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196-032
Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 09/12/2025 InspectNo:susSTS250729145743 Well Pressures (psi): Date Inspected:7/25/2025 Inspector:Sully Sullivan If Verified, How?Other (specify in comments) Suspension Date:3/23/1996 Tubing:0 IA:0 OA:0 Operator:Hilcorp Alaska, LLC Operator Rep:Chris Casey Date AOGCC Notified:7/18/2025 Type of Inspection:Subsequent Well Name:MILNE PT UNIT K-25 Permit Number:1960320 Wellhead Condition Clean, valves turned easily Surrounding Surface Condition Clean and free of debris. No sign of subsidence Condition of Cellar Free of debris and contaminants Comments Location verified by plot map Supervisor Comments Photos (2) attached Suspension Approval:Completion Report Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Friday, September 12, 2025 9 9 9 9 9 9 9 9 9 9 9 2025-0725_Suspend_MPU_K-25_photos_ss Page 1 of 1 Suspended Well Inspection – MPU K-25 PTD 1960320 AOGCC Inspection Rpt # susSTS250729145743 Photos by AOGCC Inspector S. 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IORDWFROODU 3%7' .23#;;; 0D[KROHDQJOH [[WR[[GHJI WR[[[ +ROHDQJOHWKUX SHUIV [[GHJ '/6 [[GHJ #[[[[[ IORDWVKRH SSI+ 038. ;;;;;-HWFKDUJHV#GHJ SKDVLQJ 6WLPXODWLRQ6XPPDU\ VKRUWMRLQWIURP[[[[[ WR[[[[[ PG 3%7'DW[[[[ PG -%)6XUIDFH+ROH'ULOOHGDQG&DVHGE\1( 'ULOOLQJZDVVXVSHQGHGRQFHVXUIDFHFDVLQJZDVVHW +\GUDWHVZHUHHQFRXQWHUHGGXULQJGULOOLQJ 7KHSULPDU\FHPHQWERQGTXDOLW\ZDVYHU\SRRU 3DWKIRUZDUG\HWWREHGHWHUPLQHG 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Inspect well Hilcorp Alaska Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 3,955 feet N/A feet true vertical 3,761 feet N/A feet Effective Depth measured 3,855 feet N/A feet true vertical 3,683 feet N/A feet Perforation depth Measured depth N/A feet True Vertical depth N/A feet Tubing (size, grade, measured and true vertical depth)N/A Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Chad Helgeson Contact Name: Authorized Title:Operations Manager Contact Email: Contact Phone: 110' 777-8333 2. Operator Name Senior Engineer: Senior Res. Engineer: Collapse N/A 3,746' 110' Burst 3,090psi 20" 3,936'3,936'Surface Intermediate 9-5/8" 5,750psi N/A Production Production Casing Conductor Liner Length 110' MILNE PT UNIT K-25 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Gas-Mcf Casing Pressure Tubing Pressure N/A measured 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Authorized Signature with date: Authorized Name: David Gorm dgorm@hilcorp.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 196-0320 50-029-22650-00-00 Plugs ADL00375133 5. Permit to Drill Number: MILNE POINT / KUPARUK RIVER OIL Junk measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: Representative Daily Average Production or Injection Data Oil-Bbl measured true vertical Packer WDSP2 WAG Water-Bbl MD TVDSize PL G Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Jody Colombie at 8:15 pm, Jul 21, 2020 Chad A Helgeson 2020.07.21 16:41:54 -08'00' 196-032 DSR-7/22/2020MGR22JUL2020 SFD 7/22/2020 RBDMS HEW 7/23/2020 SFD 7/22/2020 State of Alaska Oil and Gas Conservation Commission Deficiency Report Location: Milne Point Unit Date: 7/23/2020 PTD: Various Operator: Hilcorp North Slope Type Inspection: Suspend Operator Rep: Derek Weglln Inspector: Jim Regg Position: Wellsite Supervisor Op. Phone: 907-670-3387 Correct by (date): 8/15/2020 Op. Email: Derek.Weglin@hilcorp.com Follow Up Req'd: Yes Detailed Description of Deficiencies Date Corrected Missing API # on Well Sign: MPU C-16 (PTD 1851100) 7-24-2020 Missing API # on Well Sign: MPU K-25 (PTD 1960320) 7-24-2020 Missing API #on Well Sign: MPU L-34 (PTD 1970800) 7-25-2020 Missing API # on Well Sign: MPU L -35A (PTD 2011900) 7-25-2020 Attachments: Photos (4) Note Jeff Jones waived reinspection on 7-25-20 01,1all, slprrta ty oereI w,o Derek Weglin wUs DN'-Dtt¢kweglm «z5, LX Operator Rep Signatures: 4625 Digitally signed by James B. Regg James B. Regg AOGCC Inspector Date: 2020.07.23 10:56:05 -08'00' *After signing, a copy of this form is to be left with the operator. Follow-up Instructions Return a copy of this Deficiency Report to AOGCC (Attention: Inspection Supervisor) within 7 days of receipt. Include the "Date Corrected" and attach supporting documentation for each corrective action implemented to address the deficiencies. If a follow- up inspection was performed by AOGCC, include the date and name of Inspector. Extensions for corrective actions taking longer than the "correct by" date must be requested and accompanied byjustification (Attention: Inspection Supervisor). Documentation of deficiences that are outside of AOGCC regulatory jurisdiction will be forwarded to the appropriate authority 1 44 )12g1 Revised 7/2019 MPU Well Signs Corrected (Missing AN #) Response to AOGCC Deficiency Report Issued 7/23/2020 Photos Courtesy of Hilcorp 7/24/2020 OWNER Ailne Point Unit *OPERATOR HILCORP Alaska, LIZ SUR. LOCATION S7 114, Sec. 10, T13N, R10E DRILLING PERMIT 185-110 API# 50-029-21364-00-00 WELL NAME MPKm25 i OWNER Milne Point Unit OPERATOR HILCORPAlaska, LLC SUR. LOCATION NE 1/14, Sec. 03, T12N, R11E DRILLING PERMIT 196-032 API# 50-029-22650-00-00 2020-0725_Deficiency_Report_Corrected_MPU_Wellsigns_photos.docx Page 1 of 2 r WELL NAME MPL-341 OWNER Milne Point Unit i OPERATOR HILCORP Alaska, LLC SUR. LOCATION NW 1/4, Sec.08, T13N, R10E DRILLING PERMIT 97-80 DAP1# 50-029-22766-00-00 WfLLNAME MPLw35A . OWNER ` Milne Point Unit Z $ OPERATOR HILCORP Alaska, LLC SUR. LOCATION NW 1/4, Sec. 08, T13N, R10E DRILLING PERMIT 201-109 i'AP1# 50-029-22768-01-00 2020-0725_Defi cie ncy_Re po rt—Co rrected_M PU_W el Isig ns_photos. docx Page 2 of 2 Regg, James B (CED) From: Sent: Regg, James B (CED) Thursday, July 23, 2020 11:54 AM To: Chad Helgeson l Cc: Roby, David S (CED) Subject: MPU Well Signs Attachments: 2020-0723_Deficiency_Report_MPU wellsigns.pdf; MPU L-34 well sign.jpg; MPU L -35A well signjpg; MPU C-16 well signjpg; MPU K-25 well signjpg AOGCC performed suspended well inspections at several MPU wells in late June and recently received the suspended well 10-404s from Hilcorp. 4 wells had identification signs that were missing the API number. Attached is a Deficiency Notice requesting these signs be adjusted to include the API #; the due date can be amended if needed. Hilcorp is encouraged to confirm that the other wells in MPU have the correct info on the well signs. Call or email if you have questions. Jim Regg Supervisor, Inspections AOGCC 333 W.7"' Ave, Suite 100 Anchorage, AK 99501 907-793-1236 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jim Regg at 907- 793-1236 or im.regg@@alaska.eov. State of Alaska Oil and Gas Conservation Commission Deficiency Report Location: Milne Point Unit Date: 7/23/2020 PTD: Various Operator: Hilcorp North Slope Type Inspection: Suspend Operator Rep: Inspector: Jim Regg Position: Op. Phone: Correct by (date): 8/15/2020 Op. Email: Follow Up Req'd: Yes Detailed Description of Deficiencies Date Corrected Missing API # on Well Sign: MPU C-16 (PTD 1851100) , Missing API # on Well Sign: MPU K-25 (PTD 1960320) _ '- Missing API # on Well Sign: MPU L-34 (PTD 1970800) Missing API # on Well Sign: MPU L -35A (PTD 2011900)T— Attachments: Photos (4) Operator Rep Signatures: James B. Re Digitally signed by James B.Regg �g Date: 2020.07.2310:56:05-08'00' AOGCC Inspector *After signing, a copy of this form is to be left with the operator. Follow-up Instructions Return a copy of this Deficiency Report to AOGCC (Attention: Inspection Supervisor) within 7 days of receipt. Include the "Date Corrected" and attach supporting documentation for each corrective action implemented to address the deficiencies. If a follow- up inspection was performed by AOGCC, include the date and name of Inspector. Extensions for corrective actions taking longer than the "correct by" date must be requested and accompanied byjustification (Attention: Inspection Supervisor). Documentation of deficiences that are outside of AOGCC regulatory jurisdiction will be forwarded to the appropriate authority for fn1low-un art nn Revised 7/2019 w � 7' Y ■ `.� . \ / ■ `.� . Suspended Well Inspection Review Report InspectNo: susMFH200620141650 Date Inspected: 6/20/2020 Inspector: Matt Herrera Type of Inspection Well Name: MILNE PT UNIT K-25 Permit Number: 1960320 Suspension Approval: Completion Report Suspension Date: 3/23/1996 Location Verified? P] If Verified, How? Other (specify in comments) Offshore? ❑ Subsequent Date AOGCC Notified: 6/19/2020 Operator: Hilcorp Alaska, LLC Operator Rep: Josh McNeal Wellbore Diagram Avail?❑ Photos Taken? ❑ Well Pressures (psi): Tubing: 0 Fluid in Cellar? ❑ IA: - 0 - BPV Installed? ❑ OA: 0 VR Plug(s) Installed? ❑ Wellhead Condition Good. No leaks on any flange connections or lock down screws. No SSV. All Valves operational. Gauges installed and in .- working order to note tubing and annulus pressures Condition of Cellar Good; no standing wateror stains or sheen. Clean with no subsidence Surrounding Surface Condition Good; no standing water or stains. No subsidence ' Comments Well location verified per MPU K -Pad Supervisor Comments Thursday, July 23, 2020 RECEIVED STATE OF ALASKA ALOKA OIL AND GAS CONSERVATION COM SION SEP 1 7 2015 REPORT OF SUNDRY WELL OPERATIONS ,,)GCC 1.Operations Abandon H Plug Perforations A Fracture Stimulate _I Pull Tubing ❑ Operations shutdown _ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ] Plug for Redrill ❑ srforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Inspect Well ❑✓ 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: Hilcorp Alaska,LLC Development E Exploratory ❑ 196-032 3,Address: Stratigraphic❑ Service ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22650-00-00 7. Property Designation(Lease Number): 8.Well Name and Number: ADL0375133 MILNE PT UNIT KR K-25 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A MILNE POINT/KUPARUK RIVER OIL 11.Present Well Condition Summary: Total Depth measured 3,955 feet Plugs measured 3,855 feet true vertical 3,761 feet Junk measured N/A feet Effective Depth measured 3,855 feet Packer measured N/A feet true vertical 3,683 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' N/A N/A Surface 3,936' 9-5/8" 3,936' 3,746' 5,750psi 3,090psi Intermediate Production Liner Perforation depth Measured depth See Attached Schematic feet SCANNED NOV 1 6 2015 True Vertical depth See Attached Schematic feet Tubing(size,grade,measured and true vertical depth) N/A N/A N/A N/A Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 14.Attachments(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 2Exploratory❑ Development❑✓ Service ❑ Stratigraphic Li Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil El Gas Li WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP Li SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Stan Porhola Email sporhola@hilcorp.corn Printed Name Stan Porhola Title Operations Engineer Signature ,,,,,Z44------- � ft,-ik_ Phone 777-8412 Date 9/15/2015 54l t�.iti„' RBDMS SEP 2 2015 Form 10-404 Revised 5/2015 }("` ' Submit Original Only 1 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 08/23/15 Inspector: Chuck Scheve Operator: Hilcorp.LLC Well Name: MPK-25 Oper.Rep: Bill Kruskie PTD No.: 196-032 Oper.Phone: 1-907-670-3387 Location Verified? Yes Oper.Email: wkruskieahilcoro.com If Verified,How? Other(specify in comments) Onshore/Offshore: Onshore Date AOGCC Notified: 08/21/15 Suspension Date: 03/23/15 Type of Inspection: Subsequent Sundry No.: 96-070 Wellbore Diagram Avail.? Yes Photos Taken? Yes Well Pressures(psi): Tubing 20 IA 20 OA 0 Condition of Wellhead: Good,no visable leaks and all gauges are installed,well guard inplace,well head sign installed&tree has one working valve . Condition of Surrounding Surface Location: Good,blue goo on bottom of flutes. Follow Up Actions Needed: None. Comments: Map on location. Attachments: Pictures REVIEWED BY: Area map Insp.Supry WBS Comm PLB 12/2014 MPK-25 2015 Suspended Well Inspection Form • • 44 .....,' ,,,,,,,,,,,'„ ,,,,:..,, • • i..., : .. .,... . .,, .. , ., , I f : --a , I tit -'.— '- - -- ....:'4'''''''X 1:;. •... '7.- -....•,..;;,7---,_...,.., -••Nei ft-5111111 . .. -"N/ - I, _ ____± Ilk Err''".'"----- '... ., Al 7 " .IssimmisaiNimmis._ il won ft a.. 0., . . . '''- '''' 71111j11Pllr""Ci.- ik ' ... ,,,,,,,,. - .......-- . ,, _ , 1 1 • N I , , ili:V.111 AT'. 4 .. As., fij __., ..._. . . _. {, 4, ....... .,_ ,,...,... f A r MK • ' ' •• "• ii. n AN*4= . '.-."°** *44.10401111111114111111116w __ ',i Illi=:, ....„ , .... --4..0i Siiiiiiritiikia row, •••Romir .•• fili•-iAL:. ..., --...-- - ... . ... ,,........,..,:.,,,.4,..,•4'17,7q".0.. , . • .... '- . . .• ) , „, .-- : • . - - - 1---•--• - . . V.L...-....roset• s_ - .. . .: .. ....6.111"1.,... .ltri...r............... - 11..... . 11111NIA• mic.,...xxi* wellow---, - WELL NAME MPK•25 , .._....„ . . ......, . , OWNER , . .. ... .., .. . . , Milne Point Unit • . OPERATOR BP Exploration . .. SUR.LOCATION NE 1,,r,Sec.03,T12N,RI1E ''''.- • - • DRILLING PERMIT 196-032 ... -, •..APP"'.40000001°''- . ., - , . , .„. • . . . .1 : .- '• ".4%,00,,,,4 - •-.11 .1,r . • . • • . ••• . • • . , r ' . . , •„ .... , • ....:„.,,. , . ‘'.-.. 7 .! ,,, - , 7 •: •,at,K3, '' '• ,•.,'....',IP • •,— . ..' si— • . •-... .-- ,.. .. `. • ''', • '..'..,rit, .:• . •_INN. iixio;%,,A1 ,,'N,'7.--...... -',..• . „. •. ... . -. . . - . . .... , .....afPlp -, ..- ' '. . t' .. ,-.4.- - ,0.44. , ,,,,„, ._.r.. -.?..- p' .firo,5,,,,,..›..,..,,,t;4,7",•,et.74.,,ste-..K_ ..,•• ,jt.' ,...,•,1p :.„0:, .7.' fr. ' ..2,2. ,-..'.41.7.-.-.1.',..;•:'-i*,,,,,' .41'.... .....' ....*-' . ' '' L - ' - - . ; ,,,, 4-,,,-,.. .. . ...., • -........1.,:„,..:4-1.-!",;...if•-,,Li- .4,. -.....--„,,, ,-., •.... :,, -.' ._, -;., ..;..;,,!:.., "im,"•10..,70.6..f..... -- L. . ....;, „ _. • ,._ , . - -.. .....% , os ' • 7, -- ^"...' 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'''' • c. r . • ,, r •s ',„ rip t. . � ..^ M„ s -,i-'4"::''''''''i 'rYf • ' . ,•:, < i•<1,,:.;-•'''-'1-''''''.4'1.,..:.<••<'',-;••':•••<4:''' ' ''''• '1'!..;<'.-.."..,<,,'(''..'".i...,;.....A54F•';41ti..:',..,8.• -- r'l-,- ,•,•.:,•;•• •'•,,,,,r,r' • --— -•' ' ;„t A.7�F ,& a , 1 �r° ur . '" „...:•_;. •.4'4,47,41'..11- > r M t^ ! • 1 aV `D / • co _mi A A .____ . . . ()_, .,.., _....„ ..._ ____ . x c,.., mu .._. . , ,. . . „... N.) , .._____ ••••• ---1, ., .. c., gz - , ..„ , x_,,I :b a .,„.., ‘, \ - .„ , . ,..„, • . ........ . c,..., • . . . ,, ilik r\11\ „ ---._. c....) (A,, • , ,,,, • c, 1 • . , • • X � *• o 0 • X ,, 0< - '' 15 X CO • CCi CO l /may~ 1 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 08/23/15 Inspector: Chuck Scheve Operator: Hillcorp Well Name: MPU K-25 - Oper. Rep: Bill Kruskie - PTD No.: 1960320 Oper. Phone: 907-670-3387 Location Verified? Yes Oper. Email: 3-Milne-WellsiteSuperisorsahil If Verified,How? Other(specify in comments) Onshore/Offshore: Onshore Suspension Date: 03/23/96 - Date AOGCC Notified: 08/20/15 , Sundry No.: Well Completion Report' Type of Inspection: Subsequent - Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing 0 Photos Taken? Yes IA 20 - OA 0 Condition of Wellhead: Single master valve only. Condition of Surrounding Surface Location: Good Follow Up Actions Needed: None Comments: Location verified by site map. Photos taken by operator available upon request. Attachments: none CANNED SEP O 2016 REVIEWED BY: Insp.Supry c_ 1/(5,4,4; Comm PLB 06/2014 2015-0823_Suspend_MPU_K-25_cs.xlsx 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. I(~- 0'~ File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Bevedy~incent Nathan Lowell Date: j~-~(~ ,s/D.~ [] TO RE-SCAN Notes: Re-Scanned by: Begedy Dianna Vincent Nathan Lowell Date: Is/ • • bp BP Exploration (Alaska) Inc. , .,..._... • Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 S ti t) FEB 1. 7 2012 December 30, 2011 Mr. Tom Maunder l q6 - Alaska Oil and Gas Conservation Commission 1M 1 333 West 7 Avenue Y r I Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPK -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPK -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator �� ... • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPK 10/29/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal MPK -02 1960810 50029226750000 0.2 NA 0.2 NA 5.1 9/5/2011 MPK -05 1960680 50029226700000 1.9 NA 1.9 NA 17.9 8/24/2011 MPK-06 1961910 50029227250000 1.5 NA 1.5 NA 8.5 8/27/2011 MPK -09 2050140 50029232470000 1.9 NA 1.9 NA 12.8 8/24/2011 MPK -13 1960400 50029226550000 1.7 NA 1.7 NA 14.5 8/24/2011 MPK -17 1960280 50029226470000 1 NA 1 NA 2.6 8/24/2011 MPK -18A 1970270 50029227330100 4.6 NA 4.6 NA 23.8 8/27/2011 MPK -21A 2031620 50029227180100 0.4 NA 0.4 NA 6.9 10/29/2011 MPK -22 2050220 50029232490000 2 NA 2 NA 5.1 8/27/2011 ----- MPK -25 1960320 50029226500000 4.2 NA 4.2 NA 30.6 8/24/2011 MPK -30 1961680 50029227110000 1.5 NA 1.5 NA 17.0 8/25/2011 MPK-33 1962020 50029227290000 1.7 NA 1.7 NA 15.3 8/24/2011 MPK -34 1961690 50029227120000 2.5 NA 2.5 NA 25.5 8/25/2011 MPK -37 1960760 50029226740000 2 NA 2 NA 17.0 8/24/2011 MPK -38 1960300 50029226490000 3.2 NA 3.2 NA 15.3 8/25/2011 MPK -43A 1970410 50029227380100 1.7 NA 1.7 NA 13.6 9/16/2011 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 09/12/10 Inspector: Chuck Scheve Operator: BPX Well Name: MPU K -25 Oper. Rep: Lee Hulme PTD No.: 1960320 Oper. Phone: 659 -5766 Location Verified? No Oper. Email: If Verified, How? Onshore / Offshore: Onshore Suspension Date: 03/23/96 Date AOGCC Notified: Sundry No.: Well Completion Rpt Type of Inspection: Initial Wellbore Diagram Avail.? Yes Well Pressures (psi): Tubing N/A Photos Taken? Yes IA N/A - by Operator OA 180 Condition of Wellhead: Barricade in place, Master valve installed. Well has surface casing only. Condition of Surrounding Surface OK Location: Follow Up Actions none Needed: Attachments: none REVIEWED BY: Insp. Supry \ (c' I � I I Comm PLB 08/2010 2010- 0912_Suspend_MPU_K- 25_cs.xls THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE JANUARY 03,2001 M E PL A T E IA L U N D T H IS M ARK ER W E R C :LORIXMI~M/)OC / / Schlumberger - GeoQuest A Division of Schlumberger Technologies Corporation 500 W. International Airport Road Anchorage, Alaska 99518 - 1199 (907) 562-7669 (Bus.) (907) 563-3309 (Fax) August 30, 1996 TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The following data of the CDR,, CDR 'FVD for well MPK-25 Job # 96104 was sent to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 1 OH LIS Tape 3 Bluelines each 1 Film each State of Alaska Alaska Oil & Gas Conservation Comm. . Attn: Larry Grant 3001 Porcupine Drive ~,,,Anchorage, Alaska 99501 I OH LIS Tape -....... 1 Blueline each ':-.... 1 RF Sepia each ~, OXY USA, In'~-'- Attn: Darlene Fairly P.O. Box 50250 Midland, Texas 79710 1-.OH LIS-TaP~ 1 Blueline each I RF Sepia each Sent Certified Mail Z 777 937 467 .NOTE: NO DEPTH SHIFT PER MATT LINDER PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP EXPLORATION (ALASKA)INC. PETROTECHNICAL DATA CENTER, MB3-3 900 EAST BENSON BLVD. ANCHORAGE, ALASKA 99519-6612 Schlumberger Courier: SCHLUMBERGER GEOQUEST 500 WEST INTERNATIONAL'AIRPORT ROAD ANCHORAGE, ALASKA 99518-1199 RECEIVED Date Delivered: SF'_P 05 '~99~o Received By: Alaska 0ii & Gas Cons, ~mmission ~chorage HOWARD OKLAND Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE ~LK, 99501. Date: 8 August 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION 1 LDWG TAPE+LIS MPK-05 ~ '~~ 1 LDWG TAPE+LIS ECC No. Run # 1 6630.00 Run # 1 6653.00 Please sign and return to: Attn. Rodney D. Paulson Western Atlas ~ogging Services 5600 B Street · Suite ~01~'~' ...~ Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by ! %~%~L~'~te: .- . -.r LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. · . Date: 10 April 1996 Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION i PFC/PERF FINAL BL+RF 1 SBT FINAL BL+RF 1 SBT FINAL BL+RF ECC No. Run # 1 6512.02 Run $ 2 6630.01 Run # 1 6639.00 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 A~chorage, JLK 99518 7) 563-7803 Received by: Date: APR 'l b '1996 Alaska Oil & Gas Cons. Commission ~.ch~,~e LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Dear Sir/Madam, Reference: BP MILNE POINT NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 SBT FINAL BL+RF Date: RE: 28 March 1996 Transmittal of Data ECC #: 6630.00 Sent by: HAND CARRY Data: SBT/GR Run # 1 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 907) 563-7803 Received by: Date: F EOEIVED APR 0 9 Alaska Oil & Gas Cons, Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation Shutdown X Re-enter suspended well __ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate ~ Change approved program __ Pull tubing Vadance __ Perforate ~ Other .__ 2. Name of Operator BP Exploration (Alaska) Inc 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3592' NSL, 2078' WEL, SEC. 3, T12N, R11E At top of productive interval 405' NSL, 3079' WEL, SEC. 3, T12N, R11E At effective depth N/A At total depth 224' NSL, 3135' WEL, SEC. 3, T12N, R11E 5. Type of Well: Development x Exploratory __ Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 61 7. Unit or Property name Milne Point Unit 8. Well number MPK-25 9. Permit number 96-32 10. APl number 50- 029-22650 11. Field/Pool Milne Point Unit/Kuparuk River feet 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner true vertical measured true vertical Length 110' 3899' 3936' feet Plugs (measured) 3618' feet feet Junk (measured) feet Size Cemented Measured depth True vertical depth 20" 250 sx Arcticset ! (Approx.) 110' 110' 9-5/8" 768sxPF'E',250sx'G:100s~PF'E' 3936' , ~ ~. i=. ~ ~ .~.. ~er se.ing su~a~ ~sing for ~PK-25, we request an operation sh~ do~. A fo~ard program ~!1 be developed after fu~er evaluation of the 9-5/8" ~ment job. 13. Attachments Description summary of proposal ~ Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 03/23/96 16. If proposal was verbally approved Name of approver Blair Wondzefl o3/zz/96 Date approved 15. Status of well classification as: Oil X Gas__ Suspended__ Service 17. I hereby certify that the for~lgoing is tn.je and correct to the best of my knowledge. ~-;~¢.~-,,/ ¢-oq~L~LC+ -¢r~ ~' ~on5: Signed ~ Title Senior Drilling Engineer Date FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test__ Location clearance __ Mechanical Integrity Test~ Sub~sequen~ form required 10- OrJgina, 8ignea By David W, J0hnstor, Approved by order of the Commission I Approval No. Approved Co'py Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICAT-E_~ MEMORANDUM TO: r David Johnst_~l~r-, Chairman~--~ THRU: Blair Wondzell, P. 1. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission DATE: March 22, 1996 FILE NO: gwqlcvdd.doc FROM: John Spaulding, SUBJECT: Petroleum lnsp. Casing Cement Integrity BPX MPK-25 Miine Point Unit Friday March 22, 1996: The surface casing had been set at a depth of 3935.45 feet md and cemented, cement was not circulated to surface. A "top job" was performed. While witnessing the BOPE Test on the rig it was noted that gas cut mud and water was bubbling up around and out of the wash ports on the conductor pipe. Suspected hydrates were encountered at 2172' md, 2329' md, 2350' md, 2761' md. At 2761' md gas cut mud was encountered lowering the mud weight from 11 ppg. to 7.8 ppg. at this point the mud was weighted up to 11.5 ppg. and circulated out. Typically hydrates are not always controlled by weight, they are influenced more by temperature. BPX is not convinced that the gas that they are seeing in the surface portion of the well is ali hydrates. On the next well gas monitoring and testing equipment will be installed in an effort to define what type of gas is being encountered Summary' i reccommended that a cement evaluation tool be run to determine the top of the parent cement in the annular area. Once the top of cecment has been determined BPX will need to devise a plan on how to get cement to surface. : MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Johnston, Chairman DATE' March 22, 1996 THRU: Blair Wondzell, ~ FILE NO: P. I. Supervisor FROM: John Spaulding~ ~ SUBJECT: Petroleum Insp. gwqlcvdd.doc Casing Cement Integrity, BPX MPK-25 Milne Point Unit Friday March 22, 1996: The surface casing had been set at a depth of 3935.45 feet md and cemented, cement was not circulated to surface. A "top job" was performed. While witnessing the BOPE Test on the rig it was noted that gas cut mud and water was bubbling up around and out of the wash ports on the conductor pipe. While drilling the surface section of the hole, suspected hydrates were encountered at 2172' md, 2329' md, 2350' md, 2761' md. At 2761' md gas cut mud was encountered lowering the mud weight from 11 ppg. to 7.8 ppg. at this point the mud was weighted up to 11.5 ppg. and circulated out. Typically hydrates are not always controlled by weight, they are influenced more by temperature. BPX is not convinced that the gas that they are seeing in the surface portion of the well is all hydrates. On the next well gas monitoring and testing equipment will be installed in an effort to define what type of gas is being encountered Summary: ! reccommended that a cement evaluation tool be run to determine the top of the parent cement in the annular area. Once the top of cecment has been determined BPX will need to devise a plan on how to get cement to surface. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David John~-~i DATE: Chairma~ THRU: Blair Wondzell, '~~ FILE NO: P. I. Supervisor FROM: John Spaulding,"f,,~ SUBJECT: Petroleum Insp. '~n"" March 21, 1996 awqlcudd.doc BOPE Test Nabors 27E BPX MPU K-25 Kuparuk River Field PTD 96-32 Thursday March 2'1, '1996: I traveled this date to BPX's Milne Point Unit well K- 25 to witness the BOPE Test on Nabors 27E. The AOGCC BOPE Test Report is attached for reference. The BOPE tested well with 2 failures observed, both were valves located on the choke manifold. These were greased and re-tested ok. The are~around the rig was well laid out with attention to good access to all areas of the rig. This pad is new and construction will be starting soon on the facilities, hopefully the conflicts in logistics between the rig and construction will be minimized. Summary: I witnessed the successful BOPE test on Nabors 27E, 2 failures, 4 hour test time. Attachments: awqicudd.xis STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drlg Contractor: Operator: Well Name: Casing Size: 9 5/8" Test: Initial X Workover: Nabors Rig No. 27E PTD # 96-32 BPX Rep.: MPK.25 Rig Rep.: Set @ 3935.45' Location: Sec. Weekly Other DATE: 3/21/96 Rig Ph.# 659-4373 Rodney Klepzig Jim Gaffney 3 T. 12N R. 11E Meridian Umiat TEST DATA MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok (Gen) PTD On Location ok Standing Order Posted ok BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Well Sign ok Drl. Rig ok Hazard Sec. ok Quan. Test Press. P/F 1 P 300/3,000 1 500/5,000 P I 500/5,000 P 1 500/5,000 P I 500/5,000 P 2 500/5,000 P I 500/5,000 P NA FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan Pressure P/F 1 500/5,000 P I 500/5,000 P 1 500/5,000 P I 500/5,000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes 15 Test Pressure P/F 500/5,000 P* 39 500/5,000 P 2 P Func~oned Func~oned ACCUMULATOR SYSTEM: System Pressure 2,900 P Pressure After Closure 1,600 P MUD SYSTEM: Visual Alarm 200 psi Attained After Closure minutes 20 Trip Tank ok ok System Pressure Attained 1 minutes 40 Pit Level Indicators ok ok Blind Switch Covers: Master: X Remote: Flow Indicator ok ok Nitgn. Btl's: 8 Average 2300 psi Meth Gas Detector ok ok Psig. H2S Gas Detector ok ok sec. sec. X TEST RESULTS Number of Failures: 2 ,Test Time: 4.0 Hours. Number of valves tested 21 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: FI-021L (Rev. 12/94) AWQLCUDD.XLS MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David John, st~. '//' DATE: Chairman -- March 17, 1996 THRU' Blair Wondzell, ~~ FILE NO: P. !. Superviso~~ FROM: Bobby Fos~--~-~L SUBJECT: Petroleum InsiS~=,ctor EWQICQDD.doc Diverter Inspection BPX - MPU - MPK-25 PTD # 96-0032 Kuparuk River Field Sunday, March 17,. 1996: I traveled this date to BPX's Milne Point field and inspected and function tested the diverter on Nabors rig 27 E. The diverter system was rigged up properly and in compliance with AOGCC regulations conceming diverters. I did request that warning signs and barricades be installed at the ends of the diverter lines. There is a lot of construction work on going on this new pad so the waming signs were needed. The rig was clean and all equipment seemed to be in good working order. The location was clean and all extra equipment and drilling supplies were stored properly. Summary: i inspected.the acceptable diverter system on Nabors 27E rigged up on BPX's Miine Point Unit well K-25. Attachment: EWQICQDD.XLS STATE OF ALASKA ALASKA UIL AND GAS CONSERVATION COMMISSION Diverter Systems Inspection Report Operation: Drlg Contractor: Nabors Alaska Drilling, Inc. ,, , Rig No. Operator: BPX MPU Oper. Rep.: Welt Name: MPK-25 Rig Rep.: Location: Sec. 3 T. 12N R. 11E Development 27E PTD # Date: 3/17/96 X Exploratory: 96-0032 Rig Ph. # 659-4384, TOM ANGLEN ROD KLEPZIG Merdian Umiat MISC. INSPECTIONS: ACCUMULATOR SYSTEM' Location Gen.: OK Well Sign: OK Systems Pressure: 3100 psig Housekeeping: OK (Gen.) Drlg. Rig: OK Pressure After Closure: 1850 psig Reserve Pit: ,N / A Flare Pit: N / A, 200 psi Attained After Closure:~ min. 20 sec. Systems Pressure Attained: 1 min. 21 sec. DIVERTER SYSTEM INSPECTION: Nitrogen Bottles: 8 Bottl~ ', ...... Diverter Size: 20 in. 2300 Ave. psig Divert Valve(s) Full Opening: iValve(s) Auto & Simultaneous: ;Vent Line(s) Size: Vent Line(s) Length: iLine(s) Bifurcated: !Line(s) Down Wind: Line(s) Anchored: Tums Targeted / Long Radius: YES , YES ~. MUD SYSTEM INSPECTION: Light Alarm ,,,10 ~in. Trip Tank: OK OK "86 & 136 ff. Mud Pits: OK OK "~ES Flow Monitor: OK ~K YES "'YES" GAS DETECTORS: Light Alarm YES Methane OK OK Hydrogen Sulfide: NT NT NORTH v Prevailing / Winds Drawing Not To Scale Mud System Motor Module N. Oo (2) 10" Mechanically ~ ~' ' ~ _ l. O, , , Annular Preventer With 10" FO Hydraulic Knife Valve Non Compliance items~ Remarks: lines. Distribution orig. - Well File c - Oper/Rep ¢- Database c - Trip Rpt File o - Inspector 0 Repair Items Wlthil 0 Day (s) And contact the Inspector @ 659-3607 ! ,,requested that warnin~l signs and barricades be installed at the ends of the diverter AOGCC REP.: FI-022 (Rev. 7/93 EWQlCQDD.XLS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Diverter Systems Inspection Report Date: 3/1 7/9 6 Operation: Development Drlg Contractor: Nabors Alaska Drlg. Rig No. 27E PTD # Operator: BPX Oper. Rep.: Well Name: MPU K-25 Rig Rep.: Location: Sec. 3 T. 12N R. 11E Merdian UM X Exploratory: 96-32 Rig Ph. # Tom Anglen Rodney Klepzig 659-4373 MISC. INSPECTIONS: Location Gen.: X Well Sign: X Housekeeping: X (Gen.) Drlg. Rig: X Reserve Pit: NA Flare Pit: NA DIVERTER SYSTEM INSPECTION: Diverter Size: 2 0 Divert Valve(s) Full Opening: Yes Valve(s) Auto & Simultaneous: Yes Vent Line(s) Size: 1 0 Vent Line(s) Length: 86/1 36 Line(s) Bifurcated: Yes Line(s) Down Wind: Yes Line(s) Anchored: Yes Turns Targeted / Long Radius: Yes in. in. ACCUMULATOR SYSTEM: Systems Pressure: 3,1 50 Pressure After Closure: 1,850 200 psi Attained After Closure: min. Systems Pressure Attained: 1 min. Nitrogen Bottles: 2300 Avg for 8 bottles 2O 21 MUD SYSTEM INSPECTION: Visual Trip Tank: OK Mud Pits: OK Flow Monitor: OK GAS DETECTORS: Visual Methane OK Hydrogen Sulfide: X Alarm OK OK OK Alarm OK X psig psig sec. sec. psig Prevailing Winds (2) 10" Mechanically Linked Knife Valves N.O. 56' Pipe Shed N. '~ ~_.~l~_~~r 32' 54' m~ Mud Syste Motor Module North 20" Annular Preventer w/ 10" F.O. Hydraulic Knife Valve Distribution orig. - Well File c- Oper/Rep c- Database C - Trip Rpt File c- Inspector AOGCC REP.: OPERATOR/RIG REP.: Witnessed by Bobby Foster Rodney Klepzig FI-022 K-25 Diverter Test copy STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [-] Oil [-] Gas [~ Suspended [--~ Abandoned [-~ Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 96-32 96-70, 398-223 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22650 4. Location of well at surface !t,-~,2~A?~.*.~ 9. Unit or Lease Name 3593' N SL, 2077' W EL, SEC. 3, T12N, R 11 E, U M.!~': ~,~"~../,:~~ ..... ,. M i lng Point Unit At top of productive interval N/A !'~~'i 10. WellNumber MPK-25 · At total depth--~ 11. Field and Pool 2842' NSL, 2315' WEL, SEC. 3, T12N, R11E, UM Milne Point Unit / Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Sands KBE = 61'I ADL 375133 12. Date Spudded3/17/96 110' Date T'D' Reached i 14' Date C°mp" Susp" °r AbanO'115' water depth' if °fish°re 116' N°' °f C°mploti°ns3/20/96 3/23/96 N/A MSLJ One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD)119. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 3955 3761 FT 3855 3683 FTJ [~Yes ]--] NoI N/A MDI 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, CBL, CDR, VSP 23. CASING~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# NTg0LHE 38' 110' 24" 250 sx Arcticset I (Approx.) 9-5/8" 40# L-80 37' 3936' 12-1/4" 768 sx PF 'E', 250 sx 'G', 100 sx PF 'E' ' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKE~ None N/A MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect with 70 bbls diesel Date First Production I Method of Operation (Flowing, gas lift, etc.) '"' ' ' ' Not on ProductionI N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAs-OIL RATIO TEST PERIOD I 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. Form 10-407 Rev. 07-01-80 Submit In Duplicate /9. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. No producing geological markers 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that th.~/~f//regoingsigned ';¢_/~ ~is true and correct to the best of my knowledge 7'9¢ Terrie Hubble ," I Title Technical Assistant III Date O~"' / MPK-25 96-32 96-70, 398-223 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. 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 Alaska hared ervices rilling To: Blair Wondzell From: Brent Reeves Date: August 28, 1998 Referencing MPK-25 Form 10-403 Request for Suspend Status, I understand your concern about the integrity of the surface cement job on the 9-5/8" casing and agree that future use of this casing will require AOGCC approval of SSD's Drilling plan prior to re-entry. The integrity of the surface casing will be verified pdor to any future work as per SSD HSE Policies. We are finalising our 99 program which includes K Pad wells and will research the use of K25 during that time. Sincerely, SSD Engineering Supervisor - WNS cc. Kathy Campoamor t998 SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: MPK-25 Rig Name: Nabors 27E AFE: 337011 Accept Date: 03/17/96 Spud Date: 03/17/96 Release Date: 03/23/96 03/17/96 Move rig. Rigged up drill floor and derrick. Lay mats, lay herculite, spot sub. Rigged up fluid system. Rigged up additional services. Rigged up diverter, riser and flowline. Rig Accepted. 03/18/96 Load BHA in pipe shed. Strap and caliper. Pull up to rig floor. MU BHA. Took several hours to thaw out CDR tool Orient MWD. Function test diverter. Test witnessed by Bobby Foster, AOGCC Field Inspector. Function test completed. Fill pits with water based mud. Finish mixing spud mud. Extend cuttings chute drag chain. Held pre-spud meeting with all personnel. Drilled to 850 ft. 03/19/96 Drilled to 1784 ft. Started drilling hydrates and hole getting sticky. Stopped to circulate at 1784 ft. Obtained required fluid properties. Drilled to 1910 ft. Started scheduled wiper trip due to drag on connections. Circulated Hi-Vis sweep. Monitor well. Dry job. Hole swept with slug. POH to 858 ft. RIH to 1910 ft, no fill, no problems. Drilled to 2350 ft. Change top screens on shakers. Mud thick due to hydrates. Drilled to 2485 ft. 03/20/96 Drilled to 2793 ft. Encountered more hydrates. Mud so fluffed up unable to keep it in pits. Cuttings tank filling up. Circulated and condition mud. Pump dry job. POOH to 1800 ft. RIH to 2793 ft. No fill, no problems. Drilled to 3425 ft. 03/21/96 Drilled to 3955 ft. Reached planned end of run. Pump sweep, circulate hole clean. Monitor well, short trip to drill collars, hole a little sticky to 2000'. RIH to 3955 ft. No problems, no fill. Circulate and condition mud for 9-5/8" casing. BHA pulled and laid out. Ran casing to 1900 ft. Operations Summary for: MPK ,_5 03/22/96 Ran casing to 3936 ft. No problems, hanger landed. Circulate and condition mud for cement job. Cut vis back. Test lines, mix and pump 768 sx of type E permafrost, followed by 250 sx Premium G. Kicked out plug with 10 bbls water. Released top plug. Displaced slurry with rig pump. Bumped plug with calculated strokes. Test casing with 3000 psi for 30 minutes, 0 psi loss. Rig up and do top job. Flushed annulus with 40 bbls water. Pumped 97 100 sx PF E cement. Nipple down diverter system. Nipple up casing head, spacer spool and adaptor flange. Test, 0 psi loss. Nipple up BOPE, riser, flowline, choke and kill lines. Test BOPE with 250 and 5000 psi. Test witnessed by John Spaulding. At end of test, while doing cellar check gas was noticed migrating up between 9-5/8" x 20" annulus. Pull test plug. Install wear ring. Blow down choke and kill line. Perform rig service and maintenance. Checked for top of top job cement. Tagged something at 44 ft. Could not verify what. 03/23/96 Rigged up logging / braided cable equipment. Conduct braided cable operations. Completed run with VSP from 55 ft to 3761 ft. Equipment work completed. Lay down drill pipe. Circulate at 2015 ft. Hole displaced with Diesel, freeze protection. Installed bore protector. Rigged down BOP stack. 03/24/96 Installed tubing hanger. Installed adaptor flange tubing spool and tree. Pressure tested successfully. Installed BPV. Removed casing spool. Clean cellar and rig release. Page 2 BPXA COMPANY B~' WELL NAM LOCATION 1 MIL~ PT t~f~:ATIO~4 2 ALASKA ~ETIC D~LiNATI~ Z7.77 AP1 m ,lOB ~ 37613 [~TE~ 17-~-96 ~LL ~BER WELL HEAD LOCATION: LAT(N/-S) 0.00 AZIMLq~H ~q]M R~]~AR¥ TABLE 'DO TARGET IS TIE IH POINT(TI?> MEASURED DEPTH TEgE Pl~'f DEFTH 112,00 INCLINATION 0.00 AZIMt~'H 0,00 LATITUDE(~U-S) 0 DEPA~'URE(E/-W) 0.00 DEP(£/-W) 0,00 197 ORIGINAL CALCULATIONS CIRCI)LAR ARC MEAStlR£D iNTERVAL VE~'.TICAL DEPTH DEPTH ft ft_ ft 112.00 0.0 248,75 124,8 248,75 S~.~., 53 89,8 338,52 427,&0 89,3 427,79 517,2~ 89,5 517,26 AZIMUTH LATITUDE N/-S Eeo ft 6.51 0,48 342,07 1,30 3,79 2.46 339,51 3.64 D~F'ARTURE D!SF'LACEM~NT ~t AZIMUTH ft ft deo O.OC) 0,00 0,06 0,49 6,5I -0,07 1,30 355,95 -0,18 2.47 355.71 -0,33 3,~. 354,82 DLS deo/ l~3ft 0,00 0,30 O,3& 0,39 0,41 _/-.06,45 696,01 785,93 975,48 89,2 6(.~,43 -3,78 89,6 6~,~ -3.65 89,9 785,~9 -3,26 1,04 94,7 &80,59 -2.21 1,26 94,8 975,~/ 0,18 262+13 4,22 276,56 4,34 266,19 4,35 241,EE) 3,~ 197,95 1,75 -0,83 4,30 348,90 -1,67 4,.¢ 339,03 -3,01 5,29 325,35 -4,78 6,11 308,54' %,20 6,44 285,~0 0,66 0,31 0,43 0,56 t.46 1068,83 1162,47 1257,4~ 135_2.18 1442,19 5'3,3 lO6&,&7 ~,6 1162,24 . 95+0 1Z57,16 94,7 1351.79 90,0 1441,77 3,~ 2,21 7,32 2,3~ 11,35 2,54 1..~/ 1.79 16..~ 1,61 192,46 -1,54 -7,08 7.25 257,73 0,33. 15'3,01 -5,20 -7,91 9,47 2~.66 0,19 185,41 -9,22 -8,55 12,58 222,55 0,38 159,00 -12,69 -8,22 i5.12 212,93 1~ lo -15,18 -7,24 16.81 21)5,49 0,21 1540,98 1635,39 1730,44 18~,49 1921,43 98,8 154.0.53 94.4 1~4,93 i: ."Y, Y8 95,('., 1825,01 ~.9 1920,95 18,36 0,~ ld~b,$'7 -17,22 -6,45 18,~ 200,52 0,69 19,~ 0,8t 156,29 -18,5& -5,93 - 19,48 197,71 0,i5 20,48 0.65 173,45 -19.71 -5,60 20.49 I95,85 0,28 2t,63 0,87 171,i9 -20,% -5,42 21,65 194,50 0,23 23.04 O.~? 174,~ -~2,51 -5,23 23,11 193,09 0,13 20-1%24 2111.18 ~04,34 t3r_J4,17 2403,~8. 93.8 2014,72 95.9 2110.47 93,2 2203,07 ii.8 22~)1.76 %',2 2399.22 ~.44 2,02 197,90 -24.88 31.~7 5.01 2¢~,13 -~J.25 41.~9 7.50 2~.,65 -~',35 56,t9 9,79 202,25 -53,03 74,~ 11,75 201,18 -5,~, 25,52 1'.~.82 1,25 - -8.03 31.30 194,86 3,16 -12,55 41.3C. 197.69 2.67 -18,69 56,23 199,4i 2,59 -~,53 74.75 l'P~.97 1,98 2485,4! 25~1,56 2677,26 2769,10 2864 62,0 2479,18 92.91 14,CQ 20.3,81 -87,32 96,1 2571.95 118.12 16.45 2¢~.37 -1i0,95 95,7 2E..63,17 146,99 18,70 198,76 -138,19 91,8 2749,48 178,~ 2t,25. 198.49 -i67,93 95,9 2638,06_ 215,~ 23,75 198.17 -202.76 -32.07 93,02 200.17 2,74 -40,94 118,27 200,25 2,56 -50,~ 147,16 20O,ll 2,40 -.60,61 178,53 199,85 2,77 -72~14 215.21 199,59 2,62 2959,91 3Qb-'5.3.A 3150.61 3245,~ ~.77 94.9 ~4,55 254.15 24,90 197,~ -240.(~ 55.4 ~10,67 294.89 25,~8 197.43 -278,88 95,2 ~)95,78 33~B,04 26,24 197,11 -5~0.07 95.1 3178.~ ~4.40 30,15 196.70 -[~-~4,44 94,1 ~9.67 4~,44 31,25 196,7& -410,45 -84,06 254.~) 199.31 1,26 -96,26 295.02 199,04 0,76 -109,~. 3~.15 198,52 2,75 -t22,54 3,54.49 198.58 2.02 -1[~5.37 432,51 198.3S 1.17 ~433.87 3529.98 3624,98 3720,28 3813,22 94,1 3339,76 481,8S 32,10 196.31 -457,81 96.1 3420,5.6 533.8/__. 33,46 195.67 -507,83 95,0 3499,13 S87,24 34,94 197,10 -ssg,0s 95.3 3576,44 642,96 ~.,62 196,68 -612,37 92,9 3650,10 6-99,63 38,53 197,06 -666._,59 =150,44 481,90 198.19 0,94 -164,77 533.89 197.96 1.46 -179,84 587.26 197,83 1,77 -196,02 642,98 197.75 1,79 -212,48 699,64 197,68 2,Q6 I,.. 25 MEASLtR~ INT~L V~',TICAL TARGET STATICS.4 AZIMUTH LATITUT_)E DEP~JRE DISPL~EM~-4T ar AZIMUTH Di,S DEP~ DE'TH SE[~ION INCiH ~ N/-S ft ft ft ft Oeo *********************************** Fg,0,~T~ TO TD ****************************************** 5~'~.00 141.6 3761.04 787.91 38,50 1~7.10 -750+98 -23~..43 78.7.92 !97,61 0.02 COMPA~ BF' ~LL NAME LDC~TtON 1 MIL~Z LOCATION 2 ALASKA I)A~~. 17 -~V-~:-96 t 50-029-22650 37,513 MA~2TIC Dh~LINATIC4q ~7.77 GRID ~'ER~ENCE ANGLE ~LL Nt~BER O **~********* ANtE)RILL ~ ......... *** D]RtA2Y ANALYSIS *~********~* Ct~S]_fLAR AEC: M£tqqOl)******...~* Mi.'- TVZ) INC Cldg ft ft .,Jeo CUMI.~. CHG I RA% AZM C~S O]MAZM CFE-: de.q d. eqil~,W, t d.m~ de-:] TO.~,~ RATE de.~/lOOft CLOSURE TOOL FACE BLS DLS,;RT ft de~ deo/l%ft ,.:teo/lOOft~*~ 112,0 t12,® 0,00 0,00 246.~ 248.75 0,41 0.41 3~,.5 3~,.52 0,26 0,67 4~,8 427.79 0.19 0,86 5i7,3 5'7 _~..26 -0,17 0,70 0,00 0.® 0,® 0,00 0,30 6,5i 6,5! 4,76 0.29 -24~44 -17~73 -27,23 0.2~ 21,73 ~ ~' -0.19 -24,29 -20,49 -27,i4 0.00 O,~b 0,00 0,00 -0,09 0,00 0,~ 0.~2 -0,45 54,17 O,~q 0,09 -0.91 67.22 0,39 0,0~ 0,00 0.00 0,41 0,02 406.5 ~,43 -0,29 0.40 696.0 655.99 0.28 785.9 7~5.89 0.~ 1.0,4 &~O.6 &~.59 0,22 1,26 'L~.5 975,~? 0.73 1.98 -0.~ -57.~. -,,-V.87 0.31 -5.57 -83.44 0.~' -10,37 -~.81 0.23 -24,~. -118.20 0.77 -43,85 -162,05 -6.22 -11.54 -25,74 -46,24 -2.05 144.47 0.~ 0.28 -2.89 12.65 0.31 0.38 -4,17 28,90 0,43 0.13 -5,69 78.30 0,56 0,14 -1.40 i28.,/,3 1,46 0.95 10~.8 1068,67 0,~ 2,21 1162,5 "^~ ~4 ~i.~,~. 0.17 2,38 1257,'.5 t257.t6 0.15 2,54 !~2.2 1~1.77 -0,74 1.77 1442.2 1441,77 -0.18 1.61 0.25 %,49 -167,54 0.18 0.55 -1&5.99 0.16 -7,60 -I74.57 ^ ~' -26,4t -Df,On -0,20 -!,~ -5.88 0.59 -27.89 -t.47 -6.30 43.95 0.33 1,21 -6..00 4.07 0.19 0.15 -5.41 65.~. 0.38 0.20 -4,06 139.~? 1.29 0.97 -6,44 82.7~ 0,21 1,21 1541,0 1~0.53 %,68 0,93 i635,4 1634.93 -0.i3 0,81 i C~ . . .7.~,4 !729,9~ -O,1A 0,65 1815,5 i825,0i 0,22 1921,4 1W~O.~ 0.12 0,99 D15,2 2014.72 1.03 2,02 , 211i.2 21!0,47 3,~ 5.01 2204.~ 2203.07 2,49 7.~ :30~,~ 2[<~I.76 2,29 9,79 ~uo~,; 25."~.Z2 1~95 11.75_.'- -0.~ 3.29 -177.03 -0.13 -4.&9 -203.71 -0.16 !7.!6 -1&5.55 0.23 -2.26 -185.8! 0.12 ~,~. -185,45 , ~o,~.4 -162.10 1 I0 '"-~ ~ 3.!2 :],23 -153,67 2.67 0.52 -153.35 ,o0 -4.4C) -1~.75 1.97 -i,07 -155,82 3,33 -4,96 24.69;' 0.56 -4.4! -1.01 1~.44 0.69 0.48 -0.12 151.&B, 0.15 0.57 0.54 133.~ 0,28 0.13 1.% 8.97 0.23 0.05 -2.36 1~4,14 0.13 0.11 2,02 42,64 1.25 1,20 1.°l.-.. 13.67 3,16 -0,24 1,27 2.67 0.53 -2,01 18,27 2.39 0,28 1.72 23.97. 1.9~ 0.42 2465,4 2479.18 2.25 14,% 25Sl.6 257i,95 2.$5 16,45 2EJ7,3 2~3.17 2.25 18.70 2769,1 2749.48 2.55 21.25 2865.0 2838.06 2.50 23.75 2,74 -0,37 -159,19 2.56 -0.45 -159,63 2.35 -1.61 2,77 -0,27 -161,S1 2,61 -0,3I -161,83 -0.45 %.46 -0.33 -4.56 2,13 2,74 0,94 -5,97 2,97 2,56 -7,06 12.96 2,40 0,16 -7.74 2,~ 2,77 0.40 -3.41 6,5-5 2.62 0,17 2959.9 2924.55 1.15 24.% 3055.4 3010.67 0.73 25.63 31X,.6 3095.7~ 2.61 28.24 3245.7 3178.75- 1.91 30.15 ~39.8 3259,67 1.10 31,~5 3433,9 32G5',76 0,65 32,10 35.~.0 34D.56 1,~. ~,46 $.4Z5,0 3499,13 1.~ 37D,3 5~76,44 1.~ ~,62 ~13.2 5550.10 1,% ~.53 1.21 -0,79 -162,62 0.76 0,05 -1~.57 -0.o~ -162,89 2,74 o~ . 2.01 -0,4! -1~,30 1.17 0.08 0.90 -0.46 -163.69 1.42 %.65 -I64.33 1.56 1.43 -162.90 1,77 -0.42 -163.32 2.05 0.41 -162.92 -0.83 0,05 -0,34 -0.43 0.09 -0.49 -0.67 1,51 -0,45 0,44 -5,64 16,12 1,26 1,43 -8.67 0,99 0.76 0.52 -8,59 3.30 2,75 2.08 -8,22 6.13 2,02 0.76 -8.:% 2.94 1,17 -6.99 16,07 0,94 0,24 -5.74 14,./8. 1,46 0.54 -4,84 29,16 1,77 0,33 -4,38 B,53 1,79 0,01 -7,69 1,68 2.06 0.~ MD TVD !~ CHG CUMINC CHG, I RATE AZM CHG £%~AZM CHG TURN RATE CLOSE,RE TOOt, FACE DLS DLS~T ~*~*~**~***~*~*~****~***~****~***~ PROOECTEI~ TO TD **************************************************** · 3955,0 ~7^1,04 -0.03 38,50 -0,02 0,02 -162.90 0,01 -3,49 154,39 0,02 t,44 Alaska hared ervlces rilling To: Blair Wondzell From: Brent Reeves Date: August 28, 1998 Referencing MPK-25 Form 10-403 Request for Suspend Status, I understand your concern about the integrity of the surface cement job on the 9-5/8" casing and agree that future use of this casing will require AOGCC approval of SSD's Drilling plan prior to re-entry. The integrity of the surface casing will be verified prior to any future work as per SSD HSE Policies. We are finalising our 99 program which includes K Pad wells and will research the use of K25 during that time. Sincerely, SSD Engineering Supervisor - WNS cc. Kathy Campoamor ALASKA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907)279-1433 FAX: (907) 276-7542 February 15, 1996 Tim Schofield, Senior Ddlling Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit MPK-25 BP Exploration (Alaska), Inc. Permit No 96-032 Surf Loc 3592'NSL, 2078'WEL, Sec. 03, T12N, R11E, UM Btmhole Loc 224'NSL, 3135'WEL, Sec. 03, T12N, R11E,UM Dear Mr. Schofield: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting ddiling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before ddiling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David W. Jo nst~~ Chairman BY ORDER OF ~MMISSION /encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation -w/o end STATE OF ALASKA .... ALASKA OIL AND GAS CONSERVATION CO,vlMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Change from Cps S/D ;2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3593' NSL, 2077' WEL, SEC. 3, T12N, R11E, UM At top of productive interval N/A At effective depth N/A At total depth 2840' NSL, 2307' WEL, SEC. 3, T12N, R11 E, UM 5. Type of well: [] Development [] Exploratory F-I Stratigraphic I~ Service 6. Datum Elevation (DF or KB) KBE = 61' 7. Unit or Property Name Milne Point Unit 8. Well Number MPK-25 9. Permit Number 96-32 10. APl Number 50-029-22650 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 3955 feet true vertical 3761 feet Effective depth: measured 3855 feet true vertical 3683 feet Plugs (measured) Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size 72' 20" 3899' 9-5/8" Perforation depth: measured N/A true vertical N/A Tubing (size, grade, and measured depth) N/A Packers and SSSV (type and measured depth) N/A Cemented MD TVD 250 sx Arcticset I (Approx.) 110' 768 sx PF 'E', 250 sx 'G', 100 sx PF 3936' 110' 3746' ORIGINAL. A]aska Oil & ea$ Cons. ComrnissionAnchorage 13. Attachments [] Description summary of proposal I--i Detailed operations program [] BOP sketch 4. Estimated date for commencing operation August 18, 1'998 16. If proposal was verbally approved Name of approver Date approved Contact Engineer Name~Number: T. Brent Reeves, 564-5376 15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Prepared By Name/Number: Terrie Hubble, 564-4628 17.1 hereby certify~hat~be~regoing isled/~ correct-~o the best of my knowledge Signed.~ T Title Drilling Engineering Supervisor Commission Use Only Conditions of Approval: Notify Commission so representative may witness Date I Approval N o:~ ~"'0'~ Plug integrity __ BOP Test __ Location clearance Mechanical Integrity Test __ Subsequent form re.~q~ 10-~-:~ Or' 4d~ [ ~.}>~t ~'¢~.~'~ ~o Approved by order of the Commission navid W, J0hnstor, "_ ~ ¢~ :ommissioner Date/~ -~ ~~¢¢-~ Form 10-403 Rev. 06/15/88 ~ Submit In Triplicate MPK-25 Operations were shutdown on this well March 24, 1996. The 9-5/8" Surface Casing was ran to 3936' and cemented with 768 sxs PF E @ 12.0ppg and 250 sxs Prem G @ 15.8ppg as the primary stage and a 100 sxs PF E Slurry was used for a top job. The casing was tested to 3000 psi. Hydrate gas percolating between the 9-5/8" and 20" annulus was identified. A CBL was run which indicated a TOC around 2850'. The cement top at the surface was tagged at 40'. The casing float equipment was not drilled up and 11.5 ppg mud with a diesel freeze protect cap was left in place. A dry hole tree was installed and tested to 5000psi. Form 10-403 was submitted on 3/27/96 and approved on 4/3/96 to request an Operations Shutdown. A Suspend status for one year and a waiver of the surface cement plug is requested due to the following: 1. The 9-5/8" was tested to 3000 psi and the float shoe with cement remains intact. 2. The equivalent hydrostatic of mud and diesel left in the casing exceeds the 8.6ppg BHP. (Mud hydrostatic at 9-5/8" shoe is 9.4EMW) 3. Dry Hole tree was tested to 5000 psi. 4. MPK-25 has potential utility in 1999 for additional infield drilling opportunities which are currently under evaluation. cc. Paper copy to MPK-25 Wellfile. ~'~.~ Shared Service Drilling WNS Engineering Supervisor (907)-564-5376 Facility M. Pt. K Pad Progress Report Well MPK-25 Page 1 Rig Nabors 27E Date 18 August 98 Date/Time 16 Mar 96 17 Mar 96 18 Mar 96 19 Mar 96 04:00-06:00 04:00-06:00 06:00-02:00 06:00-13:00 13:00 13:00-18:00 18:00 18:00-21:30 21:30 21:30-02:00 02:00 02:00-06:00 02:00-06:00 06:00-09:00 06:00-09:00 09:00 09:00-14:45 09:00-14:45 14:45 14:45-15:30 14:45-15:30 15:30 15:30-19:00 15:30-19:00 19:00 19:00-06:00 19:00-19:30 19:30 19:30-06:00 06:00-06:00 06:00-16:00 16:00 16:00-18:30 18:30 18:30-20:00 20:00 20:00-21:00 21:00 21:00-21:30 21:30 21:30-22:00 22:00 22:00-04:00 04:00 04:00-04:30 04:30 04:30-06:00 06:00-10:00 06:00-10:00 10:00 10:00-16:00 10:00-16:00 16:00 16:00-06:00 Duration 2 hr 2 hr 20hr 7 hr 5 hr 3-1/2 hr 4-1/2 hr 4hr 4hr 3hr 3hr 5-3/4 hr 5-3/4 hr 3/4 hr 3/4 hr 3-1/2 hr 3-1/2 hr llhr 1/2 hr 10-1/2 hr 24 hr 10hr 2-1/2 hr 1-1/2 hr lhr 1/2 hr 1/2 hr 6 hr 1/2 hr 1-1/2 hr 4 hr 4 hr 6 hr 6 hr 14 hr Activity Move rig Rigged down Drillfloor / Derrick Move rig (cont...) Rigged down Drillfloor / Derrick (cont...) Work completed, equipment laid out Rigged up Drillfloor / Derrick Work completed - Drillfloor / Derrick in position Rigged up Fluid system Work completed - Fluid system in position Rigged up Additional services Equipment work completed Nipple up Divertor Rigged up Divertor Nipple up Divertor (cont...) Rigged up Divertor (cont...) Equipment work completed BHA run no. 1 Made up BHA no. 1 Stopped: To test equipment Test well control equipment Tested Divertor Function test completed satisfactorily Fluid system Fill pits with Water based mud Completed operations BHA run no. 1 Held safety meeting Completed operations Drilled to 850.0 ft BHA run no. 1 (cont...) Drilled to 1784.0 ft (cont...) Stopped: To circulate Circulated at 1784.0 ft Obtained req. fluid properties - 200.00 %, hole vol. Drilled to 1910.0 ft Started scheduled wiper trip: due to Drag on connections Circulated at 1910.0 ft Hole swept with slug - 120.00 % hole volume Pulled out of hole to 858.0 ft At BHA R.I.H. to 1910.0 ft On bottom Drilled to 2350.0 ft Reached limitations of Circulation rate Serviced Mud shakers Equipment work completed Drilled to 2485.0 ft BHA run no. 1 (cont...) Drilled to 2793.0 ft (cont...) Reached limitations of Circulation rate Fluid system Circulated at 2793.0 ft Obtained req. fluid properties - 400.00 %, hole vol. BHA run no. 1 Facility M. Pt. K Pad Progress Report Well MPK-25 Page 2 Rig Nabors 27E Date 18 August 98 Date/Time 20 Mar 96 21 Mar 96 22 Mar 96 16:00-16:30 16:30 16:30-17:00 17:00 17:00-06:00 06:00-15:00 06:00-15:00 15:00 15:00-16:00 15:00-16:00 16:00 16:00-18:00 16:00-18:00 18:00 18:00-19:30 18:00-19:30 19:30 19:30-22:00 19:30-22:00 22:00 22:00-01:30 22:00-01:30 01:30 01:30-06:00 01:30-06:00 06:00-09:00 06:00-09:00 09:00 09:00-16:00 09:00-10:30 10:30 10:30-12:00 12:00 12:00-13:00 13:00 13:00-13:30 13:30 13:30-15:00 15:00 15:00-16:00 16:00 16:00-17:30 16:00-17:30 17:30 17:30-01:00 17:30-20:00 20:00 20:00-01:00 01:00 01:00-02:00 01:00-02:00 02:00 02:00-06:00 Duration 1/2 hr 1/2 hr 13hr 9hr 9hr 1 hr lhr 2hr 2 hr 1-1/2 hr 1-1/2 hr 2-1/2 hr 2-1/2 hr 3-1/2 hr 3-1/2 hr 4-1/2 hr 4-1/2 hr 3hr 3hr 7hr 1-1/2 hr 1-1/2 hr lhr 1/2 hr 1-1/2 hr 1 hr 1-1/2 hr 1-1/2 hr 7-1/2 hr 2-1/2 hr 5 hr 1 hr 1 hr 4 hr Activity Pulled out of hole to 1800.0 fi Began precautionary measures R.I.H. to 2793.0 ft On bottom Drilled to 3425.0 ft BHA run no. 1 (cont...) Drilled to 3955.0 ft (cont...) Reached planned end of run - Section / well T.D. Fluid system Circulated at 3955.0 ft Obtained clean returns - 120.00 % hole volume BHA run no. 1 Pulled out of hole to 3955.0 ft At top of check trip interval BHA run no. 1 R.I.H. to 3955.0 ft On bottom Fluid system Circulated at 3955.0 ft Obtained req. fluid properties - 150.00 %, hole vol. BHA run no. 1 Pulled BHA BHA Laid out Run Casing, 9-5/8in O.D. Ran Casing to 9-5/8in (1900.0 ft OD) Run Casing, 9-5/8in O.D. (cont...) Ran Casing to 3936.0 ft (9-5/8in OD) (cont...) Hanger landed Cement: Casing cement Circulated at 3936.0 ft Obtained req. fluid properties - 250.00 %, hole vol. Mixed and pumped slurry - 348.000 bbl Cement pumped Displaced slurry - 281.500 bbl Plug bumped Tested Casing Pressure test completed successfully - 3000.000 psi Rigged up Drillfloor / Derrick Equipment work completed Cement pumped. Rigged down Divertor Equipment work completed Wellhead work Installed Wellhead integral components Equipment work completed Nipple up BOP stack Rigged up BOP stack Equipment work completed Tested BOP stack Pressure test completed successfully - 5000.000 psi Wellhead work Installed Bore protector Equipment work completed Suspend operations Facility M. Pt. K Pad Progress Report Well MPK-25 Page 3 Rig Nabors 27E Date 18 August 98 Date/Time 23 Mar 96 02:00-06:00 06:00 06:00-08:00 08:00 08:00-11:00 11:00 11:00-15:00 15:00 15:00-16:00 16:00 16:00-03:00 16:00-16:15 16:15 16:15-17:00 17:00 17:00-19:00 19:00 19:00-20:00 20:00 20:00-22:30 22:30 22:30-01:30 01:30 01:30-03:00 03:00 03:00-06:00 03:00-03:30 03:30 03:30-06:00 06:00 06:00-12:00 06:00-08:00 08:00 08:00-09:30 09:30 09:30-10:00 10:00 10:00-10:30 10:30 10:30-12:00 12:00 12:00-06:00 12:00-00:00 Duration 4 hr 2 hr 3 hr 4 hr 1 hr llhr 1/4 hr 3/4 hr 2 hr 1 hr 2-1/2 hr 3hr 1-1/2 hr 3 hr 1/2 hr 2-1/2hr 6hr 2hr 1-1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 18hr 12 hr Activity Rig waited: Equipment Resumed operations Rigged up Logging/braided cable equipment Work completed - Logging/braided cable equipment in position Conduct braided cable operations - 7/32 size cable Completed run with VSP from 2500.0 ft to 3761.0 ft Conduct braided cable operations - 7/32 size cable Completed run with VSP from 55.0 ft to 3106.0 ft Rigged down Wireline units Equipment work completed Suspend operations Held safety meeting Completed operations Laying down pipe R.I.H. to 2540.0 fl Stopped: To pick up/lay out tubulars Pulled out of hole to 0.0 ft At BHA lay down drill pipe R.I.H. to 2015.0 ft Stopped: To circulate Circulated at 2015.0 ft Obtained req. fluid properties - 300.00 %, hole vol. inject 230 bbl mud down MPK-17 Circulated at 2015.0 ft Hole displaced with Diesel - 100.00 % displaced Freeze protect Pulled out of hole to 30.0 fl At Wellhead: 30.0 ft lay down drill pipe 64 jts Wellhead work NO ACCIDENTS NO SPILLS 282 DSLTA Installed Bore protector Eqpt. work completed, running tool retrieved Rigged down BOP stack Equipment work completed Wellhead work (cont...) NO ACCIDENTS NO SPILLS 282 DSLTA Installed Tubing hanger Equipment work completed install adaptor flange tubing spool and tree and Tested All tree valves Pressure test completed successfully - 5000.000 psi Removed Hanger plug Equipment work completed Installed Hanger plug Equipment work completed INSTALL B.P.V. Removed Casing spool Equipment work completed CLEAN CELLAR RIG RELEASED AT 1200 3/23/96 Move rig Rig moved 100.00 % Facility ! M. Pt. K Pad Progress Report Well MPK-25 Rig Nabors 27E Page Date 4 18 August 98 Date/Time 24 Mar 96 00:00 Duration Activity At well location - Cellar STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work Drill [] Redrill FIIlb. Type of well. Exploratoryl-I Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen []1 Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 61 feet Maine Point Unit 3. Address 6. Property Designation P. O. Box 196612, Anchoracle, Alaska 99519-6612 ADL 375133 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 3592' NSL, 2078' WEL, SEC. 3, T12N, R11E Maine Point Unit At top of productive interval 8. Well number Number 405' NSL, 3079' WEL, SEC. 3, T12N, R11E MPK-25 2S100302630-277 At total depth 9. Approximate spud date Amount 224' NSL, 3135' WEL, SEC. 3, T12N, R11E 02/28/96 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth (MD and TVD) property line ADL 375132 3135 feet MPK-17, e1'@2099'TVD feet 2560 8708' MD/7533'TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 2000 feet Maximum hole angle42, z¢ o Maximum surface 3005 psig At total depth (TVD) 7529'/3758 psig 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.1# NTaOLHE Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# L-80 Btrc 3877' 31' 31' 3908' 3701' 768 sx PF 'E', 250 sx 'G', 250 sx PF 'E' 8-1/2" 7" 26# L-80 Btrc & Mod B 8678' 30' 30' 8708' 7532' 247 SX Class 'G' 19.To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface V b '" Intermediate Production Liner FEB 1 2. 1"J96 Perforation depth: measured true vertical Alas~ Oil & Gas Cons. Commission 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter SketciC~°~ll~ing program [] Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby~y that the for~egoing i~ tt~ue and correct to the best of my knowledge ?y;~4_~,y Date Signed ~'~'T7 ~ O~..~_,,L~,~'-~ ; TitleSoniorDrillingEnginoor /i2/(/6. /- ,,6ommission Use Only Permit Number APl' number Appr~gval date . ISee cover letter ~'-'.'~:2- 50-0.~..'~- 2_ 2_.. ~' ,~"0 ~:;,('--/"~'--- ,¢"~:~ Ifor other requirements 'Conditions of approval Samples required [] Yes J~'NO Mud log required []Yes ~ No Hydrogen sulfide measures-~ Yes ~ No Directional survey required [] Yes [] No Required workin9 pressUre for BOPE []2M; []3M; ,I~SM; EIIOM; I-I15M; Other: Original Signed By by order of // Approved by David W. Johnston Commissioner ~ne commission Date~ Form 10-401 Rev. 12-1-85 Submit cate Well Name: I MPK-25 I Well Plan Summary ]Type of Well (producer or injector): ] Kuparuk Producer Surface Location: 3592' FSL 2078' FEL Sec 3 T12N R11E UM., AK. Target Location: 405' FSL 3079' FEL Sec 3 T12N R11E UM., AK. Bottom Hole 224' FSL 3135' FEL Sec 3 T12N R11E UM., AK. Location: Note: Target & BHL footages are based on assumed true and square sections and are not surveyed legal locations. ]AFE Number: ]337011 ] ]Rig: ]Nabors 27E [ I Estimated Start Date: ]February 20, 1996 Operating days to drill and case: [MD: 18708 I ITVD: 17533'BKB I IKBE: 161'1 Well Design (conventional, slimhole, I Ultra Slimhole, 7" Longstring etc.): Formation Markers: Formation Tops MD TVD Formation Pressure/EMW Base permafrost 1811 1811 n/a NA (Top Schrader) 5105 4581 1905 psig / 8.0 ppg OA 1955 psig / 8.0 ppg Base Schrader Bluff 5398 4796 1995 psig / 8.0 ppg Top HRZ 7484 6391 n/a Base HRZ n/a Kupark D Shale 7908 6781 n/a Kuparuk C 8153 7011 3650 psig / 10 ppg TKA 8408 7251 3669 psig / 10 ppg Total Depth 8708 7532 n/a Casing/Tubin Pro: ;ram: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg MD/TVD MD/TVD O.D. 30" 20" 91.1# NT80LHE weld 80 3 2' 112/112 12 1/4" 9 5/8" 40# L-80 btrc 3877' 31' 3908/3701 8 1/2" 7" 26# L-80 Btrc & 6178 30' 8708/7532 Mod B 2500 N/A (tbg) 2-7/8" 6.5# L-80 EUE 7879' 29' 7908/6781 8rd Internal yield pressure of the 7" 26# casing is 7240 psi. Worst case surface pressure would occur with a full column of gas to the reservoir at 7529' TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 3758 psi is 3005 psi, well below the internal yield pressure rating of the 7" casing. The Modified Buttress 7" 26# will be run on bottom. Mud Program: Special design considerations LSND freshwater mud. Special attention to gravel and coal in the surface hole, with appropriate viscosity and weight to control each. The use of frequent short trips as per the updated pad data sheet are encouraged. Surface Mud Properties: I Spud Mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 80 15 8 10 9 8 to to to to to to to 9.6 100 35 15 30 10 15 Production Mud Properties: I LSND Density Marsh Yield I0 sec 10 rain pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 40 15 3 7 8.5 6-10 to to to to to to to 10.5 50 20 10 20 9.5 4 - 6 Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: I KOP: 12000' Maximum Hole Angle: Maximum Dog Leg: Inclination in target: Close Approach Well: 42.71 degrees _< 4 degrees 20 Degrees MPK-17; 61 Feet at 2099 feet TVD MPK-17 is the only closest well, and will be drilled and cased, but not perforated and therefore will be treated as a plugged well. This will allow MPK-25 wellpath to be drilled as per BP's close approach guidelines. The well path should be followed as close as possible to ensure we do not compromise the proximity tolerances. Disposal: Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A. pit can be opened in emergencies by notifying Karen Thomas (564-4305) The Milne Point reserve with request. Fluid Handling: All drilling and completion fluids can be annular injected after allowing the cement on the 7" casing cement job to cure 6 hours following CIP. Request for AOGCC Approval Disposal of Drilling Wastes (20AAC25.254) 1. Approval is requested for Annular Pumping for K Pad well MPK-25 to be drilled, and any well on the pad/drillsite previously permitted for disposal activities by AGOCC. 2. The Base of the Permafrost for all wells located in the Milne Point Unit is 1750 feet. Aquifers in the Milne Point Unit have been exempted from Class II injection activities by the AOGCC by Aquifer Exemption Order #2 as referenced in Area Injection Order #10. 3. The receiving zone to which the fluids will migrate is identified as the Prince Creek geological formation at 2500 - 3300' TVD. The confining layer is the Sagavanirktok Shale defined by logs between 2500 'TVD. Additional data which demonstrates the confining layers, porosity, and permeability of the injection zone was submitted to the AOGCC on 7-24-95. 4. There are no wells on Milne Point K Pad. There may be additional unidentified wells within a quarter mile distance from the subject well. There are no domestic or industrial water use wells located within one mile of the project area. 5. The drilling wastes to be disposed of during this operations can be defined as drilling mud, cement contaminated drilling mud, and drill cuttings; rig wash fluid (inclusive of rig boiler blow down, and mud and cement rinse water of associated rig equipment, completion fluids (seawater and brine), formation fluids, reserve pit fluids, and drill rig domestic waste water. (Note: if you plan to dispose of fluids OTHER than those outlined above you must list them on the request) The maximum volume to be disposed of in the annulus is 35,000 bbls. Fluid densities will range from 8.3 to 13.0 ppg. Any deviation from this program must be detailed separately. 6. The 9.625 "surface casing shoe will set at 3908'md 3701 ('tvd) and cemented with 768 "E" and 250 "G" sacks cement. This depth is below the base of the permafrost (1750' TVD) and into the top of the Prince Creek formation which has a long established history of annular pumping at Milne Point. The break down pressure of the Prince Creek formation is 13 to13.5 ppg equivalent mud weight. 7. The burst rating (80%) for the 9.625" 40# 'surface casing is4600 psi. The collapse rating (80%) for the7" 26# 'intermediate/production casing is 4325 psi. 8. The Maximum Allowable Surface Pressure while annular pumping is the lesser of 2000 psi or the calculated pressure according to the following equation: MASP (psi) = (Max Breakdown ppg-8.3 ppg) X 0.052 X Surf Csg Shoe TVD MASP (psi) - 1000 psi 9. The maximum pressure imposed at the surface casing shoe is calculated according to the following equation: Max Press @ Surf Csg Shoe (psi) - .052 x Max Breakdown ppg x Surf Csg Shoe TVD Max Prss at Surf Csg Shoe =2598 psi This pressure is less than the 80% burst and collapse casing pressures calculated in #'~~~ 1 0. Additional data supplied as needed. F E8 t 2 199 ; DO NOT EXCEED 35,000 BELLS IN ANY ANNULUS. ~aska 0~t & Gas ~ns. ~mmis~i0~ DRILLING HAZARDS AND RISKS: See both the NEW Milne Point K-Pad Data Sheet prepared by Pete Van Dusen for information on the Cascade wells , and review recent wells drilled on E Pad. Most of the trouble time on recent wells has been due to equipment mechanical problems with the surface equipment, rather than formation drilling problems. The MPU PE group will be perforating, and cleaning out wells shortly after the rig drills and completes them. This will make the near rig area congested and as a result potentially hazardous. Ensure personnel use caution moving around adjacent production activities. Lost Circulation: The Kuparuk sands and a number of shallower intervals typically are highly fractured. Wells on F Pad have lost varying amounts of mud (from 70 to 1000 bbls) drilling through or near the top of the Kuparuk sands, especially while running casing and cementing. Be prepared to treat these losses while drilling initially with LCM treatments. There has not been any appreciable amount of lost circulation in surface hole on any of the F Pad wellls to date. This is due to setting surface pipe deeper to cover the Schrader Bluff interval which might break down at the mud weights required to TD the well. Stuck Pipe Potential: Well MPF-53 was stuck coming out on the short trip at surface casing point. Proir to this incident there was only minor indications that the gravel and coal were present. It appears that we dragged the gravel up into the bottom of the curve and reduced our ability to move up or down. Then we lost the ability to circulate when the hole collapsed. Subsequent fishing operations were not successful and a very expensive BHA was lost in the hole from 2516 - 3342. Kick Tolerance: The surface casing setting depth for this well allows a kick tolerance of 34.7 bbl influx (Gas) based on a 12.5 ppg LOT at the 9-5/8" casing shoe and a estimated reservoir pressure of 3594 psig (9.6 ppg equivalent MW). Trip Schedules are required for all trips. All trips will be performed with a trip tank or one pit isolated for use as a trip tank. Formation Pressure: The maximum expected pore pressure for this well is 10 ppg EMW (3646 psi @ 7011' ssTVD). There has been no injection in this region since then, therefore the reservoir pressure should not exceed this estimate. We will continue to take the conservative approach to circulate the well until stable before tripping or before running casing. WATER USAGE Have the water truck drivers track the water usage on a daily log. Send a copy of this log to Dennise Casey in the Anchorage Office on a monthly basis. MP K-25 Proposed Summary of Operations , . o , o o , 10. 11. 12. 13. 14. 15. 16. 17. 18. 17. Drill and Set 20" Conductor. Weld an FMC landing ring for the FMC Gen 5A Wellhead on the conductor. Prepare location for rig move. MIRU Nabors 27E drilling rig. NU and function test 20" Diverter system. Ensure the diverter is as per AOGCC specifications and is approved by AOGCC supervisor. Build Spud Mud. Drill 12-1/4" surface hole to 3908' md (3701' tvd).. Run and cement 9-5/8" casing. ND 20" Diverter, NU and Test 13-5/8" BOPE. Run Wear Bushing. RIH w/PDC bit and Double Power Section PDM (motor). Test the 9-5/8" casing to 3000 psig and plot pressure vs volume for LOT baseline. Drill out float equipment and 10 feet of new formation, Perform a LOT to a maximum of 12.5 ppg as per Recommended Practices Manual. Record pressure vs. cumulatrive volume for LOT test for well file. Follow Pad Data Sheet short trip guidelines. Drill 8-1/2" hole to Base of Schrader Bluff at 5398' MD (4796' TVD). POOH to run MRIL wireline logs. Drill 8-1/2" hole to TD at 8708' MD (7533' TVD). (Note: This hole section will be logged with LWD Triple Combo (GR/Res/Neu/Dens). Pull Wear Bushing, and Change Pipe Rams to 7". Run and Cement 7" casing with 1 stage cement program. Test casing to 3500 psi and freeze protect wellbore to 2000' TVD with diesel. Closely monitor casing running loads for drag. Make sure there is a circulating head for the topdrive before starting to run casing. ND BOPE and NU dry hole tree. Release rig to MPK-38. Note: This well will be ROPE perforated, and cleaned out with a completion rig and prior to running the ESP completion. MIRU workover completion unit. ND dry hole tree. NU BOPs and test. PU and RIH with 3.5" DP and 6" bit, clean out to PBTD. TOOH. PU and RIH with ROPE perforating string (procedure to be distributed later with perforation intervals). PU and RIH with 2-7/8" EUE 8rd tubing with Electric Submersible Pump (ESP) completion. Set 2 way check. ND BOPE and NU tree and test. Pull two way check, freeze protect, set BPV, close valves. Test tree. RDMO with workover/completion rig. POST RIG WORK MPK-25 Cement Calculator copy Milne Point Cement and Centralizer Calculations Well MPK-25 Surface (1 Stage) Cement Job cement Type E G Hole Size 12.25 Yeild (cfs) 2.17 1.15 Casing Size 9.625 Weight (ppg) 1 2 15.8 BPF 0.0558 BPF + 30% 0.0725 BPF + 100% 0.1116 Depth BBLS Cu. Ft. Sacks Top of Cemenl Shoe Depth ~~~' ~,,',~,~ Calculated G Tail Volume 623 51.2 288 250 3285 E Lead Volum6 1500 167.3 940 433 1785 E Tail Volume 1785 129.4 727 335 0 Total E 7 6 8 Total G 2 5 0 9-5/8" Bows I 0 Production 1-Stage Cement Job Cement Yield Hole Size 8.5 Silicalite Slurry! 2.81 Casing Size 7 BPF 0.0226 BPF + 30% 0.0294 Top of Cemenl Stage 1 BBLS Cu. Ft. Sacks Calculated Formation Top~'~~ 123 693 247 4605 _ . , Centralizers 186 __ Turbulators Total G ST1 247 Total ST Blade: 187 MPK-25 WELL 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 9-5/8" CIRC. TEMP 80 deg F at 4000' TVDSS. SPACER: 75 bbls fresh water. LEAD CEMENT TYPE: Type E Permafrost ADDITIVES: Retarder WEIGHT: 12.0 ppg YIELD: 2.17 ft3/sx MIX WATER: 11.63 gal/sk APPROX #SACKS: 768 THICKENING TIME: Greater than 4 hrs at 50° F. TAIL CEMENT TYPE: Premium G ADDITIVES' 0.2% CFR-3, 0.2% Halad~344, 2.0% CaC12 WEIGHT: 15.8 ppg APPROX #SACKS: 250 FLUID LOSS: 100-150 cc YIELD:I.15 ft3/sx MIX WATER: 5.0 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. FREE WATER: 0 TOP JOB CEMENT TYPE: Type E Permafrost ADDITIVES: Retarder WEIGHT: 12.0 ppg YIELD: 2.17 cu ft/sk. MIX WATER: 11.63 gal/sk APPROX NO SACKS: 250 CENTRALIZER PLACEMENT: 1. 1 Bowspring centralizer per joint of 9-5/8" casing on the bottom 10 joints above the FS. '2. Place all centralizers in middle of joints using stop collars. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 bpm. Do not overdisplace by more than 1/2 the shoe joint. Mix slurry on the fly -- batch mixing is not necessary. Make sure to fill the casing every joint to avoid having to shut down to fill the casing. Casing has been stuck while we were shut down filling only 5 joints. CEMENT VOLUME: 1. The Tail Slurry volume is a standard 250 sacks is calculated to cover the 9-5/8" Casing Shoe with 30% excess. MPK-25 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON STAGE I CEMENT JOB ACROSS THE KUPARUK and SCHRADER BLUFF: CIRC. TEMP: 115° F BHST 120 deg F at 7040' TVDSS. SPACER: 50 bbls fresh water . 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. CEMENT TYPE: Premium G ADDITIVES: 0.3% CFR-3, 30#/SK Silicalite, 1.7% Halad 344 WEIGHT: 12.25 ppg YIELD: 2.81 cu ft/sk APPROX # SACKS: 247 FLUID LOSS: < 45cc/30 min @ 140° F MIX WATER: 16 gal/sk THICKENING TIME: 4 1/2 hrs @ 140° F FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: 1. 7" x 8-1/4" Straight Blade Rigid Centralizers-- two per joint on the bottom 17 joints of 7" Casing (34 total). This will cover 200' above the C Sand. 2. 7" x 8-1/4"Straight Blade Rigid Centralizers-- one per joint from 6900' - 6100' to cover the Schrader Bluffs Sands (20Total). 3. Run one 7" x 8-1/4"Straight Blade Rigid Centralizer inside the 9-5/8" casing shoe. 4. Total 7" x 8-1/4" Straight Blade Rigid Centralizers needed is 55. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 8-10 bpm. Batch mixing is not necessary. CEMENT VOLUME: 1. Stage 1 cement volume is calculated to cover 500' md above the NA Top with 30% excess. HPK- 5 EST (g E) Wp 1 CRITICAL PFIINT DATA N/S ON ON ON E/W OE OE OE 58O S 181W 1484 S 464 W 1674 S 523 ~ 2947 S 921 W 3O88 S %5 W 3106 S 971 W 3186 S gg6 W ~70 S 1022 W MD Ina Azl. TVD TIE IN 0 0.00 197.36 0 Base 1811 0,00 197,36 1811 PepmaFrost KOP / START 2000 0.00 197.36 2DO0 OF BUILD 2.50/100 END OF BUILD 3708 42.71 197,36 3554 NA Sands 5105 42.71 197.1~o 4581 Base Schrader 5398 42.71 197,36 4796 START OF 6718 42.71 197.36 5766 C~VE ~ 2.00/100 THRZ 7484 27.39 197.36 6391 END OF CURVE 7853 20.00 197.36 6729 TKUD 7908 20.00 197,36 6781 Target / TKUC1 8153 20.00 197.36 7011 TKUA 8408 20.00 197.36 7251 7011 3186 S 996 W 583519 6002530 ? CASING PDINT DATA t OD MI) Ina Azl TVD N/S E/W 5/8 ,i 3908 48.71 197,36 3701 710 S 222 W 'n lO7.RA 7%52 ~.'-~R R tAFi~ ~ T~r,M~L Nmm~ TVD NS EW ~'id X Grid Y I Target VERTICAL VIEW SCALE 1000 Ft, / DIVISIDN TVD REF: WELLHEAD VERTICAL SECTIBN REF: WELLHEAD 1000 1811 2000 3000-- 3554 4000-- 4581 4796 5000-- 608 0.00 ~ 0 MD TIE IN 0.00 8 1811 MD Base PerMaFrost 0.00 @ 2000 MD KOP / START OF BUILD @ 2.50/100 Pt 2,50 8 2100 MD 5.00 @ 2200 MD 7.50 e 2300 MD 10.00 @ 2400 MD 18.50 @ 250(] MD 15.00 (~ 2600 MD 17,50 ~ 27OO MD 20.00 @ 2800 MD 22.50 e 2900 MD 27.50 @ 310(i) MD 32.50 @ 3300 MD 37.50 @ 3500 MD 42.71 @ 3708 MD END OF BUILD g 5/8 in OD, @ 3g08 MD, 3701 TVD 1555 42.71 8 5105 MD NA S~nds 42,71 ~ 5398 MD Base Sch~aden 1754 2112/96 i 1:38 am HF1RIEI]NTAL VIEW (TRUE NF1RTH) SCALE ~50 F~. / DIVISIDN SURVEY REP WELLHEAD 750 1500 1250 IOOD 750 500 250 0 250 [9.18.42 W ~4 9.00 E Halliburton Energy Services - Drilling Systems PSL Proposal Report Calculated using the Minimum Curvature Method Computed using WIN-CADDS REV2.1.B Vertical Section Plane: 197.36 deg. Page 1 Date: 2/12/96 Time: 11:45 am Wellpath ID: MPK-25 Wpl Last Revision: 1/29/96 T O T A L GRID Coordinates Rectangular Offsets Northing Easting (ft) (ft) (ft) (ft) Closure Vertical Dist. Dir. Section (ft) (deg.) (ft) Build Walk DLS Cum. Rate Rate Dogleg (dg/100ft) (dg/100ft) (dg/100ft) (deg) Expected Total Rectangular Coords (ft) fit) Max Hor Min Hor Dir. Vert Error Error Max Err Error (ft) (ft) (deg.) (ft) Survey Tool )0 0.00N 0.00 E )0 O.OON 0.00 E ~0 0.00N 0.00 E )0 2.08 S 0.65W }0 8.32 S 2.6CW )0 18.71 S 5.85W )0 33.23 S 10.3¢'W )0 51.85 S 16.21W )0 74.54 S 23.3EW )0 101.24 S 31.65W )0 131.92 S 41.24W )0 166.51 S 52.05W )0 204.95 S 64.0fiW 30 247.16 S 77.2fiW 30 293.06 S 91.61W 00 342.57 S 107.08W 00 395.60 S 123.6~W 00 452.03 S 141.3£W 00 511.77 S 159.93W 00 574.69 S 179.64W 6005727.00 584479.00 0.0¢@ 0.00 0.00 6005727.00 584479.00 6005727.00 584479.00 6005724.92 584478.37 6005718.65 584476.49 6005708.23 584473.36 6005693.66 584468.99 6005674.98 584463.38 6005652.22 584456.55 6005625.42 584448.50 6005594.64 584439.26 6005559.93 584428.84 6005521.36 584417.26 6005479.01 584404.55 6005432.95 584390.72 6005383.27 584375.81 6005330.07 584359.83 6005273.45 584342.83 6005213.51 584324.84 6005150.37 584305.88 0.0C@ 0.00 0.00 O.OC@ 0.00 0.00 2.18@197.36 2.18 8.72@197.36 8.72 19.61@197.36 19.61 34.82@197.36 34.82 54.33@197.36 54.33 78.0¢@197.36 78.09 106.03@197.36 106.07 138.21@197.36 138.21 174.46@197.36 174.46 214.73@197.36 214.73 258.95@197.36 258.95 307.05@197.36 307.05 358.92@197.36 358.92 414.43@197.36 414.47 473.6C@197.36 473.60 536.1~@197.36 536.19 602.12@197.36' 602.12 0.00 0.00 0.00 0.0 0.00N 0.00 E 0.00 0.00 0.00 0.0 0.00N 0.00 E 0.00 0.00 0.00 0.0 0.00N 0.00 E 0.00 0.00 0.00 0.00 5.00 5.00 0.00 2.62 5.46 5.46 0.00 2.91 2.50 0.00 2.50 2.5 2.08 S 0.65W 5.70 5.70 287.36 3.07 2.50 0.00 2.50 5.0 8.33 S 2.5¢W 5.96 5.93 287.36 3.24 2.50 0.00 2.50 7.5 18.73 S 5.8ON 6.26 6.15 287.36 3.44 2.50 0.00 2.50 10.0 2.50 0.00 2.50 12.5 2.50 0.00 2.50 15.0 2.50 0.00 2.50 17.5 2.50 0.00 2.50 20.0 2.50 0.00 2.50 22.5 33.26 S 10.2¢W 51.91S 16.03W 74.63 S 23.0£W 101.38 S 31.1¢W 132.12 S 40.58W 166.79 S 51.14W 6.62 6.37 287.36 3.66 7.07 6.58 287.36 3.91 7.64 6.79 287.36 4.17 8.36 7.00 287.36 4.46 9.23 7.21 287.36 4.78 10.29 7.42 287.36 5.12 205.33 S 62.84W 11.52 7.63 287.36 5.48 247.66 S 75.67W 12.92 7.85 287.36 5.88 293.70 S 89.58W 14.50 8.08 287.36 6.30 2.50 0.00 2.50 25.0 2.50 0.00 2.50 27.5 2.50 0.00 2.50 30.0 2.50 0.00 2.50 32.5 2.50 0.00 2.50 35.0 2.50 0.00 2.50 37.5 2.50 0.00 2.50 40.0 2.50 0.00 2.50 42.5 343.36 S 104.55W 396.57 S 120.5fiW 453.20 S 137.55W 513.16 S 155.51W 576.34 S 174.38W 16.26 8.32 287.36 6.75 18.17 8.56 287.36 7.23 20.25 8.81 287.36 7.74 22.48 9.07 287.36 8.29 24.85 9.33 287.36 8.87 MWD BPHM-PBD BPHM-PBD BPHM-PBD BPHM-PBD BPHM-PBD BPHM-PBD BPHM-PBD BPHM-PBD BPHM-PBD BPHM-PBD BPHM-PBD BPHM-PBD BPHM~PBD BPHM-PBD BPHM-PBD BPHM-PBD BPHM-PBD BPHM-PBD BPHM-PBD 26 580.03 S 181.31W 6005145.01 584304.27 607.71@197.36 607.71 2.50 0.00 2.50 42.7 581.70 S 175.9¢W 25.05 9.36 287.36 8.91 BPHM-PBD Halliburton Energy Services - Drilling Systems PSL Proposal Report Page 2 Date: 2/12/96 Wellpath ID: MPK-25 Wpl T O T A L GRID Coordinates Rectangular Offsets Northing Easting (ft) (ft) (ft) (ft) 40.00 lb/ft. 0 709.50 S 221.78W 6005015.11 584265.27 743.315@197.36 743.36 2 1484.40 S 464.01W 6004237.60 584031.82 1555.23@197.36 1555.23 8 1673.80 S 523.21W 6004047.56 583974.76 1753.67@197.36 1753.67 Closure Vertical Build Walk DLS Cum. Expected Total Max Hor Min Hor Dir. Vert Dist. Dir. Section Rate Rate Dogleg Rectangular Coords Error Error Max Err Error (ft) (deg.) (ft) (dg/100ft) (dg/100ft) (dg/100ft) (deg) (ft) (ft) (ft) (ft) (deg.) (ft) Survey Tool 0.00 0.00 0.00 0.00 0.00 0.00 0.00 42.7 709.50 S 221.78W 0.00 0.00 0.00 0.00 BPHM-PBD 0.00 42.7 1489.56 S 447.5CW 59.61 16.57 287.36 14.99 BPHM-PBD 0.00 42.7 1679.69 S 504.3TW 66.95 18.16 287.36 16.39 BPHM-PBD 6 2528.22 S 790.25'3hr 6003190.28 583717.31 2648.8t5@197.36 2648.86 0.00 0 2591.72 S 810.14W 6003126.57 583698.18 2715.3¢@197.36 2715.39 -2.00 .0 2652.69 S 829.2CW 6003065.39 583679.80 2779.27@197.36 2779.27 -2.00 ,0 2711.06 S 847.45W 6003006.82 583662.21 2840.43@197.36 2840.43 -2.00 s0 2766.76 S 864.8fiW 6002950.93 583645.43 2898.7¢@197.36 2898.79 -2.00 D0 2819.73 S 881.42W 6002897.79 583629.47 2954.28@197.36 2954.28 -2.00 }0 2869.89 S 897.1CW 6002847.46 583614.35 3006.83@197.36 3006.83 -2.00 ~0 2917.19 S 911.88W 6002800.01 583600.10 3056.3~@197.36 3056.39 -2.00 ;6 2946.74 S 921.12W 6002770.35 583591.19 3087.35@197.36 3087.35 -2.00 4 2961.56 S 925.75W 6002755.48 583586.73 3102.88@197.36 3102.88 -2.00 )0 3002.96 S 938.7CW 6002713.95 583574.25 3146.25@197.36 3146.25 -2.00 l0 3041.33 S 950.6¢'W 6002675.45 583562.69 3186.4~@197.36 3186.46 -2.00 3076.63 S 961.73W 6002640.03 583552.05 3223.44@197.36 3223.44 -2.00 3088.36 S 965.35"W 6002628.26 583548.51 3235.73@197.36 3235.73 -2.00 ~4 3106.39 S 971.03W 6002610.17 583543.08 3254.62@197.36 3254.62 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 42.7 2537.41 S 760.8%V 100.13 25.41 287.36 22.94 BPHM-PBD 2.00 44.7 2601.14 S 779.9~V 102.54 26.17 287.36 23.18 BPHM-PBD 2.00 46.7 2662.33 S 798.37W 104.85 26.92 287.36 23.39 BPHM-PBD 2.00 48.7 2720.89 S 816.0CW 107.04 27.67 287.36 23.58 BPHM-PBD 2.00 50.7 2776.77 S 832.85W 109.13 28.40 287.36 23.73 BPHM-PBD 2.00 52.7 2829.89 S 848.9CW 111.10 29.11 287.36 23.86 BPHM-PBD 2.00 54.7 2880.20 S 864.12W 112.96 29.81 287.36 23.96 BPHM-PBD 2.00 56.7 2927.62 S 878.51W 114.71 30.49 287.36 24.03 BPHM-PBD 2.00 58.0 2957.25 S 887.5¢W 115.81 30.93 287.36 24.07 BPHM-PBD 2.00 58.7 2972.11 S 892.01W 116.36 31.15 287.36 24.09 BPHM-PBD 2.00 60.7 3013.60 S 904.65W 117.87 31.79 287.36 24.12 BPHM-PBD 2.00 62.7 3052.05 S 916.35'W 119.26 32.39 287.36 24.13 BPHM-PBD 2.00 64.7 3087.42 S 927.21W 120.53 32.97 287.36 24.13 BPHM-PBD 2.00 65.4 3099.17 S 930.8¢W 120.96 33.16 287.36 24.13 BPHM-PBD 0.00 65.4 3117.24 S 936.33W 121.64 33.40 287.36 24.24 BPHM-PBD 76 3186.29 S 996.01W 6002530.00 583519.00 3338.33@197.36 3338.33 ~0.00 $0 3269.66 S 1022.07W 6002446.35 583493.87 3425.6~@197.36 3425.69 0.00 )01b/~. 35 3367.58 S 1052.68W 6002348.11 583464.36 3528.27@197.36 3528.27 0.00 )5 3367.60 S 1052.6¢W 6002348.09 583464.36 3528.2¢@197.36 3528.29 0.00 0.00 0.00 0.00 0.00 0.00 65.4 3197.29 S 960.8CW 124.65 34.42 287.36 24.70 BPHM-PBD 0.00 65.4 3280.83 S 986.35W 127.79 35.49 287.36 25.19 BPHM-PBD 0.00 65.4 3367.58 S 1052.68W 0.00 0.00 0.00 0.00 BPHM-PBD 0.00 65.4 3378.95 S 1016.35W 131.49 36.75 287.36 25.76 BPHM-PBD Halliburton Travelling Cylinder Report Cotnputed using WIN-CADDS REV2.1.B Page 1 Date: 2/12/96 Time: 11:44 am Normal Plane Method REFERENCE WELL: BPX-Shared Services Drilling Alaska State Plane: Zone4 Milne Pt: MPK MPK-25 EST MPK-25 (96E) Wpl N/S and E/W are measured from the WELLHEAD TVD is measured from the WELLHEAD Interval Step Depth 50.00 ft.(MD) From 0.00 To 8708.46 ft.(MD) All Directions using BP Highside Method in Dec. Deg. All Depths and Distance are in FEET All distances are between EXPEC'I~D Positions Closest Points Slot Wellpath Distance Direction RefMD RefTVD SepFactor CASCADE-IA CASCADE-IA 1533.37 79.44 450.00 450.00 2692.69 337.27 5500.00 4871.05 CASCADE-01 CASCADE-01 1533.37 79.44 450.00 450.00 3456.49 37.55 7850.00 6726.23 MPK-10 Est MPK-10 Wpl 162.94 20.75 0.00 0.00 165.56 20.70 2100.00 2099.97 MPK-17 As-StakdVIPK-17 Wp2 59.62 337.95 0.00 0.00 61.36 339.25 2100.00 2099.97 MPK-18 Est MPK-18 Wpl 124.48 39.45 0.00 0.00 129.28 38.63 2150.00 2149.89 MPK-37 Est MPK-37 Wp 1 89.70 158.37 0.00 0.00 1033.37 99.12 8400.00 7243.06 MPK-38 Est MPK-38 Wpl 142.06 107.21 2050.00 2050.00 152.33 86.46 2500.00 2496.04 451.8 11.7 451.8 21.4 162.9 14.5 59.6 5.4 124.5 11.0 89.7 4.2 12.7 11.0 Halliburton Travelling Cylinder Report Computed using WIN-CADDS REV2. I.B Page 1 Date: 2/12/96 Time: 11:44 am Normal Plane Method REFERENCE WELL: BPX-Shared Services Drilling Alaska State Plane: Zone4 Milne Pt: MPK MPK-25 EST MPK-25 (96E) Wpl N/S and FdW are measured from the WELLHEAD TVD is measured from the WELLHEAD Interval Step Depth 50.00 ft.(MD) From 0.00 To 8708.46 ft.(MD) All Directions using BP Highside Method in Dec. Deg. All Depths and Distance are in FEET All distances are between EXPECTED Positions Close Approach Status Offset Flowing Zone Well Safety Min. Clear Spread MD TVD CASCADE-IA 1505.6 1527.5 1750 1750 CASCADE-01 1505.6 1527.5 1750 1750 MPK-10 Wpl 122.0 147.0 2000 2000 MPK-17 Wp2 18.7 43.7 2000 2000 MPK-18 Wpl 83.6 108.6 2000 2000 MPK-37 Wpl 47.1 73.3 2150 2150 MPK-38 Wpl 98.0 124.8 2250 2250 Flowing Shut-in Enter Safety Safety Shut-in Dist Dist Zone MD 26.3 4.4 26.3 4.4 3O.0 5.0 30.0 5.0 30.0 5.0 31.5 5.4 32.5 5.6 Enter Exit Exit Danger Danger Shut-in Zone Zone Zone MD MD MD Close Approach Status OK OK OK OK OK OK OK ]3PX-Sh~ ed Se~ vices Mi(ne P-~ : MPK MPK-P5 EST IvlpK-P5 (98E) Wp ~ Zone4 HORIZONTAL VIEW (TRUE NORTH) SCALE 500 Ft. / DIVISION SURVEY REF: ~/ELLHEAD ,,,.o / I I ~ 1~64 ' 16.64 16.64 16.64 I I I I I I I I I c~z 179,99 17g.gg 179,99 179.99 4796 466t - 179,99 4871 - 179,99 BPX-SHa~ed Services ' u~iLLin9 h[cskc S~a~e Plane: Zone4 / ;'-',,;-~ ......... ~ ; ~ ! i IAI I II~LJI,N'I]N MiLn e P-t,: ' M?K \ , ,, ; I L ........ ;!.....~. , MPt<-P5 EST B70 Tr"o.w?ltir~O C~tinc, fer, - Nor,mo.l PI.c~ne z~ ReFer,ence ~eLL - MPK-25 Wp_l_ ~ MD: 0 - 8708 F~, In~ervd, 50 F~, ~ AIL Dir,ectlons usln~ BP Hi~hslde Method ~ Ciec[es one the B,P, FLO~G/SHUT-IN condition ~ ~ 3 33 300 240 210 225O 25OO 60 120 gO ST ZO/© GEOL ~ ~(~ UNIT~ .,~/, /~ ON/OFF SHORE ~_~ ttached ................... appropriate ............... na~e and number ............... Y in a defined pool .............. Y proper distance from drlg unit boundary. · Y Y . proper distance from other wells ..... .creage available in drilling unit ..... is wellbore plat included ........ y affected party .............. appropriate bond in force ......... ;e issued without conservation order .... se issued without administrative approval. ,e approved before 15-day wait ....... J REMARKS N N N :ring provided ............... ~ N ~; .rig protects all kno~ USDWs ........ ~ N luate to circulate on conductor & s~f csg..$ N ~~ !uate to tie-in long string to surf csg . . . N ~ 'er all kno~ productive horizons ...... ~ N Ins adequate for C, T, B & permafrost .... Y~ N lkage or rese~e pit ............. ~ N .1, has a 10-403 for abndnmnt been approved. ~ · .lbore separation proposed .......... ~ N r~uired, is it adequate .......... ~ N ~id progr~ sche~tic & equip list adequate .~ N ~te ..................... ~ N 2ating adequate; test to ~'--~ psig.~ N ~ld complies w/~I ~-53 (~y 84) ...... ~ =c~ without operation shutdo~ ....... ~ N of H2S gas probable ............ ~ N 3e issued w/o hydrogen sulfide measures .... Y N ':ed on potential overpressure zones . £ysts of shallow gas zones .......... ~tion survey (if off-shore) ........ ~ N ' ~/phone for weekly progress reports . . . y/. Y N [exploratory only] ENGINEERING: COMMISSION: TAB 'L."~,~ .. Comments/Instructions: Z Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special'effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER COMPANY NAME : B. P. EXPLORATION WELL NAME : MPK-25 FIELD NAME : MILNE POINT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22650-00 REFERENCE NO : 96104 RECEIVED SEP 05 1996 Oil & Gas Cons, c. ommimion Anchorage 'LIS Tap~ Verification Listing Schlumberger Alaska Computing Center 22-AUG-1996 16:45 PAGE: **** REEL HEADER **** SERVICE NAM~ : EDIT DATE : 96/08/22 ORIGIN · FLIC REEL NAME · 96104 CONTINUATION # : PREVIOUS REEL : CORff~ENT . BP EXPLORATION (ALASKA), MILNE POINT MPK-25, API #50-029-22650-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 96/08/22 ORIGIN · FLIC TAPE NAME : 96104 CONTINUATION # : 1 PREVIOUS TAPE : CO~94ENT : BP EXPLORATION (ALASKA), MILNE POINT MPK-25, API #50-029-22650-00 TAPE HEADER MILNE POINT MWD LOGS WELL NAME: API NURiBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL : FSL : FEL '. FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING MPK-25 500292265000 B. P. Exploration SCHLUMBERGER WELL SERVICES 22 -AUG-96 BIT RUN 1 96104 RUMINER/JACK ANGLEN BIT RUN 2 BIT RUN 3 3 12N llE 3592 2078 61.89 60.89 28.70 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 20.000 112.0 ~LIS Tap$ Verification Listing Schlumberger Alaska Computing Center 22-AUG-1996 16:45 3RD STRING PRODUCTION STRING REMARKS: Well drilled 17-MAR through 21-MAR-96 with CDR only. All data was collected in a single bit run. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT . 001 SERVICE · FLIC VERSION · O01CO1 DATE : 96/08/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: O. 5000 FILE Str~gViARY LDWG TOOL CODE START DEPTH STOP DEPTH MWD 51.0 3995.0 $ BASELINE CURVE FOR SHIFTS: NONE CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH .............. $ MERGED DATA SOURCE LDWG TOOL CODE .............. $ REMARKS: No depth shifts applied as per Matt Lender. This file also contains the Very Enhanced QRO resisitivity with 2' average that was reprocessed at GeoQuest. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... BIT RUN NO. MERGE TOP MERGE BASE LIS FORMAT DATA 'LIS Tap~ Verification Listing Schlumberger Alaska Computing Center 22-AUG-1996 16:45 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 36 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 28 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630362 O0 000 O0 0 1 1 1 4 68 0000000000 RA MWD OtP4~ 630362 O0 000 O0 0 1 1 1 4 68 0000000000 RP MWD OHI~I 630362 O0 000 O0 0 1 1 1 4 68 0000000000 VRA MWD OhlVffq 630362 O0 000 O0 0 1 1 1 4 68 0000000000 VRP MWD OHI4~ 630362 O0 000 O0 0 1 1 1 4 68 0000000000 DER MWD OP2V~l630362 O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHR 630362 O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI 630362 O0 000 O0 0 1 1 1 4 68 0000000000 FET MWD HR 630362 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 3954.000 RA.MWD -999.250 RP.MWD -999.250 VRA.MWD VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD 68.986 GR.MWD FET.MWD -999.250 DEPT. 51.000 RA.MWD -999.250 RP.MWD -999.250 VRA.~BFD VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD -999.250 GR.MWD FET.MWD -999.250 -999.250 -999.250 -999.250 14.303 ** END OF DATA ** 'LIS Tap~ Verification Listing Schlumberger Alaska Computing Center 22-AUG-1996 16:45 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/08/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE · FLIC VERSION · O01CO1 DATE : 96/08/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: O . 5000 FILE S~Y VENDOR TOOL CODE START DEPTH STOP DEPTH 51.0 3955.0 LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIldE): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESIST./GR $ 21 -MAR-96 FAST 2.5 4.0 MEMORY 3955.0 51.0 3995.0 80 0 38.5 TOOL NUMBER RGS904 LIS TapJ Verification Listing Schlumberger Alaska Computing Center 22-AUG-1996 16:45 PAGE: BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 12. 250 112.0 BOREHOLE CONDITIONS MUD TYPE: SPUD MUD DENSITY (LB/G): 11.50 MUD VISCOSITY (S) : 96.0 MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): 6.0 RESISTIVITY (OH~I) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 2. 615 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 2. 233 MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 20000 REMARKS: ************ RU~V1 ************* DRILLED INTERVAL 112' - 3955' MAX. HOLE ANGLE = 38.53 DEG @ 3813' RES TO BIT: 51.82'; GR TO BIT: 62.24' TD WELL @ 15:00 20-MAR-96 DATA FROM DOWNHOLE MEMORY, V4. OC SOFTWARE $ LIS FORMAT DATA 60.0 60.0 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 36 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT ~IS Tape? Verification Listing Schlumberger Alaska Computing Center 22-AUG-1996 16:45 PAGE: 6 TYPE REPR CODE VALUE 11 66 28 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN * * NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630362 O0 000 O0 0 2 1 1 4 68 0000000000 ATR LW1 OH~ff4630362 O0 000 O0 0 2 1 1 4 68 0000000000 PSR LW1 0I~4~I630362 O0 000 O0 0 2 1 1 4 68 0000000000 ATVR LW1 014~ff4 630362 O0 000 O0 0 2 1 1 PSVR LW1 OHMM 630362 O0 000 O0 0 2 1 1 DER LW1 Otff4~I 630362 O0 000 O0 0 2 1 1 ROPE LW1 F/HR 630362 O0 000 O0 0 2 1 1 GR LW1 GAPI 630362 O0 000 O0 0 2 1 1 TAB LW1 HR 630362 O0 000 O0 0 2 1 1 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 ** DATA ** DEPT. 3954.500 ATR.LW1 -999.250 PSR.LW1 PSVR.LW1 -999.250 DER.LW1 -999.250 ROPE.LW1 TAB. LW1 -999. 250 -999. 250 ATVR. LW1 -999. 250 GR. LW1 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/08/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : ~IS 'Tape~ Verification Listing Schlumberger Alaska Computing Center 22-AUG-1996 16:45 PAGE: **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 96/08/22 ORIGIN : FLIC TAPE NAME : 96104 CONTINUATION # : 1 PREVIOUS TAPE COf~fENT : BP EXPLORATION (ALASKA), MILNE POINT MPK-25, API #50-029-22650-00 **** REEL TRAILER **** SERVICE NA~E : EDIT DATE : 96/08/22 ORIGIN : FLIC REEL NAME : 96104 CONTINUATION # : PREVIOUS REEL : COI~4ENT : BP EXPLORATION (ALASKA), MILNE POINT MPK-25, API #50-029-22650-00 :.~. ~ ,: :::.~ ::.:',:::,~:: :::::::::::::::::::::::::::::::::::::::::::: .~. . ....... , .,,. ::::~:::::~: ~ :::::::::::::::::::::::::::: ,:k:: ,,: ......... ::,::.:':::::: .... i- · Ak~H ~D SS%f~ ,~,SHI.~ O,1, G.qHO,l,k~4 H,I, dHG Ak~H ~D SS¥~ GNODHS (I : SMOqqO.~ S~ HHflGHDOH~ ,I,.~IHS ~ q~HM SIH~ HO~ HDNHHH~HH HA~H~ HHA SI SIHA ~ : S~HH HAdHG GHA~IHSN/1 ANH%~AIfl0H S~DIAHHS DNIDDO~ Sk~I~ NHH~SHM 96-Hk~4-EE I I HDHD HD H,~,~HG HNIqHS~f~ 00'09 0'9~8~ :ANti.OD DNIDDOq :HH~W/1N SS~ :HH~/1N N/IH :HGOD HAHflD ~ :HGOD qOOA ~6 SA~IHS HO~ HAH~ID HNI~HS~ (HA~HG GH~/1S~H~) GH~GN~fAS OA SHSS~6 ~ - YAnG A~IHS HAHflD gE9'6 ~NIH~S NOI~D~GOH~ ~NIHAS GH~ DNIH~S GNE DNIH~S ASI (,l,.~/~q) ,I, HDIHM (,1,.~) H,I, aHG (NI) HZIS (NI) HZIS ONIS%fD SHHqqIHG DNIS~fD HqOH NH60 00'6E 00'09 00'I9 8£0E AHN~t~D '£ NIfO 'O 00'0~99 96-D~-£0 SHDIAHHS DNIDDO~ Sk~/~ NHHASHM 'DNI (kQISk~I~) NOI&k~HO~aX~ a~ 000~9EE6E00~ SIq :a~X$ s~. E aI~.~qns ade? FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 1 DEPTH INCREMENT: .5000 FILE S~Y PBU TOOL CODE START DEPTH STOP DEPTH GRCH 60.0 3720.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE PASS NUMBER: BASELINE DEPTH $ REMARKS: EQUIVALENT UNSHIFTED DEPTH PASS 1 (MAIN PASS). NO DEPTH SHIFTS WERE DONE SINCE THIS IS THE DEPTH REFERENCE. CN : BP EXPLORATION WN : MPK - 25 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GRCH GR 68 1 GAPI 2 TENS GR 68 1 LB API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 30 995 99 1 4 4 30 995 99 1 * DATA RECORD (TYPE# 0) Total Data Records: 88 1014 BYTES * Tape File Start Depth = Tape File End Depth = Tape File Level Spacing = 55.000000 3725.000000 0.500000 sasXq ~IOI :g$6uaI paoDaa mnm~x~ sa~Xq E9 :g$6uaI paoDaa mnm~u~ · --sp~o~a~ LLI E :aI!~qns s~n~p ~EOEE 89 :apo0 :Xa~unans 6u!pomap apom uoy$~$uasaadaa SI~ Tape Subfile 3 i's type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GRCH $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 START DEPTH 3100.0 BASELINE DEPTH GRCH 3107.0 3106.5 3110.0 3109.5 3120.5 3120.5 3121.5 3121.5 3125.0 3124.5 3125.5 3125.0 3140.0 3140.0 3141.0 3141.0 3141.5 3142.0 3142.5 3143.0 3151.0 3150.5 3159.5 3159.0 3160.0 3160.0 3164.0 3164.0 3166.5 3166.0 3171.5 3171.0 3172.0 3172.0 3181.0 3181.0 3184.0 3183.5 3185.5 3185.0 3186.0 3186.0 3199.0 3199.0 3208.5 3208.0 3212.5 3212.0 3213.0 3213.0 3217.5 3217.5 3218.5 3218.0 3219.5 3219.0 3220.0 3220.0 3221.5 3221.5 3223.0 3222.5 3227.5 3227.0 3235.5 3235.5 3237.5 3237.5 3238.5 3238.0 3245.0 3244.5 3256.0 3255.0 3265.5 3264.5 STOP DEPTH 3294.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH 3266.0 3269.5 3281.5 3285.0 3285.5 $ REMARKS: 3265.5 3269.0 3281.5 3285.0 3285.5 PASS 2 (REPEAT PASS). TENS SHIFTED WITH GRCH / ? ?MATCH2A . OUT $ CN : BP EXPLORATION WN : MPK - 25 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH GR 68 1 GAPI 2 TENS GR 68 1 LB 4 4 30 995 99 1 4 4 30 995 99 1 * DATA RECORD (TYPE~ 0) Total Data Records: 1014 BYTES * Tape File Start Depth = 3095.000000 Tape File End Depth = 3295.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 1204 datums Tape Subfile: 3 81 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 56.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 3723.0 22-MAR-96 FSYS REV. J001 VER. 1.1 1421 22-MAR-96 3856.0 3760.0 65.0 3752.0 1800.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL GR ELEC SBT VDL CENT $ CASING COLLAR LOC. GAMMA RAY SEGMENTED BOND TOOL VDL SUB CENTROLLER TOOL NUMBER 2346 1309 1633 1424 1424 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 3856.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): FRESH WATER 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE C.OUNT ~RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS) : 0 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 1 (MAIN PASS). $ CN : BP EXPLORATION WN : MPK - 25 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units 1 GR GR 68 1 2 CCL GR 68 1 3 SPD GR 68 1 4 TTEN GR 68 1 5 TEN GR 68 1 GAPI F/MN LB LB API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 30 310 01 1 4 4 30 150 01 1 4 4 30 636 99 1 4 4 30 635 99 1 4 4 30 635 99 1 20 * DATA RECORD (TYPE# 0) Total Data Records: 349 1014 BYTES * Tape File Start Depth = 60.000000 Tape File End Depth = 3720.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 109871 datums Tape Subfile: 4 425 records... Minimum record length: 62 bytes SaSXg ~IOI :g$6uai ploDaI ~n~x~ Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 3100.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 3295.0 22-MAR-96 FSYS REV. J001 VER. 1.1 1028 22-MAR-96 3856.0 3760.0 65.0 3752.0 1800.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL GR ELEC SBT VDL CENT $ CASING COLLAR LOC. GAMMA RAY SEGMENTED BOND TOOL VDL SUB CENTROLLER TOOL NUMBER 2346 1309 1633 1424 1424 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 3856.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): FRESH WATER 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT ,RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : 0.0 BASE NORMALIZING WINDOW (FT) : 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS) : 0 NEAR COUNT RATE LOW SCALE (CPS) : 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 2 (REPEAT PASS). $ CN : BP EXPLORATION WN : MPK - 25 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR GR 68 1 GAPI 4 2 CCL GR 68 1 4 3 SPD GR 68 1 F/MN 4 4 TTEN GR 68 1 LB 4 5 TEN GR 68 1 LB 4 4 30 310 01 1 4 30 150 01 1 4 30 636 99 1 4 30 635 99 1 4 30 635 99 1 20 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 19 Tape File Start Depth = 3100.000000 Tape File End Depth = 3295.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 5891 datums Tape Subfile: 5 95 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 6 is 'ty~e: LIS 96/ 8/ 8 01 **** REEL TRAILER **** 96/ 8/ 8 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Thu 8 AUG 96 ll:06a Elapsed execution time = 15.71 seconds. SYSTEM RETURN CODE = 0
