-12-131 Mud Wt. (8-1/2" Hole): 9.0 P Sag River: P Sadlerochit: P Top Sadlerochit: ' OB Sag River: OB Top Sadlerochit: Current GOC: Top Sag River Top Sadlerochit PPg- 3800 psi. 3600 psi. at 8800' TVDSS 3573 psi. 222 psi. 518 psi. N/A 8660' TVDBKB 8791' TVDBKB Cement Calculations 7" LINER Measured Depth: Basis: Total Cement Vol: 7550' (Hanger) - 9952' (Shoe) 1.5 X Annular volume to KOP + 100 cu ft 558 (cu ft) 480 Sx Neat G @ 1.1 6 Cu ft/Sk ANNULAR PREVENTER 7 PIPE RAMS , 6 BLIND5 RAMS ) DRILLING SPOOL TUBING HEAD 2 1.13-3/8" CASING HEAD 2. 5000 PSI TUBING HEAD 3. 13-5'8" - 5000 PSI PIPE RAM~ 4. 5000 P!31 DRILLING SPOOL 5. 13-5/8' - 5000 PSI BLIND P, AM~ $. 13-5r8' . 5000 PSI PIPE RAM~ 7. 13-5'8' - 5(X30 PSI ANNUl. AR ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMU. ATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE AU. UNITS SIMULTANEOUSLY AND RECORD THE TilVE AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUM= OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECOND~ CLOSING TIME AND 1200 PS1 REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIF~ WITH ARCTIC DIESEL IN W1NTER OR SEAWATER DURING SUMMER MONTHS. 2. CHECK THAT ALL HOLD-[X~WN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEFTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COMP(::3~iENTS TO 250 PSi AND HOLD FOR 10 MINUTES. 5. INCREASE PRESSURE TO 2500 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. ' 6. OPEN AM~t. AR PFIEVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 5<XX~ PS1 AND HOLD FOR 10 MINUI~S. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESE~URE TO ZERO PSi TO TEST VALVES. TEST REMAINING UNTESTED MANI~ VALVES, IF ANY, WITH 5000 PSI UPSTREAM OF VALVE AND WITH ZERO PS100VVNS'rRF_AI~ BLEED SYSTEM TO ZERO PSI. 9. OPEN PIPE ~. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAM~ AND TEST TO 5000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10. OPEN BUND RAM~ AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 5000 PSI. 12. TEST KELLY COCKS AND INSII:~_ BOP TO 5000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BI.~ PREVENTER TEST FORM. $.G.~ AND SEND TO DRILLING SUPERVISOI=L 14. ~M CO~ BOP TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY FOR DRILLING OPERATIONS. FOR COMPLETIC.~ WORKOVER OPERAT1ON~, PERFORM COMPLET~ BOP TEST EVERY 21 DAYS AND FUNCTION TEST BOP WEEK].Y. DAM 11/20/89 BOP SCH (FOR: NAB 2ES) ..... ,4: p.: ~.L ,_: ~;__-. ', .... ! .... I ...... i'~:.i..: : ........................ i ................. Pr(UDHOE BAY DRILL.:ING~ ; i, S-PAl) 5600 5200 4~o . ~.~ ..... ~p?. ....... ~ : 6800 ........ ~ ...... I-- 3600 5200 5600 0000- 5200 :i:: .i; ............... i ...... 4600 4400- 4000 3600' 3200- 2800- :. 5200 , 6000 2000- -o~; : ! ,i : ' i ~ :' ! 1600- ~ .... :"1 .... : ' :' '"i ''. ".:.",: ~oo- . ': : ! 8oo- ' : ' i 400 ..... : : : ' ' : i I .......... -; .--:.-. ~.- : .... :'::. i i ~oo. : ;: , I :"1 ' ' '':': ..... i ,,~ ! : · i '.- i 1600' ' ;' · : ~ i :. ! :. ~000' : ' i !,.-:} .... ~ ........ ! " i ,i'. ~" t' ':i': :(':"~': 2400' i. ', '~ · , : :. · : · i ,. :~ :. i' .,: .~ ',. t ~:...2 ;.. . . :.;:[...: . , ~, l' : .... S:O0- ': '" ..... " ..... : : :' :'::i' : :: .... :;' - .; , {'"I { ........... : : ' ......................... i I ~ ~ I : : ' : 'J:' ' : 6400- : : ,, , : : I ' : ' .... t ' ' '6800 ', :' i :"; ....... t' ::~:':"~:- ~ ' ' 7~00. t ' ' : : : : '' :' : ~":'' :":I '/; :": ::: ~600- i ' :.: .~ . ;::: .: '... :.. :¢ :~ .... :.. :. :..: / : :._:::. ~ ' , ,;. ; ,;:~ ::;I :;'t:::,: 9~00 ...................{ ............ x t .......t ......... t--- :----I ....... 5600 5200 4800 4400 4000 :1oo0 3,°00 28})0 [ 2400 , [ : / $-1~ 0 3~.i.~B ~0 6' 0 .................... -800 k'~~-11'G ' ' '! ......... : 1200 . ' i' ' ............. 1600 · ..~ ................ t200~ .... ~ · : ..... 2800 -3200 -3600 5200 5600 1-6000 '2200 -1600 -8000 ........ 6400 .... ! .... I -- - : ..... 6800 ~l---I--+----I- --~-------t- .... t ' I ' 9~00 3800 4000 4400 4000 5200 5600 8000 8400 6800 7200 NAB~RS RIG NO, 2ES M!O SOLIDS CONTR.OL..EQUIPMENT 2 - Contir~ental Emsco Fl000 Mud Pumps 1 - Derrick FioLins Cleaner Shale Shaker 1 - Mud Cleaner 1 - DRECO Gss Buster 1 - Pioneer Sidewinder Mud Hopper 1 - 5 HP Flash Mixer Agitator 3 - Abcor 10 H P Agitators 1 - 50 bbl. Trip Tank 1 - Recordi,n,g frilling fluid p. it level indicator with both visual and audio warning devices at driller's console. 1 - Drilling fluid flow sensor with readout at driller's console RECEIVED SEP Z ? 1991 DEPTH DENSITY PV yp ~NT 10MIN FL OIL SOLIDS MUD ('i'VD) (PPG) (CP) (#/FT)GEL GEL cc/30min (%) (%) TYPE 0' 9.0 15 8 4 8 8 0 to to to to to to to 8300' 9.6 20 30 30 40 10 4 Gel to Water 8 Mud 8300' 8.8 10 8 3 6 2 80 5 Oil to to to to to to to to to Base t 0106' 9.0 18 12 8 12 4 90 6 Mud RE(EIVED HO L.DIN G T.R~ mMm e~. 'T~G ~S NABORS 2ES MUD PIT SYSTEM Trip Tank 55 BBLS PIT #1 170 BBLS PIT #2 175 BBLS PIT #3 180 BBLS Pill Tank 60 BBLS SLI~-, .",~CF_'*~.OLE DIVERTER SYSTEM-. .... ~ Two lines venting 90 deg. apart in directions that ensure safe down wind venting, and ex- tending to a point at least 100' from any' potential""" source of ignition. 10' Full Opening Valves -35' ar as required Dresser Sleeve · 1. All pipe connections 150¢ ANSI Ranges or welded connections and secured to prevent movemenL 2. Manual 10' full opening valves mechanically connected to ensure that one valve is fail-sale open at all limes. 10' Diverter Une 3. All lures are 90 deg. and targeted. 10' Full opening ball valve w/Hydraulic Actuator Cellar 20' Diverter Spool w/10' Side Outlet M EM 1/'5/'90 BAY ORZL'LZNG S-~7 REDRILL 8300 PLAN VIEU ~ i ...................................... ~lWWl iiii i i CLOSURE ' 24~8 f~ 277.5~ DECL~NATZO~' 30.00 $CAL~ ....... : ! ~nch ~ 600 feet KOP -- -- .... -- ____.~L~- ..................................... P.3 i~lllr, i ....... I , , 8400',- PRUOHOE 8AY DRILLING ! t S-!7 REORILL 8300 KOP VERTICAL SECTION VIE~ TVO Scale.: ~ inch ~ ~00 feel: Oep Scale.: ! .inch = 1~00 feel: l~'e~n .... ' 09/t7/9~ C 94,~0 ' ~ ': ' ' 0 ;~0 400 600 800 ~1000 Section Departure $45DUA247:[DRAN033]S17 CLOSAP SHORT.LIS;2 Search Radius= 200 COURSE LINE For proposed well: S-17 [34-34-12-12] Location = W-E S-N TVD(SBS) Top 618885.00 5979279.00 -35.00 Bottom 616470.58 5979320.01 8856.00 Note: Ail depths in feet Below Kelly Bushing (BKB) 9-SEP-1991 16:47 Closest Approach Analysis Date: 9-SEP-91 Time: 16:46:53 Page 1 Closest Approach WELL IDENT /PROPOSEDk /NEARBYk CLOSEST TVD DEPART TVD DEPART DISTANCE A029-2069800 S-2 A029-2077100 S-9 A029-2077800 S-8 A029-2095900 S-4 A029-2111300 S-15 A029-2112300 S-16 A029-2114800 S-17 A029-2115600 S-18 A029-2161100 S-19 A029-2163700 S-20 A029--2205700 S-27 A029-2208200 S-29 ( A029-2209500 S-28 2335.0 0.0 2390.3 172.4 463.4 NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW 3128.0 40.8 3197.0 275.8 2266.2 0.0 2299.9 9.9 1967.8 0 .0 1999 .9 6.5 0.0 0.0 32.5 0.1 0.0 0.0 40.2 0.0 2700.0 0.0 2757.6 182.0 475 8 212 9 103 6 0 1 110 0 436 7 NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW 2899.7 8.7 2949.8 532.7 385.6 NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW 4594.1 603.2 4808.0 977.6 483.1 SUMMARY The well which comes closest to the proposed well is: Closest approach distance = KICK OFF for this run = 0.1 feet 2700.0 feet Vertical Intersection /PROPOSEDk /NEARBY~ VERTICAL TVD DEPART TVD DEPART DISTANCE 6177.7 1270.8 9126.5 1724.2 2909.8 2700.0 0.0 0.0 0.0 -2732.5 3232.5 63.3 4606.1 838.4 1343.7 TREE: 4" ClWS-17KB. ELEV = 67.5 WELLHEAD: 13-3/8" McEVOY BF, ELEV = 38,83 ACTUATOR: OTIS ...... - ~==...._.: (OTIS 4-1/2 DBE) ' CMl"d- ~ ~ (3.813" ID) 13-3/8", 72#/ft I I-- 1 k, GAS LIFT MANDRELS L-80 BTRS 2662 [OTIS LBO W/RA LATCH) N~.i MD(BKBI TVDss I I 4 3915 3798 I KOP: 2700 ,, I 3 6949 6477 I MAX ANGLE: 29' ii 2 7882 7328 ,;i [ 1 8957 8269 ; 4-1/2", 12.75#/It, L-80, . TUB,N ,D: 3.958- ! OTIS XA 9072 ----'--- ( 3.813" MIN. ID) ' '--!-- 4-1/2", 12.75#/ft, L-80 TAILPIPE ~ Iz J (OTIS) (3.013" ID) 9201 7" LINER I il ~---' 4-1/2" CUTTAILPIPE J 9230 J 9-5/8"' 47#//t' I I L-80, BTRS 9488 -- J k (ELMD) J 9226 PERFORATION SUMMARY /[~S~AG 35'TAILPIPE CUT REF: LOG: BHCS DROPPED 8/16/00 SIzE SPF INTERVAL OPEN/SQZ'D 3-3/8 6 9489-9525 3-1/8 4 9633-9677 = IVISHAK 3-1/2 4 9692-9726 COVERED ~.%J%.%.%.%. ,- ,~,~,~,~,~.~, 't'~[~ FISH: 21.5' Oearha~ 3-1/8" HCS pod gun ~.{~X{{g~{ -9762' MD 11-11-85 PBTD I o oo I i DATE REV. BY , COMMENTS pRUDHOE BAY UNII 8-20-84 ROCHIN COMPLETED WELL:S-17{33~34,12-12) 9-29-89 PGS PUT ON MAC Apl NO: ~0-Q29-2114~, " ~EC 351T12N; RG12E 0/15~0 PRH CUT TP. 8~1/91 REVISED BP Exploration (Alaska) I GAS LIFT MANDRELS OTIS LBD W/RA LATCH) N~, MD(BKB) TVDs, 4 3915 3798 3 6949 6477 2 7882 7328 1 8957 8269 TO: THRU: MEMORANDUM State of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION Lonnie C. Smi~/ DATE: August 9,1991 Commis s ioner FILE NO: DA. 10 8- 2 TELEPHONE NO: SUBJECT: BOP Test BPX PBU S-17A Permit No. 91-119 Prudhoe Oil Pool FROM: Doug Am~ Petroleum Inspector Sunday:Sept, ~,1.~91: I traveled this date from BPX PBU F- Pad to well S-17A to witness the BOP test on Nabors Rig 2ES. The testing commenced at 4:30 pm and was concluded at 9:00 pm. As the Attached AOGCC BOP test repQ~t indicates there were no equipment failures, however th~' t~t'"plug leaked through out the entire test. We exhausted two hours of the four and half hours of test time verifying that the test plug was the cause of a slow and consistent pressure bleed off which occurred during each component test. Ralph Olson AAI's representative assured me that the csg spool would be replaced to elevate this problem on future test. I was completely satisfied that the test plug and not the BOP equipment was ~e source of the reoccurring bleed off ~. test. through out th~ In summary, I w nesses ~he BOP test at BPX PBU S-17A well on Nabors Rig N~'~ES. There were no equipment failures during this test~ however the test plug did bleed pressure through out the '~tire test. Steps were taken to replace the csg spool which will correct this problem on any future test. Attachment. ~<~ 02-00lA (Rev. 6/89) 20/11/MEMO1.PM3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION BOP Test Report DATE OPERATION: Drlg. ~/ Wkvr TES,T: Initial__ Weekly I? Other Operator ~)X Representative Location: Sec ~G T. tZ/~. R I Z~M ~.,.~, ~U Casing Drlg contrctr ...... ~A'~~5 R~g~ Z~ Rep ~iS Location (general) ~ Well sign 1~'~ ACCUMULATOR SYSTEM: Housekeeping (general) ~ Rig, ,~/'~' Full charge pressure Reserve pft ~./ Press after closure MUD SYSTEMS: Visual Audio p tank ~- J ,, ~,f Tri I Pit gauge ~, j ~/ Flow monitor ,/ J Pump tncr clos press 200 psig Full charge press attained N2 ¢- ,Z ZeO Controls: Master ~ Remote / B1 pslg pstg mtn :2.~' sec min 44~ sec pstgL, ~ ,, ind switch cover Gas detectors ,~ J i/" KELLY AND FLOOR SAFETY VALVES: Upper Kelly / Test pressure BO~E STACK: Test Pressure Lower Kelly I Test pressure Annular preventer ~ ~;~0~ , Ball type ,~!., , Test pressure Pipe rams ~'~ ~ ~,ODO Inside BOP ~'/ Test pressure ~"' / q Choke manifold I Test pressure Blind rams ~ . Choke line valves .... ~ ~ Number valves HCR valve ~(~ ~ I/ Number flanges Kill line valves~k~ t( Adjustable chokes / Check valve ~ Hydraulically operated choke TEST RESULTS: Failures /~/~/~ Test time ~ 7~ hrs [I /! J/ IIIi Repair or replacement of failed equipment to be made within ~ days. Notify the Inspector, and follow with written/FAXed verification to Commission office. Distribution: ortg - AOGCC c - Operator c - Supervisor C.004 (rev 07/08/91) WITNESS ITEM (1) Fee (2) Loc APPROVE DATE · thru YES NO REMARKS 1. Is permit fee attached ............................................... /~ ,, · (3) Admin [ 15] [10 & 13] (4) Casg ~ ,~-/~B-~/, [14 thru 22] [23 thru 28] (6) Other /~[2/P th u' TI] ' (6) Addl geo 1 ogy' eng i nee r ing .~ DWq~ MTM~ LCS?' ~>~i' RPC,~., BEW / RAD ' ~ JH~//--7~ ~ ! 2. Is well to be located in a defined pool ............................... 3. Is well located proper distance from property line ................... 4. Is, well located proper distance from other wells ..................... 5. Is sufficient undedicated acreage available in this pool ............. 6. Is well to be deviated & is wellbore plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ · 9. Does operator have a bond in force ................................... 10. Is a conservation order needed ....................................... 11. Is administrative approval needed .................................... 12. Is lease nLrnber appropriate .......................................... 13. Does well have a unique name & nLrnber ................................ 14. Is conductor string provided ......................................... 15. 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 & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30 31 32. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams $ descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to,5-O~ psig ..... Does choke manifold comp'ly w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones. If offshore loc, are survey results of seabed conditions presented... Additional requirements ............................................. I'NITIAL GEO1 "UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE ,. ,/ rev 03/29/91 jo/6.011 0 .-~ Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. ****************************** ~OV 0 5 1991 Alaska 0il a ~cas Cons. Commissio~ IS Tape Verification Listing Chlumber~er AlasKa Computing Center 25-0CT-1991 13:02 **** REEL HEADMR **** SERVICE NAME : EDIT DATE : 91/10/25 OPlG~N ~ FLIC REEL NAME : 75072 CONTINUATION # pREVIOUS CON~ENT : BP EXPLORATION,PRUDHOE BA¥,$-iTA-2,500292114801 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 91/10/25 ORIGIN : FbIC TAPE NAME : 75072 CONTINUATION # ~ 1 PREVIOUS TAPE ~ COMMENT : BP EXPbORATION,PRUD~OE 8AY,$-I7A-2,50029~I~480! TAPE HEADER PRUDHOE BAY UNIT CASED MOLE WlRELINE bOGS WELL NAME: API NUMBER: OPERATOR: LOGOING COMPANY: TAPE CREATION DATE: JOB ~UMBER: LOGGING ENGINEER: OPERA.TOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGM: FNL: FSb: FEb: ELEVATION(ET FROM MSL O) KELLY BUSMING~ DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD SURFACE LOCATION dST STRING 2ND STRING 3RD STRING PRODUCTION STRING 500292114B01 BP EXPLORATION SCHLUMBERGER WELL SERVICES 25-0CT-9! 75072 G, JOHNSON M, CHAMBERS ~ O~ 67.50 66,00 ~5~00 OPEN MOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT C[.B/FT) ~:'';'''''''25 '''''''''9. 625 ''''':''''$ 300 0 '':;;'''''''''47 8.500 7,000 10060.0 26,00 IS Tape verlficatloD Listlnq 25-0CT-~.99~ i3:02 cblumberqer Alaska Computinq Center CURYE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: PBU CURVE CODE: LOGGING COMPANY: ----------EQUIVALENT Ii,SHIFTED DEPTH---------- mASELINE DEPTH $ REMAPKS: THE CASED HOLE DATA WAS NOT SHIFTED TO AN OPEN HOLE STANDARD PER SHAwN SMI~ZADI, $ $ PAGE: FIL~ NA~E : EDIT ,001 S~RVICE : FLIC VERSION : 001A06 DAT~ MAX REC SIZE : FILE TYPE : LO LAST FIDE : FILE ~EADER FILE NUMBER) 1 EDITED CURVES Depth shifted and clipped curve~ for each pass ~n separate ~iles, pASS NUMBER{ 1 D~PT~ INCREMENT 0.5000 FILE SUmmARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 9990.0 9394,0 CNTD 10003,.0 9394.0 $ CURVE SHIFT DATA - PASS TO PASS(~ASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: PASS MUNBER: RF~RKS: BASELINE D~:PTH THIS FILE CONTAINS THE FIRST PASS OF T}.{E CNTD. THERE WEE NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. ----------E(}U I V AL[:N T UNSFi'IFTED GRCH CNTD IS Tape Ver]~f~,cation Listina chlumherqer AlasKa Computina Center $ FORMAT DATA 25-aCT-1991 13:02 PAGE~ ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** ?YPE R R ¥ ,~ 1 66 2 66 0 3 73 40 4 66 1 5 66 6 73 7 65 9 ~5 11 66 25 1~ 68 13 66 0 14 65 FT 15 66 68 6 66 1 66 0 ** SET TYPE - CHAN ** NAME SMRV UNIT SERVICE APl API API API FILE NUmB NUmB SIZE RMPR PROCESS ID ORDER # LOG TYP~ CbASS ~OD NUMB SAMP ELE~ CODE CHEX) DEPT FT 4.25261 O0 000 O0 0 1 i I 4 68 NPH! C'NTD PU-S 425261 O0 000 O0 0 1 I 1 4 68 NRAT CNTD 425261 O0 000 00 0 1 ~ 1 4 68 CRAT CNTD 425~61 O0 000 O0 0 I I 1 4 68 NCNT CNTD CPS 425261 O0 000 O0 0 1 1 I 4 68 FCN~ CNTD CPS 425~61 O0 000 O0 0 ! 1 ! 4 68 CNTC CNTD CPS 425261 O0 000 O0 0 1 I ! 4 68 CFTC CNTD CPS 425261 O0 000 O0 0 ! 1 1 4 68 GRCH CNTD GAPI 425261 O0 000 O0 0 i I I 4 68 T~NS CNTD LB 425261 O0 000 O0 0 I I 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** BATA ** DFPT 10003,000 NPHI'CNTD 18,667 NCNT:CNTD .4526,054 FCNT.CNTD 1290.323 GRCH.CNTD -999.250 TENS..CNTD 1155,000 NRAT,CNTD CNTC,CNTD 3.508 CRAT,CNTD 4350,000 CFTC.CNTD 3,574 1215.200 IS Tape Verification Listlnq ~hlUmberoer Alaska Computino Center 25-OCT-1. ggl 13:02 PAGE: DEPT. 10000.000 NCMT.CNTD 4546.638 G~C~.CNTD -999,250 DEPT. 9900.000 NCNT.CMTD 4204.126 G~C~.CNTD 9,875 DFPT. 9800.000 NCNT.CMTD 4323 366 GRCH.CNTD 27~172 DFPT 9700,000 NCNT]CNTD 3837,104 GPCM.CNTD !6,047 DEPT, 9600.000 NCNT.CNTD 7450.110 GRC~.CNTD 43,875 D~PT. 9500 000 NCNT.CNTD 6281:995 G~C~.C~TD 33,219 D~PT 9394 000 2 277 G~C~.CL'TD 67.563 NPMI.C~TD FCNT,CNTD TENS,CMTD NPHI.CNTD FCMT.CNTD TENS.CNTD NPHI.CNTD FCNT,CNTD TENS.CNTD NPHI,CMTD FCNT'CNTD TEN$,CMTD NPMI,CNTD FCMT,CMTD TEN$.C~TD T,C~T~ TENS,C~TD NP~I,C~TD FCNT,CNTD TENS,CWTD 18.670 HRAT.CNTD 3.589 1294.900 CMTC,CNTD 4438.183 1160.000 24 446 NRAT.CNTD 4.069 1027~686 CMTC.CNT~ 4042.009 1455.000 20,259 NRAT.CNTD 3.714 C~!TC,CNTD 4094.502 5~7 I :ooo 25,679 N~AT,CNTD 4 375 869,762 C~TC,CNTD 3737]713 {420,000 ~ 1.30 NRAT.CNTD 2 021 3455[!49 CNTC.CNTD 6984]266 ~440,000 13,905 NRAT.CMTD 2,614 2536,806 CNTC,CNTD 5973.137 14iO,O00 38 761 MRAT,CNTD 5.917 434!389 CMTC.CNTD 2507.820 1370 000 CRAT.CNTD CFTC.CMTD CRAT.CNTD CFTC.CNTD CRAT.CNTD CFTC.CNTD CRAT.CNTD CFTC.CNTD CRAT.CNTD CFTC.CNTD CR~T.CNTD CFTC,CNTD CRAT.CNTD CFTC.CNTD 3.574 1241.954 4 346 928~386 3,788 1063,198 4.506 818.820 3133:909 2.9~8 2188.022 **** FILE TRAILE~ **** FILM NA~E : ~DIT ,001 SERVICE : FL!C VERSIOn! ~ 001&06 D~TF : 91/10/~5 M~X REC SIZE : 1024 FIL~ TYPE : LO L~ST FILE : **** FILE HEADER **** FILM NAME : EDIT .002 SFRVICE ! FLIC VERSION : 001~06 D~TE : 91110125 ~× R~C SIZE : 1.024 FILF TYPE ~ LO LAST FILE % I$ Ta~.e Verification chlumberoer ~las~a Computln~ Center 25-0CT-1991 13:02 PAGE{ FILF HEADER FILE NUMBER~ 2 EDITED CURVES Depth shifted and cl~pped curves for each pass ~n separate files, DFpTN YNCREMENT 0.5000 FTLE SUMMARY PBU TOOL CODE START DEPTM STOP DEPTH -.........-.. .... .;.--..... ~RC~ 9989. 394,0 CNTD 10002.0 9394.0 S CURVE SHIFT DATA - PASS TG PASSfMEASURED DEPTH) ~ASELINE CURVE FOR SHIFTS PBU CURVE CODE: ~ASELINE DEPTH ;~;i;'''''''9968 0 9945 0 9937 9918 9918 9914 9855 9844 9844 98~9 9801 9782 9762 9760 9726 970] 9677 9647 9616 9612 9591 9587 9539 9501 9459 5 9434:0 9433.5 9430 0 94~425 100,0 GRC~ 1 ----------~QUIVALEMT UNSHIFTKD DEPTH---------- GRCH 9918.0 9855.5 9844.0 9800.5 9782,0 9762,5 9726,0 9703,0 9647.0 9616,0 961~,0 9590,5 9587,0 9539.5 950~.,0 9459,5 9432.5 9414.5 1.00,0 CNTD 88888 0 9945.0 9938.0 99t8,0 9914,5 9844.0 9819,0 9759 9678 0 9647]0 9434,0 9429.5 90.5 IS Tape Verlflcatlon List{Dq cblumber~er Al. asEa ComputIpg CeDter 25-0CT-1991 1,3:0~ RFMAPKS: TUIS FIbE CONTAINS THE SECOND PASS OF THE CNTD. TME DEPTH ADJUSTMENT SHOWN ABOVE REFLECT PASS 2 GR TO PASS 1 GR AND PASS 2 NPHI TO PASS 1 NPHI, LIS FORMAT DATA PAGE: ** Q~TA FORMAT SPECIFICATION ~ECDRD ** ** SET TYPE - 64EB ** TYPE REPP CODE VALUE ~ 66 0 2 66 0 3 73 40 4 66 ~ 5 66 6 73 7 65 8 68 0 5 1~ 66 25 13 66 0 14 65 FT ~5 66 68 16 66 1 0 66 I ** SET TYPE - CMAM ** NAMM SERV lIMIT SERVICM APl ~PI APl APl FILE NUMB NUMB SIZE REPR PROCESS ID ORDER ~ bOG TYPE CHASM ~OD NUmB SAMP EbE~ CODE (~EX) DEPT FT 425261 O0 000 O0 0 2 t I 4 68 NPHI CNTD PU-$ 425261 O0 000 O0 0 2 I I 4 68 NRAT CNTD 425261 O0 000 O0 0 2 I 1 4 68 C~AT CNTD 425261 O0 000 O0 0 2 1 1 4 68 NCNT CMTD CPS 425261 O0 000 O0 0 2 ~ 1 4 68 FCNT CNTD CPS 425261 O0 000 O0 0 2 ! I 4 68 G~CH CNTD G~PI 425261 O0 000 O0 0 2 1 1 4 68 CNTC CNTD CPS 425261 O0 000 O0 0 ~ 1 1 4 68 CFTC CNTD CPS 425261 O0 000 O0 0 2 1 t 4 68 TENS CNTD hR 42526~ O0 000 O0 0 2 ~ 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** D~TA ** IS Tape Verification I~isting chlUmberger Alaska Con, Dutino Ce.ret DFPT. 10002.000 NCNT.CNTD 4586.319 CFTC.CNTD 1209.945 F, PT. IOOCO 000 ~CNT, .CNTD 4511i931 CFTC.CNTD 1185 !18 D~PT. 9900.000 NCNT,CNTD 4275.250 CFTC,CNTD 979.492 D~PT. 9800,000 NCNT,CNTD 4291,125 CrTC.CNTD 1165.563 D~PT, 9700 000 NCN~.C~TD 3986i500 CFTC.CNTD 871 000 DEPT, 9~00.000 NCNT,CNTD 7379,157 CFTC.CNT~ 3213.016 D~PT 9500,000 NCNT~CNTD 6~36,9~7 CFTC.CNTD 2136,840 D~PT., ~394,000 NCNT,CNTD 2589,800 CFTC,CNTO 392,451 E~D OF DATA FCMT.CNTD TENS.CNTD MP~I.CNTD FCMT.CNTD TEM$.CNTD NPHI.CNTD FCNT.CNTD TE~S.CNTD NP~I.CNTD FCNT,CNTD TENS.CNTD MPHI,CNTD FCNT.CNTD TENS.CNTD NPMI CNTD TEN$.CNTD NPHI CNTD FCNT~CNT~ TENS,CNTD ~P~I CNTD FCNT:CNTD TE~$.CNTD **** FILE FIL~ NAM~ : EDIT .002 SfRVICE : FSIC VFR$ION : 00~A06 D~T~ : 91110125 ~AX REC SIZE : FILF TYPE : LO LAST FILE 25-0CT-1991 13:02 19.126 1272,844 1115.000 19.786 1292 242 1105~000 22 934 1035i688 1443 ~13 18,1o6 1200.000 1414.781 24,0~6 909.875 1392,305 7 862 3533~409 1400,000 i4,5~3 1355 O0 40,735 416,761 1325,000 NRAT.CNTD GRCH.CMTD NRAT.CNTD GRCH.CMTD NRAT,CMTD GRCH.CMTD NRAT.CNTD GRCH,CNTD NRAT CMTD GRCH:CNTD NRAT,CNTD GRCH.CNTD NRAT,CNTD GRCH,CNTD NRAT,CNTD GRCH,CNTD 3,609 -999.250 3.553 -999.250 15,141 3.561 28.875 1.990 3~.500 2..719 37.3!3 7~: 087 000 CRAT.CNTD CNTC.CNTD CRAT,CNTD CNTC.CNTD CRAT.CNTD CNTC,CNTD CRAT.CNTD CNTC.CNTD CRAT.CNTD CNTC.CNTD CRAT..CNTD CNTC.CNTD CRAT.CNTD CNTC,CNTD CRAT,CNTD CNTC,CNTD PAGE: 3.635 4394.754 3.724 4376.495 4 147 4097:875 3 498 4095:000 4 ~97 3829:250 2,098 6977.377 °'° 633 ~273 245:129 IS Tape Verification I~istina chlum~er~er AlasKa Co~vuttn~. Center 25-~CT-199~ 13:02 PAGE: **** FILE HEADER **** FILE NAME : EDIT .003 SFRVICE : FLIC V~RSION : O0~.A06 DaTE : 91/10/25 EL× REC STZE : 1024 FILE TYPE : LO LaST FILE ~ FILE HEADER FILE NUMBER: 3 EDITED CURVES - DePth shifted and Cl{DDed curves for each 3 O.50O0 PASS NUMBER: DEPTH INCREMENT FILE SUmmARY ~BU TOOL CODE C~TD START DEPTH !000.1.,0 STOP DEPTH 9394,0 9394,0 C RVE SHIFT DATA PASS TO PASS(~EASURED DEPTH) ~ASELINE CURVE FOR SHIFTS PBU CURVE CODEI gRCH BASELINE DEPT~ 88888.0 9968.5 9945 0 . 992~,5 99],8.5 9844.5 9844 0 9828:5 9824,0 9807 5 9802 0 9797 5 9796 5 9782 5 9776 5 9703 5 9693 5 9687,0 9682,0 9669.0 9668,5 9918,5 9844,0 ----------EQUIVALENT UNSHIFTED DEPTH----'----- GRCH CNTD ~8888.0 88887.5 9968..0 9945.0 992~15 9918.0 9844,0 9828,0 9824,0 9807.0 9801,5 9797,5 9795,5 9782,0 9776,5 9703,0 9668.5 9693.0 9686'5 9681.0 9669,0 £S Ta~e Veri~lcatlom Listin~ ~hlUmberqer ~las~a Com~utin~ Center 25-0CT-1991 1]:02 9647.5 9647,0 9616,5 9616,0 9615,5 9606,5 96o6,5 9595,0 9595,0 9591,0 9590,5 9576,0 9574.0 9566,5 9562,0 9540.5 9540,0 9528,0 9528.0 9513,0 951~,5 9512.0 9498,5 9478,5 9460,0 9459,5 9450,0 9~3~,0 9431,0 9422,0 94!,8,5 9415,0 9414,5 9408,5 940B.5 9407,5 ~00,0 100.0 $ 9615,5 9573:0 9565,S 956~,5 951~.5 9498,~ 9478,0 9449 5 9432'0 94~,,5 9417,5 9407,5 100.0 THIS FILE CONTAINS T~ THIRD PASS OF THE CNTD, THE DEPTH ADJUSTMENTS SHOWN ABOVE REFLECT PASS 3 GR TO PASS 1 GR AND PASS 3 NPHI TO PASS 1 NPHI, $ LIS FORMAT DATA PAGE: ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB..** TYPE REPR CODE VALUE 2 66 0 3 73 40 5 66 6 73 7 65 8 68 0,5 9 65 FT 11 66 25 IS Tame Verfflcat].on Llstinq cblumber~er Alaska Computtna Center 25-OCT-199~ 13:02 PAGE: 10 TYPE REPR CODE VALUE 13 66 0 14 65 FI 15 66 68 i6 66 1 0 66 *$ SET TYPE - ..,.............,.,.................-..-...-.-...-----.-.--------,,---.-------,----.--- N_ME SERV UNI.. ERVICE AP1 AP1 AP] APl FILE NUmB NUMB $ E REPR P OCESS ORDER # LOG TYPE CLASS ~OD NUMB SAMP ELEM CODE '''''''''''''''''''~'~i''''''';'''''''''''''''''''''''''''''''''''''''''''''''''''~;''D~PT FT 4 2 00 0 O0 0 3 1 1 4 6* 00000000 NPgI CNTD PU-S 425261 00 000 O0 0 ] 1 1 4 68 0000000000 NRAT CNTD 425261 00 000 O0 0 ] 1 1 CRAT CNTD 42526{ O0 000 00 0 3 1 ~C~T C~TD CPS ~25261 00 000 00 0 3 FCNT CNTD CPS 425261 00 000 O0 0 ] 1 1 G~C~ CNTD GAPI 425261 O0 000 00 0 CNTC CNTD CPS 425261 00 000 00 0 ~ ! 1 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 DEPT, 10001.000 NPMI,CNTD 17,~88 N~AT,CNTD 3 39! CRAT.CNTD NCNT,CNTD 4645,161 FCNT,CNTD 136~, 27 GRC}~,CNTD -999]~50 CNTC,CNTD CVTC,CNTD ~2~9,3~2 TENSiCNTD 108 ,000 DEPT 10000,000 NPHI CNTD 1~.988 NRAT,CNTD , 3 646 CRAT.CNTD NCNT~CNTD 4666,666 FCNT~CNTD 1~5 ,056 GRCH,CNTD 999~50 CNTC'CNTD CFTC:CNTD !230,420 TEN$.C~TD !~05,000 D~PT 9900,~00 NP"I.CNTD 24 ~4 NR~T.CNTD 4.036 CRAT CNTD ~C~T'C~TD 4221, 29 FCNT.,C~TD 1013~.5 GRC~.CNTD 9.~58 C~TC:CNTD CFT~]CNT[) 9~.9,597 TENS,CNTD !430,000 D~PT 9800 000 NPHI,C rD 22 034 NRAT.CN'rD 4,042 CRAT NTD NCNT.CNTD 4298,063 FCNT,CNTD ~052 219 GgCH,CNTD 26,888 CNTC NTD CFTC,CNTD {.006,250 TENS,CNTD 1396 ~50 DFPT. 9700,000 ~!PHI,CNTD 25,.461 NRAT,CNTD 4,574 CRAT.CNTD NCNT CNTD 3817.000 FCNT,CNTD 839,625 GRC~,C~TD 2~.~41 CNTC,CNTD CFTC]CNTD 811,063 TENS,C~TD 1356,250 DEPT 9600,000 NPHI,CNTD 8,730 NRAT,CNTD 2.126 CRAT,CNTD NC~'." N~"CNTD, . 77~9,139 FCNT,CNTD 3460,929 GRCH,CNTD 36,344 CNTC,CNTD CFTC,CNTD 3150,2~.7 TENS,CNTD ~385,000 3,455 4438.199 3.617 4442.383 399X, 4'026 4098,500 4.4?8 3714,375 2,2i8 7{9'7,716 IS Ta~.e Verification List~n~ ch].umheraer Alaska Compt]t{nq Center 25-0CT-199I 13{02 11 D~PT 9500,000 NPHI.C~TD 16 028 NRAT,CNTC CNT~CNTD 6226 000 FCNT.CNTD 2075~000 GRC~,CNTD CFTC.CNTD !976,000 TEN$.CNTD 1335' 539 DEPT, 9394.000 ~PHI,CNTD 35,495 MRAT,CNTD NCNT.CNTD 2589.800 FCNT.CNTD 434,851 GRCH,CNTD CFTC.CNTD 406,563 TENS.C~TD 1315,000 3.157 CRAT.CNTD 38.594 CNTC,CNTD 5.750 CRAT.CNTD 66.375 CNTC.CNTD 3,216 5919.500 .: 6 028 2461:700 END OF DATA **** FILE TRAILER **** F!LF NAME :MDIT .003 SMRVICE VERSION : O0~A06 DATE MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** FILE HEADER **** FILM NA~E ~ EDIT ,004 S~RVICE : FLIC VERSION ~ 001A06 DAT~ ~ 9~/10/~5 ~aX REC SIZE ~ 1024 FILE TYPE : LO FIL. E HEADER FILF. NUMBER: 4 EDITED CURVES Depth shifted and cl~,~ped curves for each pass ~n separate files, PASS gliBBER: 4 DMPTH IMCREgEMT 0.5000 # FIL~ SUMMARY PBU TOOL CODE START DEPTH ~'''''''''''CH '''''''''''9990.0 CNTQ 10003,0 $ C{~RVE SHIFT DATA - PASS T© PASSf~EASUR~D DEPTH) RASELIME CURVE FOR SHIFTS PBU CURVE COOE: GRC~ PASS NUMBER: 1. STOP DEPTH 9394,0 IS Tape Verification L~$tin~ :hlumberqer AlasKa Com~utlnq Center 25-0CT-~991 13:02 PAGE~ 9844, 9800, 9767. 9748, 9740 9727! 9725 9722, 9703, 9673. 9646 9616 9581 9570 9566 9561 9552 9539 9526 9510 9498 9498 9479 9450 9449 9436 9433 9432 9422 9418 9418 9414, 9407, 100,0 S ASELINE DEP?H 88.0 9968.0 o 94~5 9876,0 9854,5 9853,5 0 5 0 5 0 0 0 0 0 5 0 5 0 0 5 0 5 5 0 5 5 0 5 5 # ' T . - ....... --EQUIVAL~.N.. ONSHIFTED ~RCH CNTD 88888.5 88888.0 9968.0 9918.5 9918,0 9894,0 9876,0 9855.0 9854,0 9844,0 9800.5 9767,0 9748.0 9741,0 9727,0 97~6,0 9721.5 970],0 9673,5 9646.5 9616,0 9581,0 9570,5 9566,0 9561'5 9552,0 9540,0 9525,5 9510,5 9498.5 9498,0 9480,0 9450,0 9449.5 9437,0 9433,0 9432,0 9422.0 94t9.0 9417,5 9414.5 9409,0 10!.5 99.5 TMIS FILE CONTAINS THE FOURTH DEPTH ADJUSTMENTS SHOWN ABOVE 1 GR ~ND PASS 4 NPHI TO PASS $ FORMAT DATA DEPTH---------- PASS OF TME CNTD, THE REFLECT PASS 4 ~R TO PASS NPHI. IS Ta~e Ueriflcatlon Llstln~ Cblumberqer AlasRa Comp~]tino. Center 25-0CT-%991 13:02 PAGE{ 13 DATA FORk, AT SPECIFICATION RECORD SET TY '''''''''''''''''''''''''''R ~ D VALUE 6~ 0 3 73 40 4 66 5 66 6 73 7 65 8 68 0 5 11 66 25 12 68 I] 66 0 14 65 FT 15 66 68 16 66 ! 0 66 ** SET TYPE - CHA~ ** NAiF $~RV UNIT SERVICE APi API API API FILE NUmB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS ~OD NUmB SAMP ~LE~ CODE (HEX) DFPT FT 425261 00 000 00 0 4 I I 4 68 0000000000 NPH! CNTD PU-S 425261 O0 000 O0 0 4 {,, 1 4 68 0000000000 NRAT CNTD 425261 00 000 00 0 4 1 i 4 68 0000000000 C~AT CNTD 425261 00 000 O0 0 4 1 1 4 68 0000000000 NCNT CNTD CPS 425261 00 000 00 0 4 ~ 1 4 68 0000000000 FCNW CNTD CPS 425261 00 000 00 0 4 1 1 4 68 0000000000 G~C~ CNTD GAPI 425261 O0 000 O0 0 4 1 1 4 68 0000000000 CNTC CNTO CPS 42 5261 00 000 00 0 4 1 i 4 68 0000000000 CFTC CNTD CPS 425261 00 000 00 0 4 ~. I 4 68 0000000000 T~N~ CNTD LB 425261 00 000 00 0 4 i 1 4 68 0000000000. DATA DEPT. 10003,000 NPHI.C~TD 19.133 NRAT,CNTD 3.569 CRAT.CNTD NCNT,CNTD 4499.394 FCNT,CNTD 1~60.606 GRCH,CNTD -999,~50 CNTC.CNTD CFTC.CNTD 1187.214 T~NS.CNTD 1075,000 DRPT. 10000,000 NPHI'CNTD 19.594 NRAT.CNTD 3.562 NCNT.CNTD 4581.345 FCNT.CNTD 1294.900 GRCH.CNTD -999.250 CFTC.CNTD 1193.67~ TENS.CNTD 1080.000 C~AT.CNTD CNTC,CNTD 4317.022 3.698 4,390.943 I8 Ta~e Verification chlumberQer Alaska Computing Center 25-0CT-1991 13:02 PAGE{ i4 NCNT.CNTD 4186,252 FCN C~TD CrTC,CNTD 946'313 TEN CNTD DFPT. 9800,000 NPHI,CNTD NCNT CNTD 4287,929 FCNT,CNTD CWTC~CNTD 1040,559 TENS'CNTD D~PT 9700 000 NPHI,CNTD NCNT'CNTD 3857~500 FCMT,CNTD CFTC]CNTD 861.625 TENS,CNTD D~PT. ~600i000 NP~I.CNTD ~CNT,CNTD .3,5 000 FC~T.CNTD C~TC.CNTD 31~3 500 TEN$'CN,D D~PTo 9500 000 NPNI CNTD ~C~T.CNTD 6305i775 FC~T:CNTD CFTC.CNTD ~207 I16 TEN$oCNTD DEPT, 9394,000 NPHI,CNTD NCNT.CNTQ ~6~5,277 FCNT'CNTD CFTC,CNTD 400,876 TENS.CNTD 23.78] NRAT.CNTD 992 248 G~CH,CNTD 21,{28 NRAT,CNTD 1099,778 GRCH.CNTD 1410.000 2~ 759 NRAT,CNTD 897:125 GRCH,C~TD 1.350,000 7 822 NRAT.CNTD 3414!7501373 063 GRCH,CNTD 13,9~4 NRAT.CNTD 25~8 686 GRCM,CNTD 1330:000 ' 434, 9 GRCH NTD 1360.000 4,179 13,582 3,871 28,047 4,265 20,031 1.987 33,438 2 691 6,000 63,~8! CRAT,CNTD CNTC.CNTD CRAT.CNTD CNTC.CNTD CRAT.CNTD CNTC,CNTD CRAT,CNTD CNTC.CNTD CRAT.CNTD CNTC.CNTD CRAT,CNTD CNTC,CNTD 4,259 4024,955 3,903 4139.903 4,256 37!7,125 END OF DATA F~L~ NAME : EDIT ,004 S~RVICE : FLIC V~SlON : O01A06 DAT~ : 91/10/25 ~AX REC SIZE FIL~ TYPE I LO LAST FILE FILE NAME { EDIT .005 $~R¥ICE { FRTC V~RSION : 00lA06 M~X REC SIZE ~ ~024 FILF TYPE ~ LO FILE HEADER FILE NUmBeR: AvE~AGBD CURVES IS Tape Verification L~stina chlU~,berqer AlasKa ComputJ. nq Center 25-0CT-1.99~. ~3:02 PA~E~ 1 5 Compensated Neutron: Arithmetic average of edited passes for all curves, Pulsed seutronl Unaveraged edited Pass I oamma faf and bacKround counts; arithmetic average of edited static baseline passes for all other curves, D~PTH INCREMENT 0,5000 PASSES INCLUDED IN ~VERAGE PBU TOOL CODE PASS NUMBERS ~, 2,34, CNTD $ REM~RKS~ THIS FILE CONTAINS TH~ ARITHMETIC AVERAGE OF 2, 3, & 4, THE AVERAGING WAS PERFORMED AFTER ADjIJST~E~}TS WERE APPLIED, $ LIS FORMAT DATA PASSES ALL DEPTH ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE J 66 0 2 66 0 3 73 4O 4 66 5 66 6 73 7 65 8 68 ~ 5 ll 66 ~5 1~ 68 i] 66 0 14 65 FT 15 66 68 16 66 0 66 I ** SET TYPE - CHAN *~ N~ S~RV UNIT SERVICK APl APl AP1 AP1 FILE NUMB NUmB SIZE REPR PROCE88 ID ORDKR # LOG TYPE CLASS MOD NUmB SAMP ELEM CODE (HEX) DEPT FT 42526) 00 000 00 0 5 ! { 4 68 0000000000 NPH) CNAV P[]-S 425261 O0 000 O0 0 5 ! i 4 68 0000000000 N~AT CNAV 425261 O0 000 O0 0 5 1 I 4 68 0000000000 CRAT CNAV 425261 O0 000 O0 0 5 1 1 4 68 0000000000 NC~{T CNAV CPS 425261 O0 000 OO 0 5 1 1 4 68 0000000000 IS Ta~e Veri. t~.cati, on bisttno ~hlumberoer AlaSKa Con'~putln~e Center 25-0CT-199! 13:02 PAGE: ID ORDER # bOG TYPE CbAG$ MOD NUmB SAMP EbEM CODE (HEX) CMTC CNAV CPS 425261 O0 000 O00 S ~ ~ 4 68 0000000000 c~c c~v c~ .~~ oo ooo ooo ~ ~ ~ ~ ~ oooooooooo ~,c. c~v~,, ~s~ oo ooo ooo ~ ~ ~ ~ ~ oooooooooo .~5~.E~I~ ~ 4~~ oo ooo ooo ~ ~ I ! ~ ~~ooo 16 ** DATA DEPT. NCNT.CN~V GRCH.CNAV DEPT. NCNT.CNAV G~CM.CNA¥ NCNT.CN~V GRCH,C~AV DEPT. NCNT.CNAV DMPT, MCNT,CMA¥ GRCH.CN~V DEPT, GRC~.CN~V D~PT, NCNT.CMAV G~CH.CNAV DEPT. MC~)T.CNAV GRCW.CNAV 10002.000 NPHI.CNAV -999,250 NRAT,CNAV -999.250 CRAT.CNAV -999,~50 FCNT,CMAV -999.250 CMTC,CNAV -999.250 CFTC.CNAV -999,250 TEN$.CNAV -999,~50 10000.000 NPHi'"CNAV 19 260 NRAT.CNAV 3.587 CRAT.CNAV 4576.646 FCNT.CNA¥ 1285:025 CNTC.CNAV 4412.O0~ CFTC.CNAV ]212'791 TENS.CNAV 1112' 500 · 9900 000 NP.. I CNAV 23,797 NR~T.CNAV 4.091 CRAT CNAV 42~1:840 FCNT.CNAV 10~7,~99 CNTC.CMAV 4039.048 CFTC~CNA¥ ]1.964 TEN$.CMAV 1434,70~ 4300-~1 FCNT,C~AV 111 78 CNTC.CNAV 4~06.977 CFTC.CNA¥ ~7~945 TENS.CNAV 141~:~008 700.000 NPMI'CNA¥ 24 ~41 NRAT.CNAV 4.358 CRAT.CNA¥ ~874'5~6 FCNT*CMAV 879:97 CNTC.CMAV 3749.616 CFTC.CNAV ~9.50~ TENS,CNAV ~387,~39 9600,000 NPHI'CNAV 8.~36 NRAT.CNAV ~.03] CRAT.CNAV 7465.852 FCNT,CMAV 3466,060 CNTC.CNAV 7018.090 CFTC.CNAV )8,039 TEN$.CNA¥ ~399.516 9500.000 NPHI.CNAV 14,587 MRAT,CNAV 2.795 CRAT..CNAV 6262'689 FCNT.CNAV 2399,78I CNTC,CNAV 5936.418 CFTC.CNAV 40.313 TEN$.CNAV 1357,635 9394.000 NPHI,CNA¥ 3~,511 N~AT,CNA¥ 5,938 CRAT,CNA¥ ~607.539 FCNT*CNAV 43 ~05 CNTC,CNAV 2454.523 CFTC.CNA¥ 67.055 TEN$.CNAV 1342~: 500 ** END OF DATA ** -999.250 -999.250 4,26X 943'447 31.804 ~06B.B92 4,384 840,6~7 .2,136 3155,161 6,139 403,679 IS Tape verification Listing chlu~beroer Alaska Computlno Center 25-0CT-1991 13:02 PAGEs 17 SERvIcE ! FLIC V~RSION : 001A06 DATF : 91/10/25 ~AX R~C S!Z~ ~ 1074 FILF TYPE : I.,O L~ST FILE : **** FILE HEADER FTLE NA~E ~ ~DIT .006 SFRVICE : FLTC V~SION : O0]A06 DaT~ ~ 91/10/25 MaX REC SIZE ~ i024 FILF TYPE : LO L~ST FI!.,E FILF NU~BER 6 Curves and lo~ header data for each Pass in separate ~iles~ raw background pass ~n last f~le PASS NUMBER DFPTH INCREMENT: -.5000 # FILF SUmmARY VENDOR TOOL CODE START DEPTH CN .TD LOG N~ADER DATA DATE LOGGED: SOFTWARE VERSION~ '7~' TI~E LOGGE~ ON BOTT[ : TD DRILLER (FT): TD LOGGE~(FT): TOP LOG INTERVAL (FT): ~OTTO~ LOG INTERVAL (FT): LOGGING SPEED DEPTH CONTROL USED (YES/NO): STOP DEPTH 9394,0 TOOL STRING (TOP TO BOTTOm) VEMDO~ TOOL CODE TOOL TYPE C~TD COLLAR LOCATOR CNTD LOGGING SOURCE CNTD COMP. NMUTRON CART, C~ID TELMMFTRY CARTRIDGE CMTD TELMMETPY MODUL~ CP 32.4 945 9984.0 9981..0 9400,0 9978,0 1800,0 19-OCT'91 TOOL NUgBER CAL-UB 299 NSR-LA 3039 CNC-DA 146 ATC-CB 115~ AT~-AA 374 IS Tare Verification List{ha ChlumEer~er Alaska Comput~nq CeDter 25-OCT-!ggl 13:02 BOPEMOLE A~D CASINO DATA OPFN HOLE BIT SIZF (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH B[]RF[~OLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTO~ HOLE TEMPERATURE (DEGF): FLUID SALINITY FLUID LEVEL FLUID RAT~ AT WELLHEAD WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): ~ATRIX: ~ATRIX~ DENSITY: H~LE CORRECTION (IN): NORMALIZATION WINDOW START DEPT~ STOP DEPTH (FT): AMOUNT: 8.500 ~0060.0 SEAWATER SANDSTONE 2.65 GAS SCALING FACTOR FOR NEAR AND FAR COUNTS: NULTIPLIER: TOOL STANDOFF (IN): ~E~ARKS: TIED INTO g '~' ~PE~RY NWD DUAL GA~A RAY DATED 10/11/91 ~ELL NOT PERFORATED WELLHEAD PReSSUrE: 1~50 PSIA FLUIDS IN WELL GAS LIFTED DO~N TO 5230' $ LIS FORMAT DATA PAGE: 18 ** PATA FO~AT. .. SP,~CIFICATIONE RECORD ** ** SET TYPE - 64E~ ** 1 66 0 2 66 0 3 7~ 44 4 66 5 66 Center 25'0CT-i 991 ? 73 8 65 g 68 ~! 65 0.5 ~2 66 FT 14 66 16 66 FT 0 66 68 13:02 DEPT.. ReNT.pS! 1~005.500 G~,p$1 4526, 54 RCFT,ps! 18.667 I290.323 CNTC, ps~ 3.508 .D~PT RC~?:pS.! 10000,000 ~pHi,p$1 18,670 ~C~T.pS! 4204. 126 0.000 1027.686 1455~000 CCL,PS! 4042.00§ D~pT. 9800.000 NpNt,p$! 20.259 RTNR,ps1 0.000 NA~ · ~ S~v u~ ,,,,,,,--,............ "'''----..--'"~ ~ LOc ~v.a _~PI Pr ~''_''''--.. _ ~s~ ~zs~ oo ooo oo ~ ~ ~ ~ ooco, p ooo DS{' CPS {}~261 O0 000 Od 0 ~ I i 4 ~ i ~ ooo ~' CPS ~2526i O0 000 O0 ~ 4 ~ O00D() 000 "~ GAPI i2~261 ~ ,4 Psi S! 000 O0 0 1 i 4 ~ O00i)O ~ ( )00 oo ooo ""-----. · .... ~ ooo(,0 ~ ~oo '"'"'""'----L 2 ooo o ,oo ~'- ~ O00c 01 0000 19 200 ,. NOV 0 5 1991 Alaska Oil & Gas Cons. Commission Anchorage IS Tane Veri{l. cation bist~na Chlumberoer Alaska Computing Center DEPT. 9700.000 ~CNT.PS1 3837.104 G~.PS~ 16,047 MPHI.PSI RCFT,PS1 TENS.PSi NPHI.PS1 mCFT.PSl TE~$.PS! RCFT.P$! NPHI PSi RCFT:PS1 TE~S,PS! NPHI,PSi gCFT.PS! TENS.PS1 DEPT. 9600,000 RCNT,PS1 7450.110 G~,PSl 43,875 DEPT. 9500 000 RCNT.PSl 6281:995 G~.PS1 33'219 DEPT, 9400,000 RCNT.PS1 24~2,4~7 G~.PS1 62,031 D~PT. 9390.500 RCNT.PSI 2551.495 G~.PSI 64.000 25-0CT-1991 13:02 25,679 RTNR,PS1 869 762 CNTC,PS! 1420:000 CCh,PS1 8 ~30 .RTNR,P$i 3455!149 CNTC.PS1 1440 000 CCL,PS1 13,905 RTNR.PSl 2536.806 CNTC,PS1 1410,000 CCL,DS1 42,957 RTNR,PS! 36~ 401 CNTC,PS~ 1~80:000 CCL.PS! 40 040 RTNR,PS1 425i72! CNTC,P$1 1380 000 CCL.PSl 4~375 TNRA.D$1 3737.713 CFTC.PSi 0.000 2.0~1 TNRA.PS1 6984.266 CFTC.PS1 0,000 ~.614 TNRA.PSi 5973,137 CFTC.PS1 0.000 6.800 TNRA.PS! 2428,09g CFTC.PS1 0.000 6.167 T~RA.PS! 2449,998 CFTC.PS1 0.000 PAGE{ 20 s° 8 o 2.135 3133,909 2,928 2188,022 6,Lii 375,393 6,198 4O3.542 ~*~* FILE TRAILER ~**~ FILE NA~E : EDIT .006 SERVICE { FLIC DATF : 9i/10/~5 ~AX REC SIZE : 10~4 F!LF TYPE ~ LO LAST FILE : **$~ FILE H'EADFR mmm$ FTLE ~A~E = EDIT ,007 SFRVICE ~ FLIC V~RSIOM : 001A06 D~TF ~ 91/I0/25 ~X REC SIZE ~ 10~4 FTL~ TYPE : LO LAST FILE : FILE ~E~DER R~W CURVES C~rves and Io0 header data PASS NU~BER~ 2 D~PTH INC~E~NT: -.50~0 FIL~ SU~RY for each Pass in separate file:s; raw background pass in last IS Ta~e verlf~.cattop ;,istlnq chlumberqer Al. aska Comput, lnq Cemter 25-OCT-1991 13:02 PAGE: VENDOR TOOL CODE START DEPTH CNTD 10002.0 DATE LOGGED: SOFTWARE VERSION: . TI~E LOGGER ON BOTTOM: TD DRILLER TD LOGGER(ET): mop LO~ INTERVAL · ~OTTOM LOG INTERVAL fFT): LOGGING SPEED DEPT~ CONTROL USED (YES/NO): STOP DEPTM 9394,0 TOOL ST~ING (TOP TO BOTTOm) VKNDO~ TOOL CODE TOOL TYPE CMTD COLt, AR LOCATOR CNTD LOGGING SOURCE CNTD COMP. NE~TRON CART, C'NTD TELEmETrY ~ARTRIDGE C~TD TELEmETrY MODULE BOREBOLE AMD CASING DATA DRILLERS CASING DEPTH (ET): LOGGERS CASING BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEgPERATURE (DEGF): BOTTO~ HOLE TEMPERATURE (DEGF): FLUID SALINITY FLUID L~VEL (ET): FLUID RATE AT WELLHEAD ~TER CUTS GAS/OiL RATIO: CNOKE NEUTRON TOOL TOOL TYPE (EPITHERMAh OR TNMRMAL)I ~ATRIX DENSITY: HOLE CORRECTION (IN): NORMALIZATION WINDOW START DEPTH STOP DEPTH A~OUNT: CAS SCALING FACTOR FOR NEAR AND FAR COIINTS~ MULTIPLIER: 19-0CT-9~ CP ]~.4 945 !9-OCT-91 9984,0 9951.0 9400.0 9978,~ 1800,0 NO NUMBER NSR-bA 3039 CNC-DA 146 ATC-CB ~152 ATE-AA 374 5OO SANDSTONE 2,65 IS Tape vertficat~oD Listin~ cblumberqer AlasKa ComDutin~_ CeDter 25-OCT-1991 13:02 PAGE: 22 TOOL STANDOFF PE~ARKS: TIED TNTO SPERRY ~wD DUAL GAMMA RAY DATED 10/11/91 wELL NOT PERFORATED WELLHEAD PRESSURE: ~250 PSIA FLUIDS IN WELL GAS LIFTED DOWN TO 5230' $ LIS FORgAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE R~P. COD~ VALUE I 66 2 66 0 3 73 44 4 66 5 66 6 73 7 65 8 68 0~5 9 65 F ii 66 12 68 1] 66 0 !4 65 FT 15 66 68 16 66 0 66 ** SET TYPE - CMAN ** NAME SERV UNIT SERVICE API APl API API FILE NUmB NUMB SIZE REPR PROCESS ID ORDER # bOG TYPE CLASS ~OD NUMB SAMP EbEM ,CODE (HEX) D~PT FT 425261 O0 000 O0 0 7 1 t 4 68 NPHT PS2 PU 42526~ O0 000 O0 0 7 1 1 4 68 RTNR PS2 425261 00 000 00 0 7 I I 4 68 TNR~ PS2 425261 O0 O00 O0 0 7 1 I 4 68 RCNT PS2 CPS 425261 00 000 O0 0 7 I I 4 68 RCFT PS2 CPS 425261 O0 000 00 0 7 1 1 4 68 CNTC PS2 CPS 425261 00 000 00 0 7 ! 1 4 68 CfTC PS2 CPS '425261 O0 000 O0 0 7 1 1 4 68 G~ PS~ GAPI 425261 00 000 00 0 7 I 1 4 68 T~N~ PS2 b~ 425261 O0 000 O0 0 7 1 1 4 68 CCL pS2 V 425261 00 000 00 0 7 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 IS WaDe Verification Listlnq chlUmheroer A].a$~a ComDut~nq Center 25-DCT-1991 13:0~ PAGE: 23 ~m~mmmmm~#mmmm~mmmmmm$mmmmmmmmm~mmmmmmmmmmmm~mmmmmmmmmmmmmmmm#mmmmmmmmmmmmmmmmmmm~mmmmm ** DAT~ ** D~PT 10005.500 NPHI.PS2 19 182 RTNR.PS2 3.576 RCNT~PS2 4571,429 RCFT.PS2 1278~450 CN?C,PS2 4386.137 CFTC.PS2 G~.PS2 1@.203 TENS.PS2 995.000 CCL,PS2 0.000 DEPT 10000,000 NPHI.PS2 19.786 RTNR'PS2 3 553 TNRA.P$2 RCNT~P$2 451i,931 ~CFT.P$2 i29~.242 CNTC,P$2 4376i495 CFTC.PS% G~,PS2 18.203 TENS.PS2 1105'000 CCL,PS2 0 000 DEPT. 9900.000 NPHIoPS2 2~.833 RTNR,P$~ ~000 TNRA,PS2 RCN?.PS~ 4257,206 ~C~T,PB2 1045 404 CNTC'PS~ 407 318 CFTC.PS~ GP.PS2 15.~.09 TENS,PS2 1435:000 CCD'PS2 0.000 DFPW 9800,000 NPHI,PS2 18,023 RTNR,PS2 ~ 902 TNRA.PS2 RCNT~PS~ 4323.366 ~CFT.PS2 108~,040 CNTC,P$2 411 ~198 CFTC.P$~ GR.PS2 25,766 TENS,PS2 1410.000 CCS,PS2 0,000 DEPT. 9700,000 NPHI,PS2 24 27$ RTNR,PS2 4,375 TNRA.PS2 RCN~.PS~ ]~62,6B0 RCFT.P$2 B69:76~ C~TC,P$2 3773.?~7 CFTC.~S2 I 9o.ooo cc' .ps2 o.ooo DFPT. 9600,000 NPffI.PS2 ? ~ RTNR~PS2 I 990 TNRA.P82 RCNT PS2 7379,157 RCFT,PS2 3533.! 9 CNTC,P$2 6977~377 CFTC,PS~ G~:PS2 35,656 TENS.PS2 1400_O00 CC5.,PS2 0.000 DFPT 9500,000 NP~I'PS2 14 5~3 RTN~,PS2 2.719 TNRA.PS2 RCNT:PS~ 6236.9~7 RCFT,PS2 2465:6 2 CNTC,PS2 5920,633 CFTC.PS~ RCNT:PS~ ~51e:847 ~CFT,P$2 442. 68 CNTC,PS2 2479 926 CFTC.PS~ G~,PS2 59,906 TENSORS2 1340.000 CCD'PS2 0 000 DMPT 9389.500 NPHI,PS2 39,~53 RTNR'PS2 6. 087 TMRA.PS~ RCNT:PS~ 2767,184 RCFT,PS2 407. 30 CNTC~PS2 2500:469 CFTC G~.PS2 64,000 TENS.PS2 1340,000 CCh. PS2 0,000 ** END OF DATA ** 3.643 1204.019 118 118 97 706 3,487 1179,612 ]24 · 016 ].olo 2136,840 6'519 381,056 6,155 409,510 **** FILE FIL~ NAME SERVICE VKRSION DAT~ MaX REC SIZE FIL~ TYPE 'LAST FILE TRAILER **** : EDIT .007 : FLIC : 001A06 : 01/i0/~5 : 1024 : LO iS ?ape ver'~.~ication chlUmber~er Alaska Computing. Center 25-0CT-!991. 13:02 PAGE~ 24 **** FILE HEADER **** FILM NA~E : EDIT ,008 SERVICE : FLIC V~R~IOM ~ O01h06 DAT~ : O1/10/25 MAX REC SIZF : 1024 FILF TYPE : LO L~ST FILE : FILE NUMBER 7 RAW CURVES Curves and lo~ header data ~or each Dass 1~ ~eDarate ~lles; raw bac~oround ~ass in last PASS NUMBER: 3 DEPTH INCREMENT: -,5000 FILF SUMMARY VENDOR TOOL CODE START DEPTH CNTD. 10001,0 HEADER DATA STOP DEPTH 9394,0 DATE LOGGED: SOFTWARE VERSION: · TIME LOGGER ON BOTTOM: TD D~iLbER (FT): ~O LOGGE~(FT)~ TOP LOG INTERVAL (FT): BOTTO~ LOG INTERVAL fFT): LOGGING..SPEED DEPTH CONTROL USED (YES/NO): TOOL STRING. (TOP TO BOTTOM) VENDOR TOOL COD~ TOOL TYPE CNTD COLLAR LOCATOR CNTD LOGGING SOURCE CNTD COMP, NEUTRON CART, CWTD TELEMETRY CARTRIDGE CMTD TELEMETRY MODULE BOREHOLE AMD C~SING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING D~PTH (FT): LOGGERS CASING DEPTH ~OREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATUR~ (DEGF): BOTTO~ MOLE TEMPERATURE (DE~F): 19-0CT-91 CP 32.4 945 9984 0 9981~0 9400,0 9978.0 1BO0,O NO 9-OCT-91 CAL-UB 299 NSR-bA 3039 CNC-DA 146 ATC-CB 1152 ATE-AA 374 5O0 to 6o.o SEAWATER IS Ta~e verification l~tst,[nq chlumberqer AlasZa Computl. nfl Center 25-flCT-!991 13:02 FLUTD SALINITY (PP~): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD WATER CUTS GAS/OIL RATIO: CHOKE (DEG)~ NEUTRON TOOL TOOL TYPE (~PITHERMAL OR THERMAL): ~TRIX: SANDSTONE ~ATRIX DENSITY: 2.65 HOLE CORRECTION (IN): NORMALIZATION WINDOW START DEPTH (FT): STOP DEPTH (FT): AMOUNT: ~AS SCALING FACTOR FOR NEAR AND FAR COUNTS~ ~ULTIPLIER: TOOL STANDOFF ~E~ARKS: TIED INTO SPERRY ~WD DUAL GA~A RAY DATED 10/11/91 WELL NOT P~RFORATED WELLHEAD PRESSURE= 1250 PSIA FLUIDS IN W~LL GAS LIFTED DOWN TO 5230' $ LIS FORMAT DATA PAGE: ~5 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VhLUE 1 66 0 2 66 0 3 73 44 4 66 1. 5 66 6 73 7 65 B 68 0 ~ 9 65 F~ 11 66 ~3 1~ 68 13 66 0 14 65 FT ~5 66 68 16 66 I I$ Ta.~e verification Listin~ chlUr~berqer Alaska Computing Center 991 !3:02 26 ** SET TYPE - C~AM ** ..... ~mm.m.mmmmmm.mm.mmm.mmm~mmm.mm.mm.m'--m,~ ..... mmm...m..mm.m.mmmmmmm..m.m..m.mmmmm--.--m NA. F S~RV U~IT SERVICE API AP) API ~PI FILE NUMB NRROCEUMB SIZE R~P P 88 ID ORDER ~ LOG TYPE CLASS ~OD MU~B $A~P EhEM CODE (HEX) D~PT F 425261 O0 000 O0 0 8 I I 4 6 0 0000000 NPH! PS3 PI! 425261 O0 000 O0 0 8 1 I 4 68 0000000000 RTNP PS3 425261 00 000 00 0 8 1 1 4 68 0000000000 TNR~ PS3 425261 00 000 00 0 8 ~ ! 4 68 0000000000 RCNT P$3 CPS 425261 00 000 00 0 8 i 1 4 68 0000000000 RCFT PS3 CPS 425261 00 000 O0 0 8 ! ! 4 68 0000000000 CNTC PS3 CPS 4~5261 00 000 O0 0 8 1 1 4 68 0000000000 C~TC P$3 CPS 425261 00 000 00 0 8 1 I 4 68 0000000000 G~ PS3 GAPI 425261 00 000 00 0 8 ! 1 4 68 0000000000 T~NS PS3 LB 425~61 00 000 00 0 8 1 1 4 68 0000000000 CCh PS3 V 425261 O0 000 00 0 8 1 1 4 68 0000000000 ** DAT~ ** I)EPT 10004,000 NPHI.PS3 17,788 RTNR,PS3 3.391 TNRA.PS3 RCNTiPS3 4645,16! ~CFT.P$3 1369.727 CNTC,PS3 4456.881 CFTC,PS3 GP.P$3 18,656 TENS,PS3 915,000 CCL,PS3 0.000 D~PT I ~000~0,000 NPMI,PS3 19 ~77 RTNR,PS~ 3.613 TNRA.PS3 RCNT:PS3 .~63 ,734 RCFT,PS3 1~91:667 CMTC,PS3 446!,797 CFTC.PS3 G~.PS3 ~8,656 TENS,~83 1085.O00 CCh,P83 0.000 RCNTiPS3 4167,610 RCFT,P83 9~0,13~ CNTC,PS3 403 82- CFTC.PS3 GP.PS3 9.258 TEN'$.PS3 1420,000 CCh,PS3 61 000 RCNT;PS3 4257.206 RCFT,PS3 1!3~.998 CNTC,PS3 416 55! CFTC.PS3 G~.PS3 26,719 TENS,PS3 1400.000 CCL,PS3 ~:000 D~PT. 9700.000 NPMI.PS3 24,770 RTNR,PS3 4.~00 TNRA.P83 RCNT.PS3 3945.70i RCFT.PS3 906,002 CMTC.P83 3788,690 CFTC.PS, G~ PS3,.. 21.313 TENS.~PS3 1370,000 CCh,PS3 0,000 DEPT 9600,000 MPHI,PS3 8.730 RTNR,PS3 ~.126 TMRA.PS3 RCNT:P8~ 7719,139 RCFT.PS3 3460,929 CNTC,PS3 7~97~.716 CFTC,PS3 G~.PS3 36,344 TENS,PS3 t385,000 CCL,PS3 0,000 DEPW. 9500,000 NP~iI,PS3 16,391 RTNR,PS3 3,~14 TNRA.PS3 RCMT PS~ 6190,045 RCFT.PS3 ~029.445 CMTC, P83 588~.788 CFTC,PS3 . " ~t ". GR PS3 67,750 TE~..S PS3 1335.000 CCL.PS3 0.000 3,455 1289.982 1215,578 4,242 943,252 4'388 847,242 31.50;217 3,266 1938.892 IS Tape Verification [,Istlnq chlt]mberqer AlasKa Computinq Center 25-OCT-IA91 13:02 PAGE: 27 DFPT, RCNT.P$3 G~.PS3 9400,000 NPHI PS3 41 922 RTNR,PS3 5.B26 TNRA,P$] ~551,495 RCFT:PS] 407:982 CNTC,PS3 2445.626 CFTC,PS3 64.313 TENS.PS3 1315' 000 CCb,PS3 0.000 933~,000 NPHI.PS3 45 581 RTNR,PS] 7.000 TNRA.P$] ooo ooo DVPT, RCNT.PS3 G~.PS3 ** END OF DATA 6.401 ,]75.633 6,818 346,893 **** FIL~ TRAIBER **** FIL~ NAME : EDIT .008 SFRVICE ~ FLIC ¥~RSION : O01A06 DATE ~ 91110/25 ~X REC SIZE : ~024 FIL~ TYPE ~ LO LAS~ FILE : **** FILE HEADER FILF NA~E : EDIT .O09 $~RVlCE ~ FblC V~R$ION : OO1A06 DAT~ : 91/I0/~5 MAX RFC SIZE : ~024 FILF TYPE ~ LO baST FIbE FILF }!EADER FILF, NUgBER 9 RAW CURVES Curves and loq header data ~or each pass In separate ~les; raw ba¢~grougd pass ~n last f~le PASS NUMBER: 4 DFPTN INCREMENT: -.5000 # FILE SUMMARY VENDOR TOOl, CODE START DEPTH C~TD ~0003.0 LOG HEADER DATA DATE L~GGED: SOFTWARE VERSION: TIME LOCKER ON BOTT~M~ TO DR!LL~R (FT)~ 'rD bOGGER(FT): STOP DEPTH 9394.0 19-OCT-9~ CP 32.4 945 19-OCT-91 9984.0 9981.0 IS Ta~e verificatio~ List~.n~ ChlU~ber~er Alaska ComDutlDq Center 25-0CT-1991 13:02 PAGE: 2~ TOP LOG INTERVAl, (FT): ROTTn~ LnG INTERVAL LOGGING SPEED (FPHP){ · ~EPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CMTD COLLA LOC~TOR CNTD bOGGiNG SOURCE CNTD COMP. NEUTRON CART, CWTD TELEMETRY CARTRIDGE C~TD TELEMETRY MODULE ~PEHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS C~SING DEPTH (FT): BORENObE CONDITIONS FLUID TYPE: FLUID DENSITY SURFACE TEmPErATURE (DEGF): BOTTOM MOLE TEMPERATURE (DEGF): FLUID SALINITY FLUID LEVEL FLUID RATE AT WELLHEAD WATER CUTS (PCT)~ GAS/OIL RATIO: CHOKE NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): ~TRIX: ~ATRIX DENSITY: HOLM CORRECTION (.I~): NORMALIZATION WINDOW START DEPTH (FT): STOP DEPTH AMOUNT: 9400,0 °97~.60 NO T~_OL NUMBER AL-U 9 NSR-LA 3039 CMC-DA 146 ATC-CB 1~52 ATM-AA 374 8 50 ,o o?o SEAWATER SANDSTONE 2,65 GAS SCAI, ING FACTOR FOR NEAR AND FAR COUNTS: MULTiPLIEP: TOOL STANDOFF (IN): PE~ARKS: TIED INTQ SPERRY MWD DUAL GAMMA RAY DATED WELL NOT PERFORATED WELLHEAD PRESSURE= 1250 PSIA FLUIDS IN WELL G~S LIFTED DOWN TO 5230' $ LIS FORMAT DATA IS Ta:~e Verificat~on List~no c.hlumheroer Alaska COmDutinO Center 25-OCT-1991 13:02 PAGEI 29 ** OATA FORMAT SPECTFICA~YON RECORD SET TYPE - 64ED ** TYPE REPR CODE VALUE I 66 2 66 3 73 4 66 5 66 6 73 7 65 g 68 9 65 11 66 t2 68 13 66 14 65 15 66 ~6 66 0 0 44 ! 0 FT 68 1 ** SET TYPE - CHAN ** N~ME SERV UNIT SERVICE APl ~PI ~PI ID ORDE~ # bOG TYPE CLASS D~PT FT 42526! O0 000 O0 0 HPHT PS4 PU 425~6~ O0 000 O0 0 RTNP P$4 4~5261 00 000 O0 0 T~Ra PS4 42526~ O0 000 O0 0 RCNT PS4 CPS 4~526i O0 000 00 0 RCFT PS4 CPS 425261 O0 000 O0 0 CNTC PS4 CPS 425~6i O0 O00 O0 0 CFTC PS4 CPS 425261 O0 000 O0 0 GR PS4 GAPI 42526~ O0 000 O0 0 T~NS PS4 LB 425261 O0 000 O0 0 CCL PS4 V 425261 O0 000 O0 0 PI FILE NUMB NUMB SIZE ~EPR PROCESS OD NUMB SA~P ELE~ CODE (HEX) 9 ~ I 4 68 0000000000 9 1 I 4 68 0000000000 9 ~ I 4 68 0000000000 9 1 1 4 68 0000000000 g 1 1 4 68 0000000000 g I t 4 68 0000000000 9 1 I 4 68 0000000000 9 I I 4 68 0000000000 g 1 1 4 68 0000000000 9 I I 4 68 0000000000 9 1 1 4 68 0000000000 DEPT. 10005.000 NPHI.PS4 RCMT.PS4 4499.394 RCFT.PS4 G~.PS4 72,281 TENS.PS4 D~PT 10000,000 NP I PS4 RCNT.PS4 4581.345 RCFT,P$4 GP.PS4 ~2,28! TENS.PS4 19,133 RTNR,PS4 3.569 TNRA,PS4 1260.606 CNTC.,PS4 4317.022 CFTC.PS4 650.000 CC5,PS4 0.000 !9.594 RTNR,PS4 3.562 TNRA.PS4 1294,900 CNTC,PS4 4390.943 CFTC.PS4 1080.000 CCh,PS4 0.000 3,698 1193.671 IS Taoe verification List,.nE chlumberaer AlasKa Computing Center 25-OCT-19gl 13:02 PAGE= 3O DEPT. 9900,000 NPHI.PS4 RCNT.PS4 4186,252 RCFT,PS4 GP.P$4 !3,5R6 TENS.PS4 DFPT. 9800.000 NPHI.PS4 RC~T.PS4 4287,929 RCFT,PS4 GR.PS4 28,047 TENS.PS4 DEPT. 9700,000 NPHI,PS4 RCNT,P$4 3841.449 RCFT,PS4 GP.PS4 20.031 TENS,PS4 DFPT. 9600,000 NPHI.PS4 RCNT.PS4 7248,018 RCFT,PS4 GP.PS4 33.438 TENS,PS4 9500 000 NPHI.PS4 G~ P$4 47 313 TENS,PS4 D~PT 9400 000 NPHI.PS4 RCNT~P$4 ~355:606 RCFT,P$4 G~.PS4 64,938 TENS.PS4 DFPT 9386,500 MP~I.PS4 RCNT~PS4 2787,330 RCFT,PS4 G~.PS4 62,594 TENS.PS4 ** END OF DATA ** 23.78~ ~TNR,PS4 992.24 CNTC,PS4 1410,000 CCL,PS4 21 ~28 RTNR,PS4 1099! 78 CNTC,PS4 14i0 000 CCI..P$4 24.405 RTNR,PS4 869.76~ CNTC,DS4 1380.000 CCL.PS4 7 676 RTNR,P84 3388!448 CNTC,PS4 1370 000 CCL.PS4 13,914 RTMR.PS4 251~,686 CNTC,PS4 !33 ,000 CCL,P$4 40,395 RTNR,PS4 398,190 CNTC,PS4 1.335,000 CCL,PS4 37,820 RTNR,PS4 47~,121 CMTC,PS4 134 ,000 CCh,PS4 4.179 4024 958 0:000 3.871 4139.903 0.000 4.375 3684.401 0.000 1.968 6873'l. 80 0,000 2 691 5932!400 0 000 6.364 2413.924 0.000 ~.769 2664.895 0:000 TNRA.PS4 CFTC.PS4 TNRA.PS4 CFTC.PS4 TNRA.PS4 CFTC.PS4 TNRA.PS4 CFTC,PS4 TNRA.P$4 CFTC.PS4 TNRA,P$4 CFTC,PS4 TNRA.PS4 CFTC,PS4 4,259 946,313 3,903 1.040,559 4 341 835:897 2.072 2,g2g 2207,116 6'236 386'699 5.953 432,188 **** FILE TRAILER **** FILM NAME I EDIT .009 SERVICE : FLIC VERSION : OOIA06 D~T~ { 91/10/25 M~X REC SIZE : 1024 FILE TYPE : LO L~$~ FILE I **** TAPE TRAILE~ **** SMRVICE NAME : EDIT DITE ! 91/10/25 O~I~IN : WbIC T~P~ N~g : 75072 CONTINUATION # : PREVIOUS TAPE : COg~ENT : BP ~.~XPLORATION PRUDHOE BAY,$'I7A'2,500292114801 KS Tape Verification List~,n~ :hlumber~er Alaska Computing Center 25-0CT-~991 13{02 **** REED TRA!LE~ SERVICE ~ME : ~DTT D~TF ~ 91/10/~5 ORICI~ : FLIC ~EL ~AME : 7507~ CONTINUATION ~ : PW. EVIOUS REEL COMMENT : BP EXPLORATION,PRUDHOE BAY,S-~7A-~,50029211480~ PAGE: 3!
