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197-071
Wallace, Chris D (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Friday, August 28, 2015 8:13 AM To: Alaska NS - Endicott - Field Foreman;Alaska NS - Endicott - Operations Leads; Loepp, Victoria T (DOA) Cc: Wallace, Chris D (DOA); Regg,James B (DOA);Taylor Wellman Subject: RE: MPI 2-44A (PTD# 1970710)TIFL Passed All, Endicott producer MPI 2-44A (PTD# 1970710) passed a tubing integrity fluid level survey on 8-27-15. Over a 1 hour test, there was zero fluid level movement in the IA.T/I/0 pressures increased from 2100/950/0 to 2300/975/0.The passing TIFL confirms tubing integrity.The well will return to production. Please call with any questions. Thank You, SCANNED SEP 0 3 2015 Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 Ilikurp %la•ha. 1.1.* From: Wyatt Rivard Sent: Tuesday, August 25, 2015 2:33 PM T Iaska N5 - Endicott- Field Foreman; Alaska NS - Endicott - Operations Leads; 'Loepp, Victoria T(DOA)' Cc: 'Wallace, C1I D(DOA)'; 'Regg, James B (DOA)'; Taylor Wellman Subject: MPI 2-44A(RTD # 1970710) Sustained Casing Pressure All, Gas lifted producer MPI 2-44A(PTD# 1970710)wasfound to have sustained Inner Annulus casing pressure on 8/23/2015 with T/I/O=51/2900/0 following its shut-in fo1APs proration. IA has been bled to 1950 psi and well is back online without further pressurization. Plan forward—Operations: 1) Obtain TIFL survey 2) Pending TIFL results, well may be evaluated for additional wellhead diagnosticsor GLV change out. Please call with any questions or concerns. Thank You, Wyatt Rivard I Well Integrity Engineer 1 Wallace, Chris D (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Tuesday, August 25, 2015 2:33 PM To: Alaska NS - Endicott - Field Foreman; Alaska NS - Endicott - Operations Leads; Loepp, Victoria T (DOA) Cc: Wallace, Chris D (DOA); Regg, James B (DOA); Taylor Wellman Subject: MPI 2-44A (PTD# 1970710) Sustained Casing Pressure All, Gas lifted producer MPI 2-44A(PTD# 1970710)was found to have sustained Inner Annulus casing pressure on 8/23/2015 with T/I/O =SI/2900/0 following its shut-in for TAPs proration. IA has been bled to 1950 psi and well is back online without further pressurization. Plan forward—Operations: 1) Obtain TIFL survey 2) Pending TIFL results, well may be evaluated for additional wellhead diagnostics or GLV change out. Please call with any questions or concerns. Thank You, Wyatt Rivard Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 11i1r.��1, ►1.x.1 . 1 1 SCANNED AUG 2 72015 1 • • 14 g A1 ED Post Office Box 244027 Anchorage,AK 99524-4027 i Hilcorp Alaska,LLC L 3 0 2013 3800 Centerpoint Drive Suite 100 AOGCCAnchorage,AK 99503 Phone: 907/777-8300 Fax: 907/777.-8301 July 29, 2015 Commissioner Cathy Foerster Alaska Oil & Gas Conservation Commission ig7- 071 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Duck Island Unit Well Renaming Request SCANNED AUG 2 E Mir Dear Commissioner Foerster, Hilcorp Alaska, LLC (HAK) requests a change to the naming convention of Duck Island Unit wells to remove the unused suffixes at the end of each well name. Well names currently include a forward slash "I" followed by an obsolete bottom hole location designator. HAK would like to retain the well number as well as the "A, B, C...." sidetrack designations but remove the "/suffix". For example, "DUCK IS UNIT SDI 1-09A/L21" would become "DUCK IS UNIT SDI 1-09A". The attached spreadsheet includes original and new names for all Duck Island wells. While performing the review of Duck Island well names, HAK found a single well, "DUCK IS UNIT SDI 4-20/M35" (PTD# 1861730), that should also be modified to include an "A" label to reflect the fact that the well is a sidetrack from the original "DUCK IS UNIT SDI 4-20/T34" (PTD # 1861500). The original wellbore, abandoned 10/13/1986, was sidetracked to a new bottom hole location completed on 9/9/1987. This well appears to be one of the first sidetracks performed at Endicott. While the bottom hole code was changed, no letter was added to reflect the sidetrack. "DUCK IS UNIT SDI 4-20A" is also included on the attached spreadsheet. Sincerely, Wyatt Rivard Well Integrity Engineer Hilcorp Alaska, LLC CC Dave Roby Victoria Loepp • Orig • New API_WeliNo I PermitNumberl WellName WellNumber WellNumber I I 50029224180000 1931730 DUCK IS UNIT MPI 2-24/M12 2-24 50029218150000 1880550 DUCK IS UNIT MPI 2-26/N14 2-26 50029218470000 1880860 DUCK IS UNIT MPI 2-28/P19 2-28 50029218470100 2010180 'DUCK IS UNIT MPI 2-28A/O19 2-28A 50029218470200 2030060 DUCK IS UNIT MPI 2-286/019 2-28B 50029222280000 1911400 DUCK IS UNIT MPI 2-30/009 2-30 50029222280100 1981880 DUCK IS UNIT MPI 2-30A/EI-02 2-30A 50029222280200 2081870 DUCK IS UNIT MPI 2-30B/ME-01 2-30B 50029220840000 1901190 DUCK IS UNIT MPI 2-32/SN3 2-32 50029216620000 1861720 DUCK IS UNIT MPI 2-34/P14 2-34 50029220140000 1900240 DUCK IS UNIT MPI 2-36/014 2-36 50029220900000 1901290 DUCK IS UNIT MPI 2-38/SN1 2-38 50029225270000 1941520 DUCK IS UNIT MPI 2-40/S22 2-40 50029218920000 1881450 DUCK IS UNIT MPI 2-42/P13 2-42 50029217670000 1871190 DUCK IS UNIT MPI 2-44/R12 2-44 50029217670100 1970710 DUCK IS UNIT MPI 2-44A/Q11 2-44A 7' 50029219210000 1890230 DUCK IS UNIT MPI 2-46/Q15 2-46 50029219210100 1961810 DUCK IS UNIT MPI 2-46A/R10 2-46A 50029219210200 1971370 DUCK IS UNIT MPI 2-46B/S13 2-46B 50029226120000 1951660 DUCK IS UNIT MPI 2-48/013 2-48 50029223670000 1930670 DUCK IS UNIT MPI 2-50/U08 2-50 50029217500000 1870920 DUCK IS UNIT MPI 2-52/514 2-52 50029222180000 1911220 DUCK IS UNIT MPI 2-54/Q12 2-54 50029228630000 1980240 DUCK IS UNIT MPI 2-56/EID 2-56 50029228630100 1980580 DUCK IS UNIT MPI 2-56A/EID01 2-56A 50029220410000 1900520 DUCK IS UNIT MPI 2-58/509 2-58 50029223750000 1930830 DUCK IS UNIT MPI 2-60/U13 2-60 50029216480000 1861580 DUCK IS UNIT MPI 2-62/Q17 2-62 50029220550000 1900770 DUCK IS UNIT MPI 2-64/U10 2-64 50029220819500 1901130 DUCK IS UNIT MPI 2-66/U12XX 2-66XX 50029223740000 1930790 DUCK IS UNIT MPI 2-665D12 2-66 50029218580000 1880970 DUCK IS UNIT MPI 2-68/517 2-68 50029218990000 1881530 DUCK IS UNIT MPI 2-70/U15 2-70 50029205180000 1801200 DUCK IS UNIT MPI 5-01/SD7 5-01 50029206400000 1811180 DUCK IS UNIT MPI 5-02/SD10 5-02 50029206390000 1811170 DUCK IS UNIT MPI 5-03/SD9 5-03 50029216780000 1861900 DUCK IS UNIT SDI 3-01/N29 3-01 50029223060000 1921210 DUCK IS UNIT SDI 3-03/J33 3-03 50029216240000 1861300 DUCK IS UNIT SDI 3-05/029 3-05 50029219110000 1890120 DUCK IS UNIT SDI 3-07/N28 3-07 50029219110100 1981470 DUCK IS UNIT SDI 3-07A/L29 3-07A 50029217800000 1880020 DUCK IS UNIT SDI 3-09/L28 3-09 50029217800100 1950190 DUCK IS UNIT SDI 3-09A/L28 3-09A 50029218480000 1880870 DUCK IS UNIT SDI 3-11/M30 3-11 50029217510000 1870940 DUCK IS UNIT SDI 3-15/1(33 3-15 50029219460000 1890530 DUCK IS UNIT SDI 3-17/J30 3-17 50029219460100 1940460 DUCK IS UNIT SDI 3-17A/J30 3-17A 50029219460200 1971080 DUCK IS UNIT SDI 3-17B/M31 3-178 50029219460300 1980210 DUCK IS UNIT SDI 3-17C/M31 3-17C 50029219460400 1982080 DUCK IS UNIT SDI 3-17D/M31 3-17D 50029219460500 2022470 DUCK IS UNIT SDI 3-17E/K30 3-17E XHVZE Pages NOT Scanned in this Well History File' 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. / ~ ,7'- O ?/ File Number of Well History File PAGES TO DELETE RESCAN [] Color items - Pages: [] GraYScale, halftones, pictures, graphs, charts - Pages: [] Poor Quality Odginal- Pages: [] Other - pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type 'OVERSIZED .Logs of vadous kinds [] Other Complete COMMENTS: Scanned by: ~e,~,rty Mitdred-D;retha ~owell TO RE-SCAN Notes: Re-Scanned by: Bevedy Mildred Daretha Nathan Lowell Date: /si Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator(AKDCWelllntegrityCoordinator @bp.com] Sent: Saturday, October 12, 2013 8:45 AM To: AK, OPS END OIM;AK, OPS END Facility& FieldO&M TL;AK, OPS END Board Operator; AK, OPS END AES Drillsite Lead;AK, OPS END Operations Lead Tech;AK, RES END Production Optimization Engineer; AK, D&C Wireline Operations Team Lead;AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; Igwe, Josiah; Cinelli, Steven; Regg, James B(DOA); Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; Climer, Laurie A;AK, D&C Well Integrity Coordinator Subject: NOT OPERABLE: Producer END2-44A/Q-11 (PTD#1970710) Failing TIFL All, Producer END2-44A/Q-11 (PTD#1970710)was found to have surface equipment issues that cannot be resolved at this time.The well has been secured with a downhole plug, and is reclassified as Not Operable until further diagnostics can be completed. Please call with any questions. Thank you, �.. - Laurie Climer (:IIternafe:Jack Disbrow) BP Alaska - Well Integrity Coordinator Orgameat,on WIC Office: 907.659.5102 WIC Email: AKDCWellintegrityCoordinator @BP.com From: AK, D&C Well Integrity Coordinator Sent:Tuesday, Se s tember 17, 2013 11:47 PM To: AK, OPS END OI , .K, OPS END Facility&FieldO&M TL; AK, 0- ND Board Operator; AK, OPS END AES Drillsite Lead; AK, OPS END Opera •• Lead Tech; AK, RES END Production Opti • •tion Engineer; AK, D&C Wireline Operations Team Lead; AK, D&C Well Servis . Operations Team Lead; Cismoski, Doug A; ►; iel, Ryan; Igwe,Josiah; Cinelli, Steven; 'jim.regg @alaska.gov'; 'chris.wallace = .ska.gov' Cc: AK, D&C DHD Well Integrity Engineer; D&C Projects Well Integrity Engineer; Cli - Laurie A; AK, D&C Well Integrity Coordinator Subject: UNDER EVALUATION: Producer END2-44 s-11 (PTD #1970710) Failing TIFL All, Producer END2-44A/Q-11(PTD#1970710) IA was found to have exceeded ► , P on 09/15/2013 with TBG/IA/OA= 2720/2520/0 psi.A subsequent TIFL failed;at this time the well is reclassified as Un• - Evaluation for further evaluation. Plan Forward: 1. Slickline:Change out orifice gas lift valve(OGLV) 2. DHD: Re-TIFL 1 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20` Post Office Box 196612 Anchorage, Alaska 99519 -6612 ; May 22, 2012 01 614R ‘3 Mr. Jim Regg (I Alaska Oil and Gas Conservation Commission \ `� 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of Endicott Row 2 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from Endicott Row 2 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 . • 0 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Endicott Row 2 Date: 03/28/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal END2 -02 / P -18 1860630 50029215680000 15.0 3.0 0.5 8/28/2010 1.70 9/29/2010 END2 -04 / M -19 1860820 50029215850000 4.0 1.0 0.5 8/28/2010 1.70 9/29/2010 END2 -06 / J -22 1870180 50029216990000 2.0 1.0 0.5 8/28/2010 1.70 9/29/2010 END2 -08 / K -16 1880040 50029217710000 1.5 0.1 0.5 9/2/2010 3.40 9/29/2010 END2 -12 10-16 1921170 50029223020000 0.5 1.0 0.0 9/2/2010 NA 3/28/2012 END2 -14 / 0 -16 1861490 50029216390000 2.5 3.0 0.5 9/2/2010 1.70 9/28/2010 END2 -16 / M -16 1881340 50029218850000 2.0 0.5 0.5 9/2/2010 1.70 9/28/2010 END2 -18 / L -16 1900430 50029220320000 2.0 0.3 0.5 9/2/2010 2.60 9/28/2010 END2 -20 / L -15 1900600 50029220480000 5.0 3.0 0.5 8/28/2010 3.40 9/28/2010 END2 -22 / L -14 1890340 50029219310000 5.0 5.0 0.5 8/28/2010 6.80 9/28/2010 END2 -24 / M -12 1931730 50029224180000 0.5 NA 0.5 NA 1.70 9/28/2010 END2 -26 / N -14 1880550 50029218150000 2.0 1.8 0.5 9/2/2010 1.70 9/28/2010 END2 -28B / 0 -19 2030060 50029218470200 0.5 NA 0.5 NA 1.70 9/28/2010 END2 -30B / ME-01 2081870 50029222280200 3.0 3.0 0.5 8/28/2010 2.60 9/28/2010 END2 -32 / SN-03 1901190 50029220840000 3.0 2.0 0.5 8/28/2010 2.60 9/28/2010 END2 -34 / P -14 1861720 50029216620000 1.0 NA 1.0 NA 12.80 9/25/2010 END2 -36 / 0 -14 1900240 50029220140000 5.0 3.0 0.5 8/28/2010 2.55 9/25/2010 END2 -38 / SN -01 1901290 50029220900000 3.0 4.0 0.5 8/28/2010 1.70 9/25/2010 END2 -40 / S -22 1941520 50029225270000 15.0 13.0 0.5 9/2/2010 4.00 9/25/2010 END2 -42 / P -13 1881450 50029218920000 5.0 4.0 0.5 8/28/2010 2.55 9/25/2010 -, END2 -44A / Q-11 1970710 50029217670100 0.5 NA 0.5 NA 22.10 10/5/2010 END2 -46B / S -13 1971370 50029219210200 4.0 1.0 0.5 9/2/2010 3.40 9/25/2010 END2 -48 / 0 -13 1951660 50029226120000 2.0 2.0 0.5 8/28/2010 1.70 9/25/2010 END2 -50 / U-08 1930670 50029223670000 2.0 1.0 0.5 8/28/2010 1.70 9/25/2010 END2 -52 / S -14 1870920 50029217500000 1.0 0.3 0.5 9/2/2010 0.85 9/25/2010 END2 -54 / Q -12 1911220 50029222180000 4.0 3.0 0.5 8/28/2010 1.70 9/25/2010 END2 -56A / E101 1980580 50029228630100 0.5 NA 0.5 NA 25.50 9/25/2010 END2 -58 / S-09 1900520 50029220410000 7.0 5.0 0.5 8/28/2010 3.40 9/25/2010 END2 -62 / Q-17 1861580 50029216480000 10.0 7.0 0.5 8/28/2010 8.50 9/25/2010 END2 -64 / U -10 1900770 50029220550000 2.0 1.0 0.5 8/28/2010 2.55 9/25/2010 END2 -66 / SD-12 1930790 50029223740000 0.3 NA 0.3 NA 1.70 9/24/2010 END2 -68 / S -17 1880970 50029218580000 2.0 3.0 0.5 8/28/2010 1.70 9/24/2010 END2 -70 / U -15 1881530 50029218990000 0.7 NA 0.7 NA 3.40 9/24/2010 ON OR BEFORE C:LOKIXM~]LM.DOC STATE OF ALASKA ALAE~'~-"~,IL AND GAS CONSERVATION COMMISSi ~ -~ ' REPORT O. SUNDRY WELL OPEhATIONS 1. Operations performed: Operation shutdown__ Stimulate__ Plugging__ Pull tubing__ Alter casing __ Repair well __ Perforate X Other__ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchora.cle, Alaska 99519-6612 4. Location of well at surface 2036' SNL, 2300' WEL, SEC 36, T12N, R16E, UPM At top of productive interval 222' NSL, 3675' WEL, SEC. 26, T12N, R16E, UPM At effective depth 305' NSL, 4562' WEL, SEC 26, T12N, R16E, UPM At total depth 318' NSL, 4875' WEL, SEC. 26, T12N, R16E, UPM 5. Type of Well: Development .. Exploratory ~ Stratigraphic Service ~ 6. Datum elevation (DF or KB) KBE = 55.10 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-44A/Q- 11 9. Permit number/approval number 97-71/not recluired 10. APl number 50- 029-21767-01 11. Field/Pool Endicott Field/Endicott Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Plugs (measured) Junk (measured) 14905 feet 10256 feet 14854 feet 10229 feet /'d~ska 0il,;,. '~ (]~.s Cons. Ct;,i~,¢:;~issi0r!.. A n¢.hor~8 Length Size Cemented Measured depth True vedical depth BKB BKB 93' 30" Ddven 131' 131' 2459' ~2 3/8" 4185 c.f. Permafrost 2497' 2479' 10474' 9 5/8" 575 c.f. C/ass 'G' 10512' 8885' 10248' 7" 345 c.f. C/ass 'G' 3487'-13735' 3469'-9903' 1346' 4 1/2" 201 c.f. C/ass 'G' 13554~14900' 9881'-10236' measured 13920'- 13955'; 14055;14085'; 14110;14120'; 14636'-14656'; 14556'-14596';14656'-14676'; 14720'- 14730'; 14746'- 14786' (all open) true vertical (Subsea) 9896'- 9901'; 9919'- 9924'; 9929'- 9931'; 9955'- 9960'; 10074'- 10082'; 10082'- 10090'; 10109'- 10113'; 10120'- 10139' (afl open) Tubing (size, grade, and measured depth) 4 1/2" 12.6# NSCT 13CHR 80Tubing set at 11276' Packers and SSSV (type and measured depth) 7' Baker ZXP Liner Packer at 3487', 7" Backer S-3 Packer (3.875" I.D.) set at 11179' 13. Stimulation or cement squeeze summary Add Perforation (4/26/98) Intervals treated (measured) Treatment description including volumes used and final pressure ORiG NAL 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 361 1838 155 0 29~ 3086 183 0 Tubing Pressure 259 317 15. Attachments Copies of Logs and Surveys run__ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas__ Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. . ~,, n ,,3 . Signed ~(,¢0~,~,~,, [~.~JC¢... \~,_¢ ~c(..~'~ Title T. chnic~l A_~_~i_~t~nt IV - Form 10-404 Rev 06/~/88 Date 6/3/98 SUBMIT IN DUPLICA E',T,~ To: Endicott Productior ~ineering ~' ~"!jcation: yEndicott From: Clump I Hoffmann Well: 2-44A/Q-11 DATE: 4/26/98 Operation: CTU Add-Perfs Cost Code: AFE # 727011 Detail Code: 9335-070- 735 Summary 4/26/£$ to 4/27/98 Perform weekly BOP test ( DS CTU # 2 ). RIH w/PDS logging tools for tie-in pass. Logged from 14838' to 14260'. Flagged pipe @ 14740'. POH. RD PDS tools. Good log. MU Baker tool stdng and SWS TCP perf assembly. RIH w/gun # 1 and perf interval 14766' - 14786' ( 20' ) w/well flowing @ 104 choke. Correlate flag to top shot. POH. All shots fired. MU gun # 2 and RIH to perf interval from 14746' - 14766' ( 20' ). Shoot gun #2 after correlating flag to TS. POH. All shots fired. MU gun #3 and RIH to perf interval from 14720' - 14730' (10'). Shoot gun #3 after correlating flag to TS. POH. All shots fired. Rig down and put well back on production. Leave mast in the air - - to windy. Perforation Summary: Gun # 1 14766' - 14786' (20') Gun # 2 14746' - 14766' (20') Gun # 3 14720' - 14730' (10') 2 7~8" HSD 34J UJ Charge, 6 spf, 15.2 gm, 60 deg phasing, Random Orientation, 20.57" pen 2 7/8" HSD 34J UJ Charge, 6 spf, 15.2 gm, 60 deg phasing, Random Orientation, 20.57" pen 2 7/8" HSD 34J UJ Charge, 6 spf, 15.2 gm, 60 deg phasing, Random Orientation, 20.57" pen Initial Well Status Fwhp lap 0ap GIp FIp Fit psi psi psi psi psi °F 300 500 0 broke 250 68 I Time Operation 07:45 Miru DS CTU #2. 16000' of 1 314" coil. (36.47 bbls displacement). Shut-in well. 09:10 Perform BOP test. 10:19 Finished up with BOP test. Need a new o-ring for Baker tools. Wait on Baker. 11:14 Make up Baker tools & PDS memory tools. 12:41 Rib w/tools after opening the choke to 104 beans. Time Depth Rate Ctp Whp Total Remarks ft bpm psi psi bbls 12:41 - - 218 Start in the hole. 13:43 6400 - - 211 14 k 14:57 13400 - - 209 26 k 15:40 14838. - - 212 28k 7 15:48 14740 - - 201 28k. Flag pipe. 16:11 14248 207 24k. Stopfor PDS. Pooh. 18:22 -18.5 - - 216 Surface. Break down PDS tools. Good data. MU BHA # 2. 20:26 Surf 2000 PU guns. Stab lubricator and PT to 2000 psi. OK. 20:37 Surf 205 Open Swab valve and RIH to perforate. 23:11 14000 207 Wtcheck = 24k. 23:23 14747 208 At flag. POOH. Wt check = 25.5k Operation: G-30 PDS / STP / PI' ~'-~') ' :~'~ Page: 2 23:35 14766 205 Correlate depth to top shot ref to PDS tie-in log of 4/26198. Top shot @ 14766' and bottom shot @ 14786'. Distance from top of coil connector to top shot = 9.61' 23:55 14758 0.3 209 In Ball drop position. Launch 5/8" Aluminum ball. 24:00 14766 1.5 330 211 Start to displace ball w/methanol. 4/27 FWHP = 220 psi FWHT = 75 deg F lAP = 500 psi OAP = 0 CHOKE = 104 00:22 14766 0.5 50 205 Reduce pump rate 00:31 14766 0.5 600 207 32 Ball on seat. Fire gun # 1 w/well flowing @ 104 choke. Pump an additional 6 bbls of methanol. No change in FWHP or FWHT. PU Wt off btm = 28k. 00:39 14766 0 0 211 6 POOH. 03:00 Surf 0 0 0 OOH. Close swab and bleed off lubricator. 03:17 Surf LD gun # 1. All shots fired. MU gun # 2. 03:58 Surf 2000 Stab lubricator and PT to 2000 psi. OK. 04:07 Surf RIH w/gun # 2. 05:22 6585 40 220 Wt check = 9.5k. 05:50 9035 37 220 Wtcheck= 12.5k 06:20 12800 50 210 Wtcheck= 16k 06:45 14425 50 212 Wtcheck= 18.5k 06:56 14747 55 225 At flag. Correlate to PDS tie-in log of 4/26/98. 07:00 14760 71 230 In ball drop position. Launch 5/8" Aluminum ball. 07:04 14746 60 220 Pull uphole 1' past flag which is correlated to spot top shot @ 14746'. This puts btm shot ~ 14766'. 07:05 14746 1.7 360 220 Start pumping methanol to displace ball. 07:20 14746 0.5 50 210 Reduce pump rate 07:33 14746 0.3 2000 250 37 Ball on seat. Fire gun # 2 w/well flowing. Guns fired @ 2000 psi. Saw an initial 40 psi increase in FWHP after firing. 07:40 0 30 220 1 Pumped 1 bbl of meth after firing. POOH. PU Wt off btm = 28k. 09:42 - 0 121 374 OOH. Whfp= 90 deg F. All shots fired. LD gun # 2. 10:50 - 30 340 Rih w/gun #3 13:16 14000 0 209 291 18 k. 13:30 14797 0 214 295 13:34 14747 0 190 286 Correlate to PDS tie-in log of 4/26/98. Correct to top shot. 13:36 14734 0 154 289 Atballdrop position. 13:41 14720 1 311 271 ' 0 Start chasing ball w/ meoh. 14:08 14720 .5 640 341 33.7 5/8" Aluminum ball on seat. 14:12 14720 .6 2000 309 35 Shoot gun #3. 14:14 14720 .5/0 35 293 36.6 SD pumping. Pooh. 14:43 - - 31 370 OOH. All shots fired. LB gun #3. 18:30 RB BOP's. Leave mast in air. 35 to 45 mph winds. 19:10 Put well back on w/o GL. Final Well Status SI whp lap 0ap GIp FIp Fit psi psi psi psi psi °F 1500 500 0 500 250 94 Operation: G-30 PDS / STP / PITS Page: 3 Fluid Summary 0 Seawater 0 Diesel. 143 Meoh 143 Total Bottom Hole Assembly # 1 PDS Mem Log Tool String Descriptions O.D. I.D. Length Comments Baker CT Connector 2.250' 1.0" 1.37 Dual Flapper Checks 2.125' .80' 1.39 Baker Hydraulic Disconnect 2.125' .68" 1.57' Takes 3/4" ball XO 1 3/4' MT box X 1 3/4" 6 pitch pin 2.125' .68" .33' XO 1 3/4' 6 pitch box X 3/4' Sucker rod box2.125" .68" .33' KJ 1.688" 1.0" .60' Swivel 1.688" .88' X-over 1.688" .35' Battery Housing 1.688" 1.54' 4 Meg Memory 1.688" 1.90' Gamma Ray 1.688" 2.21' CCL 1.688" 1.54' 2-Piece Bull Plug 1.688' 1.65' Total Length 25.59' Btm Hole Assy # 2 & 3 TCP PERFORATION Tool String Descriptions Comments Baker CT Connector Dual Flapper Checks Baker Hydraulic Disconnect XO 1 3/4" MT box X 1 3/4' 6 pitch pin XO 1 3/4" 6 pitch CBF Fidng Head Adapter Upper Adapter 2 7/8' X 20' 9un loaded 6 spf Bottom Nose O.D. I.D. Length 2.250" 1.0' 1.35 2.125" .80" 1.38 2.125" .68" 1.54' 2.125" .68" .54' 2.125" .63' 2.125" 2.82' 2.125" 0.75' 2.125" 0.67' 2.816" 20.80' 2.880" 0.56' Total Length 31.04' Takes 3/4" ball Takes 5~8" ball Tool Stdn9 Descriptions Btm Hole Assy # 4 TCP PERFORATION O.D. I I.D. I Length J Comments Operation: G-30 PDS / STP / PiT · -' ' '~ ~ Page: 4 Baker CT Connector 2.250" 1.0" 1.35 Dual Flapper Checks 2.125' .80" 1.38 Baker Hydraulic Disconnect 2.125" .68" 1.54' Takes 3/4" ball XO 1 3/4" MT box X 1 3/4" 6 pitch pin 2.125" .68" .54' XO 1 3/4" 6 pitch 2.125' .63' CBF 2.125" 2.82' Takes 5/8" ball Firing Head Adapter 2.125' 0.75' Upper Adapter 2.125" 0.67' 2 7/8" X 10' gun loaded 6 spf 2.816" 10.80' Bottom Nose 2.880" 0.56' Total Length 21.04' STATE OF ALASKA ALAS~--~--OIL AND GAS CONSERVATION COMMIS,c~- '1 REPORT C. SUNDRY WELL OPErtATIONS I. Operations performed: Operation shutdown__ Stimulate__ Plugging__ Perforate X Pull tubing__ Alter casing __ Repair well __ Other 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) BP Exploration (Alaska) Inc. Development X KBE = 55.10 feet Exploratory __ 3. Address Stratigraphic__ 7. Unit or Property name P. O. Box 196612, Anchoracle, Alaska 99519-6612 Service __ Duck Island Unit/Endicott 4. Location of well at surface 8. Well number 2036' SNL, 2300' WEL, SEC 36, T12N, R16E, UPM 2-44A/Q- 11 At top of productive interval 9. Permit number/approval number 222' NSL, 3675' WEL, SEC. 26, T12N, R16E, UPM 97-71/not recluired At effective depth 10. APl number 305' NSL, 4562' WEL, SEC26, T12N, R16E, UPM 50- 029-21767-01 At total depth 11. Field/Pool 318' NSL, 4875' WEL, SEC. 26, T12N, R16E, UPM Endicott Field/Endicott Pool 12. Present well condition summary Total depth: measured 14905 feet Plugs (measured) true vertical 10256 feet Effective depth: measured 14854 feet Junk (measured) true vertical 10229 feet Casing Length Size Cemented Measured depth True vertical depth Structural BKB BKB Conductor 93' 30" Driven 131' 131' Surface 2459' 13 3/8" 4185 c.f. Permafrost 2497' 2479' Intermediate 10474' 9 5/8" 575 c.f. Class 'G' 10512' 8885' Production 10248' 7" 345 c.f. Class 'G' 3487'-13735' 3469'-9903' Liner 1346' 4 1/2" 201 c.f. Class 'G' 13554'-14900' 9881'-10236' Perforation depth: measured 13920'- 13955'; 14055'-14085'; 14110'-14120'; 14636'-14656'; 14556'-14596';14656'-14676' (all open) true vertical 9951'-9957'; 9974'-9980'; 9984'-9986'; 10130'-10138'; 10100'-10115'; 10137'-10145' (TVD) Tubing (size, grade, and measured depth) 4 1/2" 12.6# NSCT 13CHR 80Tubing set at 11276' Packers and SSSV (type and measured depth) 7" Baker ZXP Liner Packer at 3487', 7" Backer S-3 Packer (3.875" I.D.) set at 11179' 13. Stimulation or cement squeeze summary Add Perforation (1/29/98) ' Intervals treated (measu red) ORIGIh, JAL Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 320 1398 52 0 280 Subsequent to operation 451 2331 86 0 288 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations X Oil X Gas Suspended Service 17. I hereby certify that ~~~e and correct to the best of my knowledge. Signed ~ Title ~ni~r T~chnic~l A.~.~i_~t~nt IV Date 3/10/98 Form lO-40,~;/~ev 06/15/88 - - J SUBMIT IN DUPLICATE % WSA- Well Operations Telex To: From: Operation: Date: Cost Code: Anchorage Engineering Luecker/Clump Endicott 2-44 CT CONVEYED GR/CCL LOG/PERF JOB Jan. 29, 1998 727011 Summary Rig up and RIH with PDS's gr/ccl. Logged first pass placing flag at 14700. Had difficulties with encoder and/or PDS's counter causing PDS's depth counter not to track electronic depth counter of Dowell. Rigged up PDS's mechanicl counter on spooler arm alleviating the problem, Logged again from 14800 stopping at flag which was at 14699. Continued logging to 14250. Gasliff was shut in and well had cooled to a FWHT of 52 degrees. Asphaltenes on pipe caused pipe to slip in chains. Put gaslift back on and pumped 10 bbls. of warm diesel. POOH. PDS log was -10' to the MWD gr/resitivity log of 10-18-97 at the bottom of the 14656-14676 interval and -9' at the 14556-14596 interval. Pick up gun #1 a 20' 2 7/8" 6 spf HSD, 60 degree phasing, random orientation loaded with 34j charges (15.2gm.). Catch flag and reset depth to 14701.2' hydraulic disconnect depth. Pull up to 14651 placing gun across 14656-14676 interval. Gun fired after 35 bbl diesel pumped and t 2550 psi. Pick up gun #2, a 20' 2 7/8" 6 spf HSD. Catch flag and reset depth to 14700.2' hydraulic disconnect depth. Pull up to 14571' placing guns across 14576-14596' interval. Gun fired after 33 bbls diesel pumped & CTP= 3000 psig. Pick up gun #3, 20' 2 7/8" 6 spf HSD. Catch flag and reset depth to 14700.2' disconnect depth. Pull up to 14551' placing guns across 14556-14576' interval. Gun fired after 33 bbls diesel pumped & CTP= 2700 psig. Well was POP while running in & out of well. Well put in test during last gun run. Time Operation 1-29 07:00 MIRU Dowell ctu #2, ctv-34.9 bbl. Gaslitt had been shut in previous mght. FWHP- 240, FWHT- 62, lAP-&00, OAP- 0. 09:00 Pull test Baker BHA 15k. 9:20 Pressure test coil 4000 9:44 Make up PDS tools. Press test BOPE 4000. 9:58 RIH. 11:35 10500' 24.5k wt. PDS and Dowell depth readings not agreeing and not consistent. Call for new Dowell encoder and bring PDS's depth wheel. 12:18 13000' 25k wt. 12:34 14000' 26.5k wt. 12:48 14660' 27k wt. 12:56 14800' Reset PDS depth counter. Logged up to 14700 and flag pipe (white). 13:12 14300' PDS running 5' shallow. Change out encoder. 13:22 Continue logging to check new encoder, no dice. 14:15 Install PDS encoder on spooling arm, RIH. 14:20 14800 start logging, at the previous flag of 14700 Dowell electronic=14698.8, PDS= 14700. Continue to log to 14250. 14:33 Set flag @ 14250.4 electronic. 14:45 13500' chains starting to slip. Put gaslift on, FWHT-60, heavy asphaltenes on p~pe causing the slip. Prepare to pump warm diesel. 15:32 Start pumping diesel. RIH slowly. 10 bbls. pumped. 16:27 10333' 22k wt. Very heavy p~pe, FWHT-98. 18:09 OOH, RDFN.. 1-30 Endicott 2-46B CT Conveyed Perf, 03/10/98 06:30 Pick up lubricator 07:00 Safety meeting, 7:30 Pick up gun #1, a 20' 2 7/8" 6 spf HSD, 60 degree phasing, random orientation loaded with 34j charges (15.2gm.), pressure test 3000, RIH, FWHP-250, FWHT-100, lAP-1300, OAP-0 9:43 S/I well 10:16 Catch flag @ 14722, correct to 14701.2 hydraulic disconnect depth. Pull to 14651 placing gun across 14656- 14676 interval. 10:29 Drop ball, start pumping diesel. 11:04 Gun fired at 2550 psi. Pumped 37 bbls SIWHP-1630. POOH. POP. 12:49 S/I well 13:00 OOH, POP. 13:36 Pick up gun #2, same as gun #1. 13:40 RIH. 15:38 $/I well. 15:53 Catch flag @ 14735. Correct to 14700.2, drop ball, pull to 14571 placing gun across 14576-14596 interval. 16:15 Start pumping diesel. 16:43 33 bbls pumped, gun deployed. POOH. POP. 18:30 1500'. Shut in well. Stack lift gas. 18:53 OOH. Change out crews. 19:08 Pop lubricator. Have holes. Break off gun and firing head. 19:22 Pick up Gun #3, 20' 2-7/8" 6spf HSD. PT thru backside line to 2500 psi. 19:43 Rih w/Gun #3. 21:02 @7000'. 12500 #. 21:42 @10500'. 16500 upwt. 22:00 @12300'. Shut-in well. 22:10 @ 13000'. 20000# up wt. 22:34 @ flag 14746.3'. Correct to 14700.2' hydraulic disconnect depth. Pull to 14551' placing gun across 14556'- 14576' interval. 22:45 Drop ball. Whp= 1688 psi. Start pumping @ 1.5 bpm. 23:10 Slow to 0.5 bpm after 28 bbls. 23:18 Fire gun @ 2700 psig after pumping 33 bbls diesel. 23:19 Up wt= 26,200 #. Pooh. 1-31 2:58 @ 1500'. SI oil choke to stack lift gas. 3:14 OOH. 3:40 All shots fired. RDMO Dowell CTU #2. 4:00 Whp= 1550 psig. POP well into TS. BBLS. Fluid Summary 113 Diesel BHA #1 Tool string Description II O.D. II I.D. II Length II Comments Fishing Neck 2.25" .92" 1.38' Check Valve 2.125" .812 1.37' Hydraulic Disconnect 2.125" .687 1.56' %" ball I ¼ MT x %" S.R. x/o 2.00" .67' %" S.R. x 5/8" S.R. 1.875" 1.83' PDS Toolstring 1.875" 7.83 GR/CCL Total Length 14.64 cci to disconnect 9.29' gr to disconnect.. 7.8' BHA #2, #3, & #4 Tool string Description II O.D. II I.D. II Length II Comments II Endicott 2-46B CT Conveyed Perf, 03/10/98 Fishing Neck 2.125" .92" 1.37' Check Valve 2.125" .812 1.36' Hydraulic Disconnect 2.125" .687 1.55 Baker crossover 2.125 .27' SWS x/o and firing head 2.125" 4.20 5/8" ball 2 7/8" gun 2.875" 21.23 TS-.67' Hyd. Dis. To TS 5.14' Endicott 2-46B CT Conveyed Perf, 03/10/98 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION I~ ~ E [IV ~ ~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [~] Oil [--IGas I--I Suspended [--]Abandoned I--]Service ,,,~,.~,o 2. Name of Operator 7. Permit Number ..... BP Exploration (Alaska)Inc. 97-71 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 :'~ ................ 50-029-21767-01 ~ ~:~;-~: ...~ . .... .., 4. Location of well at surface ........ ; .-.~ :-~.:,-, ...... 9. Unit or Lease Name ...... "~" '~ Duck Island Unit/Endicott 2036' SNL, 2300' WEL, SEC. 36, T12N, R16E, At top of productive interval '7' i ..~ 10. Well Number ' ' '~-."~ :~:~ ... ~?;...' ~~, 2-44A/Q-II 222 NSL, 3675' WEL, SEC. 26, T12N, R16E, UPM i~ At total depth :~- ..... 11. Field and Pool 318' NSL, 4875' WEL, SEC. 26, T12N, R16E, UPM '~ .... Endicott Field / Endicott Pool 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 55.10'I ADL 034633 12. Date Spudded10/9/97 113' Date T'D' Reached I 14' Date C°mp" Susp" °r Aband115' Water depth' if OffshOre 116' NO' °f c°mpleti°nsl 1/6/97 12/6/97 N/A MSLI One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD)I19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 14905 10256 R-I 14854 10229 FTI [~Yes I--INoI 1500' MDI 1465' (Approx.) 22. Type Electric or Other Logs Run USIT, MWD, LWD, GR/CCL ~ F~ I ('"' ~ \ I 23. CASING, LINER AND CEMENTING RECORD ! J ~'~ I 0 I ~/'~ U CASING SE'FI-lNG DEPTH HOLE SIZE WT, PER ET, GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 30" Structural Drive Pipe Surface 131' - Driven 13-3/8" 68# L-80 Surface 2497' 17-1/2" 4185 c.f. Permafrost 9-5/8" 47# NTSOS/NT95HS Surface 10512' 12-1/4" 575 c.f. Class 'G' 7" 29# L-80 3487' 13735' 8-1/2" 345 c.f. Class 'G' 4-1/2" 12.6# L-80 13554' 14900' 6" 201 c.f. Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-3/4" Gun Diameter, 6 spf 4-1/2", 12.6#, 13CR 11276' 11179' MD TVD MD TVD 13920'-13955' 9951 '-9957' 14055'-14085' 9974'-9980' 26. AGED, FRACTURE, CEMENT SQUEEZE, ETC. 14110'-14120' 9984'-9986' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 14636'-14656' 10130'-10138' Freeze protect with 27 bbls diesel 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) December 6, 1997I Gas Lift 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-MOF WATER-BBL O~L GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithoiogy, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. 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. TKEK 13765' 9924' SB10 13913' 9950' FL13 14060' 9975' FL10 14604' 10118' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and c~orrect to t,he.best of my knowledge Signed I~ C(.,~ iCi" - S h~l~rZ~ SteveShultz (."L~h~ [j~.~.~,~Jk~ ~-~0.. Title Engineering Supervisor Date 2-44A/Q-11 97-71 Prepared By Name/Number: Kathy Campoamor, 564-5122 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 28: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 2?.' 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 Facility End MPI Progress Report Well 2-44A/Q- 11 Rig Doyon 15 Page Date 1 31 January 98 Date/Time 28 Sep 97 29 Sep 97 30 Sep 97 01 Oct 97 02 Oct 97 03 Oct 97 04 Oct 97 05 Oct 97 06:00-06:30 06:30-10:30 10:30-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-14:30 14:30-18:00 18:00-18:30 18:30-21:00 21:00-22:00 22:00-00:00 00:00-06:00 06:00-06:30 06:30-08:00 08:00-13:30 13:30-14:00 14:00-15:00 15:00-16:00 16:00-18:00 18:00-18:30 18:30-19:30 19:30-22:30 22:30-23:30 23:30-01:30 01:30-02:30 02:30-06:00 06:00-06:30 06:30-12:00 12:00-12:30 12:30-13:00 13:00-14:00 14:00-18:00 18:00-18:30 18:30-20:30 20:30-21:00 21:00-00:00 00:00-00:30 00:30-05:00 05:00-05:30 05:30-06:00 06:00-06:30 Duration 1/2 hr 4hr 7-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 8hr 3-1/2 hr 1/2 hr 2-1/2 hr lhr 2hr 6hr 1/2 hr 1-1/2 hr 5-1/2 hr 1/2 hr lhr lhr 2hr 1/2 hr lhr 3hr lhr 2hr lhr 3-1/2 hr 1/2 hr 5-1/2 hr 1/2 hr 1/2 hr lhr 4hr 1/2 hr 2hr 1/2 hr 3hr 1/2hr 4-1/2 hr l/2hr 1/2 hr 1/2hr Activity Held safety meeting Rig moved 100.00 % Rig waited: Other delays Held safety meeting Rig waited: Other delays Held safety meeting Rig waited: Other delays Held safety meeting Rig waited: Other delays Held safety meeting Rig waited: Other delays Held safety meeting Rig waited: Other delays Held safety meeting Rig waited: Other delays Held safety meeting Rig waited: Other delays Held safety meeting Rig waited: Other delays Rig moved 100.00 % Held safety meeting Rigged up Fluid system Removed Hanger plug Rigged up Logging/braided cable equipment Conducted electric cable operations Held safety meeting Rigged down Logging/braided cable equipment Reverse circulated at 10800.0 ft Installed Hanger plug Removed Surface tree Removed Adapter spool Installed BOP stack Held safety meeting Installed BOP stack Tested All functions Removed Hanger plug Removed Tubing hanger Circulated at 10800.0 ft Laid down 10800.0 ft of Tubing Held safety meeting Laid down 10800.0 ft of Tubing Installed Wear bushing Serviced Top drive Made up BHA no. 1 Singled in drill pipe to 5225.0 ft Held safety meeting R.I.H. to 10800.0 ft Circulated at 10800.0 ft Pulled out of hole to 725.0 ft Pulled BHA Ran Drillpipe in stands to 10650.0 ft Installed Bridge plug Tested Casing Held safety meeting Facility End MPI Progress Report Well 2-44A/Q-11 Page 2 Rig Doyon 15 Date 31 January 98 Date/Time 06 Oct 97 07 Oct 97 08 Oct 97 06:30-07:30 07:30-10:30 10:30-11:00 11:00-13:30 13:30-14:30 14:30-15:30 15:30-18:00 18:00-18:30 18:30-20:00 20:00-21:00 21:00-22:30 22:30-23:00 23:00-01:00 01:00-05:00 05:00-06:00 06:00-06:30 06:30-07:00 07:00-08:00 08:00-10:00 10:00-11:30 11:30-15:30 15:30-16:30 16:30-17:30 17:30-18:00 18:00-18:30 18:30-21:00 21:00-22:00 22:00-22:30 22:30-23:30 23:30-01:00 01:00-02:00 02:00-03:30 03:30-04:30 04:30-06:00 06:00-06:30 06:30-07:00 07:00-09:30 09:30-10:30 10:30-18:00 18:00-18:30 18:30-05:00 05:00-06:00 06:00-06:30 06:30-08:30 08:30-11:30 11:30-12:30 12:30-13:00 13:00-16:00 16:00-16:30 16:30-18:00 18:00-18:30 18:30-19:00 19:00-19:15 19:15-20:00 Duration lhr 3hr 1/2 hr 2-1/2 hr lhr lhr 2-1/2 hr 1/2 hr 1-1/2 hr lhr 1-1/2 hr 1/2 hr 2hr 4hr lhr 1/2 hr 1/2 hr lhr 2hr 1-1/2 hr 4hr lhr lhr 1/2 hr 1/2 hr 2-1/2 hr lhr 1/2 hr lhr 1-1/2 hr lhr 1-1/2 hr lhr 1-1/2 hr 1/2 hr 1/2 hr 2-1/2 hr lhr 7-1/2 hr 1/2 hr 10-1/2 hr lhr 1/2 hr 2hr 3hr lhr 1/2 hr 3hr 1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 1/4 hr 3/4 hr Activity Circulated at 10650.0 ft Pulled out of hole to 0.0 ft Rigged up sub-surface equipment - Retrievable packer Ran Drillpipe in stands to 6000.0 ft Tested Casing Pulled Drillpipe in stands to 3000.0 ft Tested Casing Held safety meeting Tested Casing Serviced Block line Pulled out of hole to 0.0 ft Serviced Draw works Rigged up Logging/braided cable equipment Conducted electric cable operations Rigged down Logging/braided cable equipment Held safety meeting Set Retrievable packer at 60.0 ft with 0.0 psi Removed Seal assembly Removed BOP stack Removed Adapter spool Removed Seal assembly Installed Seal assembly Installed Adapter spool Tested Seal assembly Held safety meeting Installed BOP stack Tested BOP stack Installed Wear bushing Retrieved Retrievable packer Ran Drillpipe in stands to 4050.0 ft Circulated at 4050.0 ft Pumped out of hole to 0.0 ft Made up BHA no. 2 R.I.H. to 9000.0 ft Held safety meeting R.I.H. to 10650.0 ft Circulated at 10650.0 ft Pumped out of hole to 10500.0 ft Milled Casing at 10510.0 ft Held safety meeting Milled Casing at 10560.0 ft Circulated at 10560.0 ft Held safety meeting Circulated at 10550.0 ft Pulled out of hole to 725.0 ft Pulled BHA Worked on BOP - BOP stack Ran Drillpipe in stands to 10502.0 ft Washed to 10650.0 ft Circulated at 10650.0 ft Held safety meeting Batch mixed slurry - 38.000 bbl Tested High pressure lines Displaced slurry - 166.000 bbl Facility End MPI Progress Report Well 2-44A/Q-11 Rig Doyon 15 Page Date 3 31 January 98 Date/Time 09 Oct 97 10 Oct 97 11 Oct 97 12 Oct 97 13 Oct 97 14 Oct 97 15 Oct 97 20:00-20:30 20:30-21:00 21:00-00:00 00:00-00:30 00:30-04:00 04:00-05:00 05:00-06:00 06:00-06:30 06:30-07:30 07:30-08:30 08:30-12:00 12:00-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-03:00 03:00-04:30 04:30-06:00 06:00-06:30 06:30-07:30 07:30-09:30 09:30-10:00 10:00-13:00 13:00-13:30 13:30-16:30 16:30-18:00 18:00-18:30 18:30-19:30 19:30-20:00 20:00-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-19:30 19:30-23:00 23:00-00:30 00:30-01:30 01:30-05:00 05:00-06:00 06:00-06:30 06:30-07:00 07:00-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-06:00 Duration 1/2 hr 1/2 hr 3hr 1/2 hr 3-1/2 hr lhr lhr 1/2 hr lhr lhr 3-1/2 hr 6hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 8-1/2 hr 1-1/2 hr 1-1/2 hr 1/2 hr lhr 2hr 1/2 hr 3hr 1/2 hr 3hr 1-1/2 hr 1/2 hr lhr 1/2 hr 10hr 1/2 hr 11-1/2 hr 1/2hr 11-1/2 hr 1/2hr 11-1/2 hr 1/2 hr lhr 3-1/2 hr 1-1/2 hr lhr 3-1/2 hr lhr 1/2 hr 1/2hr llhr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr Activity Pulled Drillpipe in stands to 9700.0 ft Circulated at 9700.0 ft Pulled out of hole to 0.0 ft Worked on BOP - BOP stack Made up BHA no. 3 R.I.H. to 7000.0 ft Serviced Lines / Cables Held safety meeting R.I.H. to 9959.0 ft Washed to 10255.0 ft Drilled cement to 10512.0 ft Drilled to 10540.0 ft Held safety meeting Drilled to 10878.0 ft Held safety meeting Drilled to 11022.0 ft Held safety meeting Drilled to 11244.0 ft Circulated at 11244.0 ft Pumped out of hole to 7000.0 ft Held safety meeting Pulled out of hole to 4417.0 ft Pulled BHA Retrieved Wear bushing Tested All functions Installed Wear bushing Made up BHA no. 4 R.I.H. to 8701.0 ft Held safety meeting R.I.H. to 11233.0 ft Took MWD survey at 11233.0 ft Drilled to 11401.0 ft Held safety meeting Drilled to 11528.0 ft Held safety meeting Drilled to 11528.0 ft Held safety meeting Drilled to 11695.0 ft Held safety meeting Circulated at 11695.0 ft Pulled out of hole to 4228.0 ft Pulled BHA Made up BHA no. 4 R.I.H. to 10430.0 ft Serviced Block line Held safety meeting R.I.H. to 11694.0 ft Drilled to 11785.0 ft Held safety meeting Drilled to 11868.0 ft Held safety meeting Drilled to 12003.0 ft Held safety meeting Drilled to 12120.0 ft Facility End MPI Progress Report Well 2-44A/Q- 11 Rig Doyon 15 Page Date 4 31 January 98 Date/Time 16 Oct 97 17 Oct 97 18 Oct 97 19 Oct 97 20 Oct 97 21 Oct 97 22 Oct 97 23 Oct 97 06:00-06:30 06:30-08:00 08:00-12:30 12:30-13:30 13:30-15:00 15:00-18:00 18:00-18:30 18:30-20:30 20:30-21:00 21:00-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-07:30 07:30-09:00 09:00-13:30 13:30-14:30 14:30-15:30 15:30-18:00 18:00-18:30 18:30-19:30 19:30-22:30 22:30-23:00 23:00-00:00 00:00-00:30 00:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-23:00 23:00-00:30 00:30-04:00 04:00-05:00 05:00-06:00 06:00-06:30 06:30-11:00 11:00-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-08:00 08:00-13:00 13:00-14:30 14:30-15:30 Duration 1/2 hr 1-1/2 hr 4-1/2 hr lhr 1-1/2 hr 3hr 1/2 hr 2hr 1/2 hr 9hr 1/2hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr lhr 1-1/2 hr 4-1/2 hr lhr lhr 2-1/2 hr 1/2 hr lhr 3hr 1/2 hr lhr 1/2 hr 5-1/2 hr 1/2 hr 11-1/2 hr 1/2hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 4-1/2 hr 1-1/2 hr 3-1/2 hr lhr lhr 1/2 hr 4-1/2 hr 7hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 1-1/2 hr 5hr 1-1/2 hr lhr Activity Held safety meeting Circulated at 12120.0 ft Pulled out of hole to 189.0 ft Pulled BHA Made up BHA no. 5 R.I.H. to 4000.0 ft Held safety meeting R.I.H. to 11965.0 ft Washed to 12120.0 ft Drilled to 12195.0 ft Held safety meeting Drilled to 12290.0 ft Held safety meeting Drilled to 12360.0 ft Held safety meeting Drilled to 12366.0 ft Circulated at 12366.0 ft Pulled out of hole to 194.0 ft Pulled BHA Retrieved Wear bushing Tested BOP stack Held safety meeting Made up BHA no. 6 R.I.H. to 10400.0 ft Serviced Block line R.I.H. to 12250.0 ft Washed to 12366.0 ft Drilled to 12397.0 ft Held safety meeting Drilled to 12500.0 ft Held safety meeting Drilled to 12600.0 ft Held safety meeting Drilled to 12720.0 ft Held safety meeting Drilled to 12750.0 ft Circulated at 12750.0 ft Pulled out of hole to 194.0 ft Pulled BHA Made up BHA no. 6 Held safety meeting R.I.H. to 12750.0 ft Drilled to 12840.0 ft Held safety meeting Drilled to 12965.0 ft Held safety meeting Drilled to 13085.0 ft Held safety meeting Drilled to 13190.0 ft Held safety meeting Circulated at 13190.0 ft Pulled out of hole to 194.0 ft Pulled BHA Made up BHA no. 8 Facility End MPI Progress Report Well 2-44A/Q- 11 Rig Doyon 15 Page Date 5 31 January 98 Date/Time 24 Oct 97 25 Oct 97 26 Oct 97 27 Oct 97 28 Oct 97 29 Oct 97 15:30-18:00 18:00-18:30 18:30-19:30 19:30-20:30 20:30-21:30 21:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-19:30 19:30-00:00 00:00-01:00 01:00-04:00 04:00-06:00 06:00-06:30 06:30-11:00 11:00-12:00 12:00-18:00 18:00-18:30 18:30-23:30 23:30-00:00 00:00-01:00 01:00-03:30 03:30-05:30 05:30-06:00 06:00-06:30 06:30-08:30 08:30-10:30 10:30-12:30 12:30-16:00 16:00-17:00 17:00-17:30 17:30-18:00 18:00-18:30 18:30-22:00 22:00-01:30 01:30-02:30 02:30-04:00 04:00-05:00 05:00-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-20:00 20:00-21:00 21:00-22:30 22:30-01:00 01:00-04:30 04:30-06:00 06:00-06:30 Duration 2-1/2 hr 1/2 hr lhr lhr lhr 8-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2hr lhr 4-1/2 hr lhr 3hr 2hr 1/2 hr 4-1/2 hr lhr 6hr 1/2 hr 5hr 1/2 hr lhr 2-1/2 hr 2hr 1/2 hr 1/2 hr 2hr 2hr 2hr 3-1/2 hr lhr 1/2 hr 1/2 hr 1/2 hr 3-1/2 hr 3-1/2 hr lhr 1-1/2 hr lhr lhr 1/2 hr 11-1/2 hr 1/2hr 1-1/2 hr lhr 1-1/2 hr 2-1/2 hr 3-1/2 hr 1-1/2 hr 1/2 hr Activity R.I.H. to 5000.0 ft Held safety meeting R.I.H. to 10400.0 ft Serviced Block line R.I.H. to 13270.0 ft Drilled to 13270.0 ft Held safety meeting Drilled to 13410.0 ft Held safety meeting Drilled to 13540.0 ft Held safety meeting Drilled to 13655.0 ft Held safety meeting Circulated at 13655.0 ft Pulled out of hole to 194.0 ft Pulled BHA Tested BOP stack Made up BHA no. 9 Held safety meeting R.I.H. to 13620.0 fi Washed to 13655.0 ft Drilled to 13700.0 ft Held safety meeting Drilled to 13743.0 ft Fished at 13743.0 ft Circulated at 13743.0 ft Pulled out of hole to 9200.0 ft Pulled out of hole to 4100.0 fi Pulled BHA Held safety meeting Pulled out of hole to 233.0 fi Pulled BHA Pulled BHA R.I.H. to 10450.0 ft Serviced Block line R.I.H. to 13670.0 ft Washed to 13743.0 ft Held safety meeting Circulated at 13743.0 ft Pulled out of hole to 5206.0 fi Laid down 1377.0 ft of 5in OD drill pipe Pulled out of hole to 0.0 ft Rigged up Casing handling equipment Ran Liner to 800.0 ft (7in OD) Held safety meeting Ran Liner to 8750.0 ft (7in OD) Held safety meeting Ran Liner to 10233.0 ft (7in OD) Installed Liner hanger Circulated at 10240.0 ft Ran Drillpipe in stands to 13743.0 ft Circulated at 13743.0 ft Mixed and pumped slurry - 61.000 bbl Held safety meeting Facility End MPI Progress Report Well 2-44A/Q-11 Page 6 Rig Doyon 15 Date 31 January 98 Date/Time 30 Oct 97 31 Oct 97 01 Nov 97 02 Nov 97 03 Nov 97 06:30-08:00 08:00-08:30 08:30-10:00 10:00-10:30 10:30-11:30 11:30-13:00 13:00-13:30 13:30-16:30 16:30-17:00 17:00-18:00 18:00-06:00 06:00-18:00 18:00-18:30 18:30-20:00 20:00-21:30 21:30-23:00 23:00-06:00 06:00-06:30 06:30-09:30 09:30-10:30 10:30-11:00 11:00-12:00 12:00-12:30 12:30-13:30 13:30-14:00 14:00-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-11:30 11:30-12:00 12:00-12:30 12:30-16:30 16:30-18:00 18:00-18:30 18:30-19:30 19:30-20:00 20:00-23:00 23:00-01:30 01:30-05:00 05:00-06:00 06:00-06:30 06:30-07:30 07:30-08:00 08:00-18:00 18:00-18:30 18:30-03:30 03:30-06:00 06:00-06:30 06:30-09:00 09:00-10:30 10:30-11:00 11:00-12:30 12:30-17:30 Duration 1-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr lhr 1-1/2 hr 1/2 hr 3hr 1/2 hr lhr 12hr 12hr 1/2 hr 1-1/2 hr 1-1/2 hr 1-1/2 hr 7hr 1/2 hr 3hr lhr 1/2 hr lhr 1/2 hr lhr 1/2 hr 4hr 1/2 hr 11-1/2 hr 1/2 hr 5hr 1/2 hr 1/2hr 4hr 1-1/2 hr 1/2 hr lhr 1/2 hr 3hr 2-1/2 hr 3-1/2 hr lhr 1/2hr lhr 1/2 hr 10hr 1/2 hr 9hr 2-1/2 hr 1/2 hr 2-1/2 hr 1-1/2 hr 1/2hr 1-1/2 hr 5hr Activity Rigged down High pressure lines Circulated at 3500.0 ft Pulled Drillpipe in stands to 0.0 ft Rigged up sub-surface equipment - Tie back packer Ran Drillpipe in stands to 3504.0 pt Set packer at 3504.0 ft with 3000.0 psi Tested Casing - Via annulus and string Pulled Drillpipe in stands to 0.0 ft Serviced Drillstring handling equipment Singled in drill pipe to 936.0 ft Held safety meeting Held safety meeting Held safety meeting Pulled Drillpipe in stands to 0.0 ft Made up BI-IA no. 10 Serviced Drilling tool / logs Singled in drill pipe to 7800.0 ft Held safety meeting Singled in drill pipe to 11947.0 ft R.I.H. to 13566.0 ft Washed to 13656.0 ft Circulated at 13656.0 ft Tested Casing - Via annulus and string Drilled installed equipment - Landing collar Tested Casing - Via annulus and string Drilled cement to 13744.0 pt Held safety meeting Drilled to 13790.0 Pt Held safety meeting Drilled to 13809.0 Pt Circulated at 13809.0 ft Flow check Pulled out of hole to 203.0 ft Downloaded MWD tool Held safety meeting Pulled BHA Retrieved Wear bushing Tested All functions Made up BHA no. 11 R.I.H. to 11947.0 ft Serviced Block line Held safety meeting R.I.H. to 13755.0 ft Washed to 13809.0 ft Drilled to 13857.0 pt Held safety meeting Drilled to 13890.0 pt Pulled out of hole to 6500.0 fl Held safety meeting Pulled out of hole to 231.0 ft Downloaded MWD tool Pulled BHA Made up BHA no. 12 R.I.H. to 13857.0 ft Facility End MPI Progress Report Well 2-44A/Q-11 Page 7 Rig Doyon 15 Date 31 January 98 Date/Time 04 Nov 97 05 Nov 97 06 Nov 97 07 Nov 97 08 Nov 97 17:30-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-20:00 20:00-20:30 20:30-21:00 21:00-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-20:00 20:00-21:30 21:30-22:30 22:30-06:00 06:00-06:30 06:30-11:30 11:30-12:00 12:00-13:30 13:30-14:00 14:00-15:00 15:00-15:30 15:30-17:30 17:30-18:00 18:00-18:30 18:30-20:00 20:00-21:00 21:00-21:30 21:30-22:00 22:00-01:00 01:00-01:30 01:30-03:00 03:00-05:00 05:00-06:00 06:00-06:30 06:30-08:00 08:00-08:30 08:30-09:30 09:30-10:00 10:00-13:00 13:00-13:30 13:30-18:00 18:00-18:30 18:30-20:30 20:30-23:30 23:30-00:30 Duration 1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 9hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr lhr 7-1/2 hr 1/2 hr 5hr l/2hr 1-1/2 hr l/2hr lhr 1/2 hr 2hr 1/2 hr 1/2 hr 1-1/2 hr lhr l/2hr 1/2 hr 3hr 1/2 hr 1-1/2 hr 2hr lhr l/2hr 1-1/2 hr 1/2 hr lhr 1/2 hr 3hr 1/2 hr 4-1/2 hr l/2hr 2hr 3hr lhr Activity Washed to 13890.0 ft Held safety meeting Drilled to 14065.0 ft Held safety meeting Drilled to 14365.0 ft Held safety meeting Circulated at 14360.0 ft Pulled out of hole to 13675.0 ft R.I.H. to 14360.0 ft Drilled to 14524.0 ft Held safety meeting Drilled to 14600.0 ft Held safety meeting Drilled to 14714.0 ft Held safety meeting Drilled to 14866.0 ft Held safety meeting Drilled to 14905.0 ft Circulated at 14705.0 ft Pulled out of hole to 13744.0 ft Logged hole with LWD: Formation evaluation (FE) from 14744.0 ft to 14200.0 ft Held safety meeting Logged hole with LWD: Formation evaluation (FE) from 14200.0 ft to 14400.0 ft R.I.H. to 14905.0 ft Circulated at 14905.0 ft Flow check Pulled out of hole to 13273.0 ft Flow check Monitor wellbore pressures R.I.H. to 14905.0 ft Held safety meeting Circulated at 14905.0 ft Pulled out of hole to 13740.0 ft Flow check Circulated at 13740.0 ft Pulled out of hole to 9500.0 ft Flow check R.I.H. to 14905.0 ft Circulated at 14905.0 ft Circulated at 14905.0 ft Held safety meeting Circulated at 14905.0 ft Flow check Pulled out of hole to 13744.0 ft Circulated at 13744.0 ft Pulled out of hole to 10051.0 ft Flow check Pulled out of hole to 5074.0 ft Held safety meeting Pulled out of hole to 210.0 ft Downloaded MWD tool Pulled BHA Facility End MPI Progress Report Well 2-44A/Q-11 Page 8 Rig Doyon 15 Date 31 January 98 Date/Time 09 Nov 97 10 Nov 97 11 Nov 97 12 Nov 97 13 Nov 97 14 Nov 97 00:30-01:00 01:00-02:00 02:00-04:00 04:00-04:30 04:30-05:00 05:00-06:00 06:00-06:30 06:30-15:00 15:00-16:00 16:00-16:30 16:30-17:30 17:30-18:00 18:00-18:30 18:30-20:00 20:00-20:15 20:15-20:30 20:30-20:45 20:45-21:00 21:00-22:30 22:30-05:00 05:00-05:30 05:30-06:00 06:00-06:30 06:30-17:00 17:00-17:30 17:30-18:00 18:00-18:30 18:30-23:00 23:00-00:00 00:00-03:30 03:30-06:00 06:00-06:30 06:30-09:00 09:00-10:00 10:00-11:30 11:30-12:00 12:00-15:30 15:30-20:00 20:00-21:00 21:00-06:00 06:00-18:00 18:00-18:30 18:30-21:00 21:00-05:00 05:00-06:00 06:00-06:30 06:30-08:30 08:30-10:00 10:00-11:30 11:30-12:00 12:00-18:00 18:00-18:30 18:30-04:00 04:00-05:00 Duration 1/2 hr lhr 2hr 1/2 hr 1/2 hr lhr 1/2 hr 8-1/2 hr lhr 1/2 hr lhr 1/2 hr 1/2 hr 1-1/2 hr 1/4 hr 1/4hr 1/4 hr 1/4 hr 1-1/2 hr 6-1/2 hr 1/2hr 1/2 hr 1/2 hr 10-1/2 hr 1/2 hr 1/2 hr 1/2hr 4-1/2 hr lhr 3-1/2 hr 2-1/2 hr 1/2 hr 2-1/2 hr lhr 1-1/2 hr 1/2 hr 3-1/2 hr 4-1/2 hr lhr 9hr 12hr 1/2 hr 2-1/2 hr 8hr lhr 1/2hr 2hr 1-1/2 hr 1-1/2 hr 1/2 hr 6hr 1/2 hr 9-1/2 hr lhr Activity Serviced Block line Rigged up Tubing handling equipment Ran Liner to 1308.0 ft (4-1/2in OD) Rigged up sub-surface equipment - Liner hanger Circulated at 1308.0 ft Ran Liner on landing string to 4500.0 ft Held safety meeting Ran Liner on landing string to 13700.0 ft Circulated at 13700.0 ft Ran Liner on landing string to 14723.0 ft Washed to 14905.0 ft Rigged up Cement head Held safety meeting Circulated at 14905.0 ft Tested High pressure lines Mixed and pumped slurry - 36.000 bbl Displaced slurry - 130.000 bbl Set Liner hanger at 13580.0 ft with 2500.0 psi Circulated at 13580.0 ft Pulled Drillpipe in stands to 0.0 ft Rigged up sub-surface equipment - Tie back packer Ran Drillpipe in stands to 2000.0 ft Held safety meeting Ran Drillpipe in stands to 13484.0 ft Tested Casing Worked toolstring at 13484.0 ft Held safety meeting Pulled Drillpipe in stands to 13484.0 ft Serviced Block line Made up BI-IA no. 14 R.I.H. to 4000.0 ft Held safety meeting R.I.H. to 14819.0 ft Drilled installed equipment - Landing collar Drilled cement to 14850.0 ft Circulated at 14850.0 ft Circulated at 14850.0 ft Filter Brine Pulled out of hole to 13560.0 ft Held safety meeting Held safety meeting Held safety meeting Circulated at 13560.0 ft Pulled out of hole to 1310.0 ft Pulled BHA Held safety meeting Laid down 1000.0 ft of 5in OD drill pipe Installed BOP stack Rigged up Tubing handling equipment Held safety meeting Ran Tubing to 3500.0 ft (4-1/2in OD) Held safety meeting Ran Tubing to 9776.0 ft (4-1/2in OD) Installed SCSSSV Facility End MPI Progress Report Well 2-44A/Q- 11 Rig Doyon 15 Page Date 9 31 January 98 Date/Time 15 Nov 97 05:00-06:00 06:00-06:30 06:30-08:30 08:30-09:00 09:00-12:00 12:00-14:30 14:30-18:00 18:00-18:30 18:30-21:30 21:30-22:00 22:00-02:00 02:00-03:00 03:00-06:00 Duration lhr 1/2hr 2hr 1/2 hr 3hr 2-1/2 hr 3-1/2 hr 1/2 hr 3hr 1/2hr 4hr lhr 3hr Activity Ran Tubing to 10526.0 ft (4-1/2in OD) Held safety meeting Ran Tubing to 11276.0 ft (4-1/2in OD) Installed Tubing hanger Circulated at 11276.0 ft Set packer at 11179.0 ft with 3500.0 psi Removed BOP stack Held safety meeting Tested Xmas tree Installed Hanger plug Freeze protect well - 27.000 bbl of Diesel Installed Hanger plug Skid rig BPX Endicott Production Engineering Department INITIAL PERFORATIONS DATE: 12/6-8/97 WELL N°: 2-44a/Q-11 BP EXPLORATION REP: R. Clump SERVICE COMPANY: AWS (D. Caan) DATE/TIME OPERATIONS SUMMARY 12/6 0800 Miru AWS. SIP= 400 psig, lAP= 600 psig, & CAP = 0. Flow well w/LG to warm it up. 0930 Arm Gun # 1. No radio silence required (Guardian system being used). 0946 RIH w/Tractor tool / GR / CCL / & Gun # 1 (20'x 2-3/4", 6 spf, gm). MP to TS= 2'. 1040 Tools sitting down @ approx. 11650' md. Power up tractor. Tractor down to 14380'. Get pickup wt of 2625#. Rih to 14750'. Have a little trouble getting through liner pkr @ Log tie in strip from 14750 - 14500'. Tied into Sperry-Sun MWD dated 11/9/97. Log confirmation strip. Still not on depth. Log another confirmation strip (- 2'). Log into place @ CCL depth of 14634' md bkb. 1340 Shoot Gun #1 from 14636'-14656' md bkb. Good signs. 100# wt loss, echo-meter picked up shot nicely. Log off. Pull tool string into 7" liner. POP well w/o LG. Well seems to want to flow fairly well. SI well after flowing for 20 mins. POOH. 1500 CCH. WHP= 900 psi. POP well w/LG while ATLAS arming Gun #2. 1530 SI well. Haven't seen oil to surface yet, but well seems to be unloading real well. Rih w/Gun #2 (20'x 2-1/2", 4 spf, 10.5 gm). Note: 2-3/4" guns didn't make it on the plane from Los Angeles. 1620 Start up tractor after sitting down at 11650'. Tractor down to 4-1/2" liner top. Work for 2-1/2 hrs cannot get back in liner. Log strip and it is apparent gun is making it into liner, but CCL is not making it in. POOH. 2100 CCH. WHP- 1750 psig. POP well w/LG. Well showing oil at sample point after ~,~ hr. Put well in HFT (initially flowing from 8000 - 3000 GFR). 12/7 0800 Miru AWS. FWHP= 400 psig (control room FWHP= 311 psig), FWHT= 72 deg F (control room FWHT= 107 deg F), lAP= 1500 psig, CAP=0. 0918 SI well & Rih w/Gun #2 (20x 2-1/2", 4spf, 10.5 gm charges)/Tractor/3" Rollers on btm of gun. GR to TS= 3.5'. 1000 Set down at 11610'. Pickup wt - 2400#. Start up tractor & Rih. 1100 Stop @ ZXP 4-1/2" liner pkr. Work, Work, Work, Work ........ No luck. Pull up hole in 7" liner. POP well @ 70 beans. Flow for ¥~ hr. Pinch back to 20 beans. Try and tractor thru. No luck. Shut-in well and try some more. No luck. Log off strip shows gun body thru, just like yesterday. POOH. 1445 CCH. No marks or evidence of any problems on tools. Add 3-5/8"rollers above x- over sub and leave 3" rollers on top and btm of tool string. .. 1515 Rih w/new roller configuration and Gun #2. 1600 Start tractor up at 11700'. Got a little deeper this time with this set up. Tractor on down to the normal sit down pt. Work several times. No luck. Log off. Gun made it into the liner once again. But appears to be setting down even a few feet higher this time. 1830 Pooh. Have no other options than running either 3-3/8"x 10' gun or possibly 2- 1/2"x10' gun (Atlas may or may not have 2-1/2x10' gun). No word on 2-7/8"guns, but won't be here tomorrow. 1915 OOH. Atlas rig down for the night. POP w/,-, 2.0 mscf GL. Whp= 1700 psig. 12/8 0800 Atlas Miru. Only have 3-3/8" x 10' guns to try today. 0915 Rih w/tractor/switching sub/3.5" roller sub/PFC GR & CCL/Gun #2 (3-3/8"x 10', 6 spf)/and 3-1/2" roller sub on btm. 1020 Start tractor from the usual spot. Roll down to liner top. Work several times. No luck. Log off. Gun didn't even make it in liner this time. Had pickup at 13535' md this time. Pooh. 1330 Decide to Rih w/just tractor. Do the usual. Tractor won't make it inside the liner. Latest news about 2-7/8" guns - - maybe in Seattle now. Plan next move w/PE Supervisor / Anch Engineer. Probably time to try this w/CTU. 1530 Atlas OOH. No evidence on tool string. Atlas rig down and move off. 1845 POP w/LG. Summary: PERFORATION SUMMARY: GUN INTERVAL SUBZONE LENGTH I 14636'-14656' MD Fiji 20' All perforations were shot using 2-3/4" AWS deep penetrating guns, 6 spf with random orientation. 5 differently configured tractor runs were made in the attempt to shoot the remaining 60' of perfs called for in the program. Could not get inside the 4-1/2" liner w/tractor tool. 2-1/2" x 20' guns would make it inside liner, but would stop near the tractor itself. A run was tried w/3-3/8"x10' gun and 3- 1/2" roller sub on btm. This run didn't even allow the gun itself to enter liner. Some of the possible troubles could be: 1. Debris from gun #1. 2. Debris from IUD fishing job. Alum. Leftovers ..-1-1/2" disk??? 3. The gun size itself. For some reason, w/a little work 2-3/4"x 20' guns made it down numerous times. But, not able to get the air-freight people excited about getting us anymore of these rascals up here. So this might still be an option in the future. However, seems like we simulated the 2-3/4"x 10' guns fairly well and should have made it down? Plan on moving in CTU unit perforate the rest of the intervals. BPX Endicott Production Engineering Department INITIAL PERFORATIONS DATE: 11/23/97 WELL N°: 2-44a/Q-11 BP EXPLORATION REP: VARBLE SERVICE COMPANY: AWS (KOENN) DATE/TIME J OPERATIONS SUMMARY 11/23 0700 MIRU AWS SIP = 300 lAP = 100 CAP = 0 0800 Arm gun # 1 (10') 0850 RIH with Tractor tool/PFC/COL / Gun # 1 (10' 2-3/4") 1000 Tools sitting down @ approx. 11650' md. Power up tractor. COL not working. POOH. 1100 CCH. Trouble shoot tools. Cable head gassed up. 1200 Cut approx. 100' of gassed up cable. Re-head. 1300 RIH with same. 1345 Tools sitting down @ approx. 11650' md. Power up tractor tool & motor down hole. (no problems entering 4-1/2" liner) 1500 Log tie in pass. Tie into MWD Icg dated 11/9/97. Take out 16'. (flag line) 1530 Log confirmation pass. On depth. Log into place @ 14106' md. (4' from COL to top shot) 1600 Bleed whp down to 200 psi. (approx 100 psi underbalanced) 1615 Shoot gun # 1 from 14110'-14120' md. Good cap break & lost approx. 100 # weight. No change in whp. 1625 Log off. 1630 Tractor down hole. 1715 Tag TD @ 14841' md. Log GR-CCL up thru jewelry. POOH 1930 CCH. Confirm all shots fired. 2030 Secure well & LDFN. SIWHP = 350 1/24 0700 RU AWS SIWHP = 350 lAP = 100 CAP = 0 0800 Arm gun # 2 0830 RIH with Tractor tool / PFC / COL / gun # 2 (20' 2-3/4") 0930 Tools sat down @ approx. 11700' md. Power up tractor tool & motor down hole. 1025 At flag. Log tie in pass. Take out 10' 1032 Tractor down & Icg confirmation pass. On depth. Hang COL @ 14061' (4' from COL to top shot) Bleed whp down to 100 psi. 1046 Shoot gun # 2 from 14065'-14085' md. Good cap break, lost 150 #. No change in whp. 1048 Log off & POOH. 1115 CCH. Confirm all shots fired. 1130 Arm gun Cf 3 (10' 2-3/4") 1210 RIH with gun Cf 3 1300 Sat down @ approx. 11700' md. Power up tractor tool & motor down hole. 1415 At flag. Log tie in pass. Take out 2'. 1440 Log confirmation pass. On depth. Hang CCL @ 14051' md. (4' from CCL to top shot) Bleed whp down to 0 psi. 1445 Shoot gun Cf 3 from 14055'-14065' md. Good cap break, lost 150 Cf. No change in whp. 1448 Log off. POOH. 1600 OOH. All shots fired. 1730 Secure well & LDFN. SIWHP - 0 11/25 0700 Rig up. SIWHP = 0 lAP = 100 OAP - 0 0800 Arm gun Cf 4 (20' 2-3/4") 0830 RIH with Tractor tool / PFC / CCL / GUN # 4 0920 Sat down @ 11700' md. Power up tractor & motor down hole. 1010 Sitting down @ top of 4-1/2" liner. 1020 Worked thru. Motor down hole. 1036 At flag. Log tie in pass. Take out 1' 1047 Log confirmation pass. On depth. Hang CCL @ 13931 '. (4' from CCL to top shot) 1055 Shoot gun Cf 4 from 13935'-13955' md. Good cap break, lost 125 Cf weight. No change in whp. 1057 Log off. POOH. 1140 OOH. All shots fired. Arm gun Cf 5 (15' 2-3/4") 1215 RIH with gun #5. 1310 Sat down @ 11700' md. Power up tractor & motor down hole. 1415 At flag. Log tie in pass. On depth. 1430 Log confirmation pass. Add 2' 1442 Tractor down hole & log again. On depth. Log into place & hang CCL @ 13911 '. (9' from CCL to top shot) 1458 Shoot gun Cf 5 from 13920'-13935' md. Good cap break, lost 150 #. No change in whp. 1500 Log off. POOH. 1600 OOH. All shots fired. 1600 RIH with GR-CCL / Press - Temp 1715 Tie into TT. 1725 Log 1 hr. pressure stop @ 11629' md. (9600 tvd) 1825 Pull up hole to 10822' md. & log 5 min. stop. (9100 tvd) 1830 Pull up hole to 10125' md. & log 5 min. stop. (8600 tvd) 1835 POOH. 1920 OOH. 2030 RDMO. POP with methanol. PERFORATION SUMMARY: GUN INTERVAL SUBZONE LENGTH 1 13920'-13955' MD FV 35' 2 14055'-14085' MD FV 30' 3 14110'-14120' MD FV 10' All perforations were shot using 2-3/4" AWS deep penetrating guns, 6 spf with random orientation. 5 total gun runs were made, as we could not run the 2-3/4"guns in the select fire mode. Logged Tbg. tail @ 11267' ELMD. SIBHP extrapolated outto 5018 psi. @ 10000' tvd. SIBHP - 190 deg,. F. @ 9600' tvd SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 1 SHARED SERYICES DRILLING ENDICOTT / 2-44A/Q-Ii 500292176701 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/ 1/97 DATE OF SURVEY: 110697 MWD SURVEY JOB NUMBER: AKMM70280 KELLY BUSHING ELEV. = 55.20 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 10479.19 8878.46 8823.26 44 54 N 79.66 W .00 10510.00 8900.27 8845.07 44 58 N 79.68 W .24 10515.00 8903.81 8848.61 44 58 N 79.68 W .40 10566.40 8939.52 8884.32 47 3 N 85.66 W 9.30 10599.03 8961.24 8906.04 49 27 N 89.46 W 11.36 734.45N 4015.37W 3935.34 738.35N 4036.78W 3956.31 738.99N 4040.26W 3959.72 743.67N 4076.91W 3994.76 744.69N 4101.22W 4017.10 10632.10 8982.39 8927.19 51 2 S 86.87 W 9.81 10662.14 9000.99 8945.79 52 28 S 83.54 W 9.92 10696.70 9022[06 8966.86 52 22 S 81.32 W 5.10 10728.24 9041.35 8986.15 52 14 S 82.76 W 3.64 10758.10 9059.77 9004.57 51 .34 S 84.27 W 4.55 744.10N 4126.63W '4039.73 742.12N 4150.14W 4060.04 738.52N 4177.29W 4082.92 735.06N 4202.00W 4103.67 732.4tN 4225.35W 4123.54 10792.86 9081.67 9026.47 50 20 S 89.39 W 11.97 10825.71 9102.72 9047.52 49 57 N 85.79 W 11.33 10853.79 9120.87 9065.67 49 34 N 80.40 W 14.71 10889.37 9144.00 9088.80 49 22 N 75.71 W 10.03 10921.43 9165.17 9109.97 47 59 N 73.28 W 7.14 730.90N 4252.29W 4147.15 731.69N 4277.48W 4170.18 734.26N 4298.75W 4190.45 739.86N 4325.19W 4216.70 746.29N 4348.39W 4240.38 10949.85 9184.31 9129.11 47 20 N 67.85 W 14.30 10985.12 9208.42 9153.22 46 27 N 64.10 W 8.17 11015.61 9229.48 9174.28 46 10 N 59.69 W 10.50 11046.10 9250.76 9195.56 45 18 N 58.63 W 3.76 11079.52 9274.72 9219.52 43 5 N 53.94 W 11.81 753.27N 4368.19W 4261.25 763.74N 4391.71W 4286.98 774.12N 4411.15W 4309.00 785.31N 4429.89W 4330.75 798.22N 4449.27W 4353.81 11110.67 9297.69 9242.49 41 55 N 50.33 W 8.68 11141.57 9320.72 9265.52 41 43 N 43.89 W 13.91 11174.22 9345.07 9289.87 41 50 N 44.46 W 1.21 11221.81 9379.72 9324.52 44 43 N 40.22 W 8.60 11255.32 9403.45 9348.25 45 4 N 39.21 W 2.38 811.13N 4465.89W 4374.39 825.14N 4480.97W 4394.07 840.75N 4496.13W 4414.50 864.87N 4518.07W 4444.75 883.07N 4533.19W 4466.27 11286.88 9425.64 9370.44 45 34 N 39.34 W 1.58 11318.80 9447.78 9392.58 46 35 N 38.82 W 3.40 11353.68 9471.40 9416.20 48 10 N 40.03 W 5.20 11385.73 9492.13 9436.93 51 12 N 41.03 W 9.78 11415.01 9509.83 9454.63 54 25 N 42.10 W 11.34 900.44N 4547.39W 4486.61 918.29N 4561.89W 4507.42 938.11N 4578.19W 4530.72 956.68N 4594.07W 4553.10 974.12N 4609.55W 4574.62 11450.26 9529.38 9474.17 58 12 N 42.95 W 10.91 995.73N 4629.37W 4601.87 11479.58 9544.05 9488.85 61 43 N 43.89 W 12.32 1014.16N 4646.82W 4625.59 11512.55 9558.83 9503.63 65 0 N 44.24 W 10.02 1035.34N 4667.31W 4653.25 11545.46 9571.96 9516.76 67 56 N 45.81 W 9.95 1056.66N 4688.66W 4681.75 11577.54 9583.49 9528.29 69 55 N 47.68 W 8.23 1077.17N 4710.46W 4710.30 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 SHARED SERVICES DRILLING ENDICOTT / 2-44A/Q-ii 500292176701 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/ 1/97 DATE OF SURVEY: 110697 [~D SURVEY JOB NUMBER: AKM~70280 KELLY BUSHING ELEV. = 55.20 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 11606.57 9593.10 9537.90 71 24 N 49.72 W 8.34 1095.24N 4731.04W 4736.69 11633.38 9601.14 9545.94 73 42 N 50.75 W 9.36 llll.60N 4750.69W 4761.50 11674.13 9611.38 9556.18 77 10 N 52.48 W 9.43 1136.08N 4781.61W 4799.98 11702.41 9617.10 9561.90 79 30 N 52.66 W 8.26 1152.91N 4803.60W 4827.10 11737.63 9622.97 9567.77 81 18 N 52.55 W 5.15 1173.99N 4831.18W 4861.11 11767.57 9627.26 9572.06 82 11 N 53.13 W 3.54 1191.89N 4854.80W 4890.16 11799.58 9631.21 9576.01 83 38 N 55.74 W 9.26 1210.36N 4880.63W 4921.46 · 11848.52 9636.51 9581.31 83 55 N 56.83 W 2.29 1237.37N 4921.10W 4969.64 11894.91 9641.10 9585.90 84 43 N 57.52 W 2.29 1262.39N 4959.89W 5015.45 11929.24 9644.01 9588.81 85 31 N 56.62 W 3.50 1280.98N 4988.60W 5049.39 11992.43 9648.81 9593.61 85 45 N 56.79 W .45 1315.57N 5041.27W 5111.85 12055.15 9653.95 9598.75 84 50 N 58.06 W 2.49 1349.22N 5093.94W 5173.92 12092.80 9657.26 9602.06 85 4 N 55.94 W 5.64 1369.65N 5125.38W 5211.11 12187.93 9668.22 9613.02 81 41 N 54.08 W 4.05 1423.82N 5202.79W 5304.37 12284.34 9681.71 9626.51 82 13 N 54.98 W 1.08 1479.21N 5280.53W 5398.47 12380.60 9695.42 9640.22 81 23 N 55.49 W 1.02 1533.54N 5358.80W 5492.57 12475.08 9710.82 9655.62 79 50 N 55.72 W 1.65 1586.19N 5435.71W 5584.72 12571.21 9727.11 9671.91 80 38 N 55.34 W .91 1639.81N 5513.81W 5678.37 12667.22 9742.95 9687.75 80 21 N 53.95 W 1.46 t694.60N 5591.04W 5771.74 12766.41 9759.25 9704.05 80 43 N 52.41 W 1.57 1753.23N 5669.36W 5867.75 12861.90 9774.09 9718.89 81 24 N 52.36 W .71 1810.81N 5744.08W 5960.07 12959.09 9790.17 9734.97 79 33 N 52.37 W 1.89 1869.33N 5819.97W 6053.86 13053.97 9806.66 9751.46 80 25 N 52.16 W .93 1926.51N 5893.86W 6145.27 13142.16 9822.20 9767.00 79 16 N 51.98 W 1.31 1979.87N 5962.33W 6230.13 13239.23 9841.24 9786.04 78 5 N 53.53 W 1.99 2037.47N 6038.09W 6323.39 13334.22 9861.08 9805.88 77 48 N 57.06 W 3.65 2090.35N 6114.45W 6415.15 13367.67 9868.54 9813.34 76 24 N 58.86 W 6.71 2107.65N 6142.08W 6447.55 13400.22 9876.03 9820.83 76 58 N 61.32 W 7.56 2123.44N 6169.53W 6479.14 13430.45 9882.08 9826.88 79 57 N 61.18 W 9.87 2137.68N 6195.50W 6508.71 13464.73 9887.58 9832.38 81 34 N 63.96 W 9.28 2153.27N 6225.53W 6542.53 13496.72 9892.07 9836.87 82 18 N 66.67 W 8.69 2166.49N 6254.30W 6574.19 13526.96 9895.71 9840.51 83 52 N 69.12 W 9.57 2177.79N 6282.11W 6604.15 13559.29 9898.84 9843.64 85 0 N 71.39 W 7.81 2188.66N 6312.39W 6636.14 13591.74 9901.69 9846.49 84 56 N 73.78 W 7.34 2198.33N 6343.23W 6668.12 13629.02 9905.61 9850.41 82 58 N 74.46 W 5.56 2208.47N 6378.88W 6704.63 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 SHARED SERVICES DRILLING ENDICOTT / 2-44A/Q-!l 500292176701 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/ 1/97 DATE OF SURVEY: 110697 MWD SURVEY JOB NUMBER: A~70280 KELLY BUSHING ELEV. = 55.20 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 13658.97 9909.47 9854.27 82 13 N 75.70 W 4.83 2216.12N 6407.58W 6733.80 13681.30 9912.52 9857.32 82 4 N 78.14 W 10.84 2221.12N 6429.12W 6755.38 13700.46 9915.14 9859.94 82 11 N 78.50 W 1.96 2224.96N 6447.71W 6773.79 13734.21 9919.57 9864.37 82 41 N 79.12 W 2.33 2231.46N 6480.53W 6806.16 13765.67 9923.83 9868.63 81 45 N 79.70 W 3.48 2237.19N 6511.17W 6836.25 13794.44 9928.16 9872.96 80 54 N 80.23 W 3.47 2242.14N 6539.17W 6863.62 13829.33 9934.32 9879.12 78 46 N 80.87 W 6.39 2247.78N 6573.04W 6896.57 13864.80 9941.29 9886.08 78 34 N 81.53 W 1.91 2253.10N 6607.41W 6929.84 13895.60 9947.04 9891.84 79 54 N 84.10 W 9.27 2256.88N 6637.43W 6958.51 13927.65 9952.43 9897.23 80 45 N 86.15 W 6.84 2259.57N 6668.90W 6988.03 13956.16 9957.08 9901.88 80 27 N 86.74 W 2.28 2261.31N 6696.97W 7014.06 13985.59 9961.98 9906.78 80 21 N 86.63 W .50 2262.99N 6725.94W 7040.88 14079.91 9978.64 9923.44 79 18 N 86.86 W 1.15 2268.26N 6818.63W 7126.64 14175.37 9997.22 9942.02 78 15 N 85.52 W 1.76 2274.48N 6912.04W 7213.47 14270.39 10019.12 9963.92 75 5 N 84.68 W 3.42 2282.37N 7004.16W 7299.85 14368.49 10044.81 9989.61 74 31 N 84.69 W .58 2291.14N 7098.42W 7388.56 14461.02 10070.63 10015.43 73 3 N 85.31 W 1.71 2298.89N 7186.93W 7471.63 14558.55 10101.67 10046.47 69 49 N 83.86 W 3.60 2307.60N 7278.96W 7558.30 14653.17 10136.53 10081.33 66 55 N 81.33 W 3.95 2318.91N 7366.18W 7641.76 14746.62 10176.16 10120.96 62 52 N 81.95 W 4.39 2331.22N 7449.88W 7722.49 14844.90 10224.34 10169.14 58 24 N 79.84 W 4.91 2344.74N 7534.44W 7804.51 14905.00 10255.83 10200.63 58 24 N 79.84 W .00 2353.77N 7584.83W 7853.82 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 7941.65 FEET AT NORTH 72 DEG. 45 MIN. WEST AT MD = 14905 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 295.77 DEG. TIE-IN SURVEY AT 10,479.19' MD WINDOW POINT AT 10,515.00' MD PROJECTED SURVEY AT 14, 905.00' MD SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 SHARED SER¥'ICES DRILLING ENDICOTT / 2-44A/Q-ii 500292176701 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/ 1/97 DATE OF SURVEY: 110697 JOB NUMBER: AKMM70280 KELLY BUSHING ELEV. = 55.20 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 10479.19 8878.46 8823.26 11479.19 9543.87 9488.67 12479.19 9711.54 9656.34 13479.19 9889.66 9834.46 14479.19 10076.02 10020.82 734.45 N 4015.37 W 1013.92 N 4646.58 W 1588.47 N 5439.05 W 2159.41 N 6238.45 W 2300.35 N 7204.22 W 1600.73 1935.32 334.59 2767.65 832.32 3589.53 821.89 4403.17 813.64 14905.00 10255.83 10200.63 2353.77 N 7584.83 W 4649.17 246.00 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 5 SHARED SERVICES DRILLING ENDICOTT / 2-44A/Q-It 500292176701 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/ 1/97 DATE OF SURVEY: 110697 JOB NUMBER: AKMM70280 KELLY BUSHING ELEV. = 55.20 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 10479.19 8878.46 8823.26 734.45 N 4015.37 W 1600.73 10589.87 8955.20 8900.00 744.49 N 4094.35 W 1634.67 33.94 10750.72 9055.20 9000.00 733.02 N 4219.59 W 1695.53 60.85 10906.43 9155.20 9100.00 743.18 N 4337.62 W 1751.23 55.70 11052.34 9255.20 9200.00 787.68 N 4433.59 W 1797.14 45.92 11187.96 9355.'20 9300.00 847.47 N 4502.52 W 1832.76 35.61 11329.64 9455.20 9400.00 924.43 N 4566.86 W 1874.44 41.68 11504.23 9555.20 9500.00 1029.96 N 4662.10 W 1949.03 74.59 12069.18 9655.20 9600.00 1356.70 N 5105.75 W 2413.98 464.96 12741.27 9755.20 9700.00 1738.10 N 5649.69 W 2986.07 572.08 13306.28 9855.20 9800.00 2075.27 N 6091.67 W 3451.08 465.01 13944.76 9955.20 9900.00 2260.65 N 6685.75 W 3989.56 538.48 14407.26 10055.20 10000.00 2294.58 N 7135.62 W 4352.06 362.50 14698.95 10155.20 10100.00 2325.11 N 7407.52 W 4543.75 191.69 14905.00 10255.83 10200.63 2353.77 N 7584.83 W 4649.17 105.42 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS State ot Alaska Alaska Oil & Gas Conservation Comm. Atten: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Transmittal of Final Prints. Please sign and return copy to: Western Altas Logging Services Pouch 340013 Prudhoe Bay, AK 99734-0013 17-Dec-97 iiWell Name 2-44 NO-11 .2-46 B/8-13 i Services Bluelines R/F Sepia Film !,GR/CCL PERF 1 1 0 ;! 'iGR/CCL PERF 1 1 0 i: ?leEeiedb~ ,...EC 'l 9 199~' Contact Rebecca Lange if you have a question concerning this transmittal at (907) 659-2816 or Fax (907) 659-2602. GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrle NO. 11619 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Endicott (Cased Hole) 12/8/97 Well Job # Log Description Date BL RF Sepia LIS Tape 1 - 01/J - 19 TUBG.PATCH SET RECORD 971 016 1 1 1 - 19 / I- 18 PERFORATION RECORD 970901 1 1 1-1 9/I-1 8 PRODUCTION PROFILE 971 010 I 1 1 - 31 / M - 21 PERFORATING RECORD 971004 I 1 1 - 33 / M - 23 PERFORATING RECORD 971004 I 1 1-43/P-26 ~-. INJECTION PROFILE 970910 I 1 1 - 67/T- 20 PERFORATING RECORD 971013 1 1 · , 2-44/R-12 ~.i ~ JET CUTTER RECORD 971 003 1 1 2-44A/Q-11 USIT/CEMENT CORROSION LOG 971 006 I 1 3-17B/M-31 PLUG SET RECORD 97091S 1 1 ,, 3-17B/M-31 PRODUCTION LOG 971 014 1 1 3-17B/M-31 GAS LIFT SURVEY 971014 I 1 3-45/M-39 (./t..I ~ INJECTION PROFILE 971 029 I 1 3-49A/M-40 PRODUCTION PROFILE 97071 4 1 1 4-1 0/M-28 ~ - ~ .'.~ ~ PERFORATING RECORD 971 01 2 I 1 4- 38 ! K- 34 PERFORATION RECORD 970914 I I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 BI F:t I I--I-- I IM G SEE F:! L/I r' Ec; WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Drive Anchorage, Alaska 99501 MWD Formation Evaluation Logs Z44A/Q-11, AK-MM-70280 December 10, 1997 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this of this transmittal letter to the attention of.' Ylm Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2-44A/Q-II: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-21767-01 2"x 5" TVD Resistivity & Gamma Ray Logs: 50-029-21767-01 2"x 5"MD Neutron & Density Logs: 50-029-21767-01 2"x 5" TVD Neutron & Density Logs: 50-029-21767-01 1 Blueline 1 Rev Folded Sepia 1 Blueline 1 Rev Folded Sepia 1 Blueline 1 Rev Folded Sepia 1 Blueline 1 Rev Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 , Fax (907) 563-7252 A Dresser Industries, Inc. Company WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Lori Taylor 3001 Porcupine Drive. Anchorage, Alaska 99501 q'/"~ MWD Formation Evaluation Logs - 2 ddA/Q-11, AK-MM-70280 December 10, 1997 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Jan Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-21767-01 5631 Silverado Way, Suite G · Anchorage, AJaska 99518 · (907) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company Sta~ of Alaska Alaska Oil & Gas Conservation Comm. Atten' Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Transmittal of Final Prints. Please sign and return copy to: Western Altas Logging Services Pouch 340013 Prudhoe Bay, AK 99734-0013 28-Nov-97 Services Bluelines R/F Sepia Film Well Name 2-44 A/Q-11 GR/CCL PERF 1 1 0 2-44 A/Q-11 STATIC SURVEY 1 1 0 2-44 A/Q-11 'GR/CCL JEWELRY LOG 1 1 0 :2-46 B/S-13 GR/CCL PERF 1: 1 0 2-46 B/S-13 GR/CCL JEWELRY LOG 1 1 0 · Receive~~ Contact Rebecca Lange if you have a question concerning this transmittal at (907) 659-2816 or Fax (907) 659-2602. 1111 E. 80th Ave. Anchorage, Alaska 99518 TEL (907) 349-4511 FAX (907) 349-2487 Date: 10-Nov-97 Well Name: 2-44A/Q-11 Company: Shared Services Drilling A_PI Number: 50-029-21767-0 1 Location: North Slope, Alaska Field: Endicott, MPI Rig: Doyon 15 Anadrill Personnel Field Crew: · Cell Managers: Cell Engineers: Michael Dammeyer Enigo Del Busto Field Support: Alaska District Manager: Martin Varco Field Service lVlanager: Craig Brown SERVICES PROVIDED Service Azimuthal Density-Neutron (Al)N) Service Dates 30 Oct 97 - 08 Nov 97 Depth Interval 13744' - 14905' OPERATING STATISTICS Total LWD Pumping Hours: Total LWD Below Rotary Hours: Total LWD Footage Al)N: Total LWD Runs: Al)N: JOB PERFORMANCE FORMATION EVALUATION 97.3 230.0 1151' 3 t~0V 2 ] 1997 Alaska Oil & Gas Cons. Comrni'ssior~ Anchorage Recorded mode logs and ASCII data were faxed/e-mailed within hours alter the tool was above the rotary table. Lessons learned When using the nuclear source handling tool, engineers should be itware that the source head can become lodged in the tool. It can be dislodged by pulling up sharply-on the handling tool. The formations at Endicott are difficult to drill. Therefore, when running a recorded mode nuclear tool, it may be best to wait until the f'mal run and ream the necessary intervals to bottom. This would not only provide a better log over the desired interval, but would also be cost effective to the client. Measurements will significantly improve with a stabilized tool. The 4 3A ADN with 6" integral stabilizer will be available toward the end of Q4, 1997 Anadrill appreciates the opportunity to provide BP Exploration and Shared Services Drilling with MWD and LWD services. Sincerely, Craig Brown Field Service Manager, Alaska District MEMORANDUM TO: THRU: David Johnst°.~ Chairman Blair Wondzell, P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission DATE: November 1, 1997 FILE NO: akhklaee.doc FROM: Chuck Scheve, ~.~ SUBJECT: Petroleum Inspector BOPE Test Doyon 15 DIU 2-44a / Q-11 PTD # 97-71 Saturday November 1, 1997: ! traveled to BPX's DIU 2-44a / Q-11 Well being drilled by Doyon Rig 15 and witnessed the weekly BOPE test. As the attached AOGCC BOPE test report shows the test lasted 3 hours with one failure. The lower 3x6 variable bore rams failed to pressure test. These were replaced with a set of 3.5" pipe rams and tested by the toolpusher after I departed location. The test went well with good test procedures being employed by the Doyon crews. The rig was clean and all related equipment appeared to be in good working order. Summary: I witnessed the weekly BOPE on Doyon Rig 15 drilling BPXs DIU 2-44a / Q-11 Well. Doyon 15, 1111/97, Test Time 3 hours, 1 failure Attachment: akhklaee.xls X Unclassified Confidential (Unclassified if doc. removed) Confidential STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: DATE: 11/1/97 Drlg Contractor: .. . Doyon Rig No. 15 PTD # g7-71 Rig Ph.# 659-6510 Operator: BPX Rep.: James Carlile Well Name: 2-44~/Q-11 Rig Rep.: Jim Willingham Casing Size: 7" Set @ 13,744 Location: Sec. 36 T. 12N R. 16E Meridian UM Test: Initial Weekly X Other ,, MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location '~es Standing Order Posted Yes Well Sign OK Drl. Rig OK Hazard Sec. OK FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F ~ 250/5,0O0 P 250/5,000 P 250/5,000 P 250/5,000 P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. I 250/2500 250/5,000 250/5,000 250/5,000 250/5,000 250/5,0OO P 250/5,000 N/A N/A P/F P P F P P P N/A MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 18 250/5,000 P 36 250/5,000 P 2 Functioned Functioned P P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 4@ 2700 3000 1400 minutes 40 sec. minutes 45 sec. OK Remote: OK Psig. Number of Failures: I ,Test Time: 3.0 Hours. Number of valves tested 26 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: Lower 3x6 VBRs failed badty and were changed out to 3.5"rams and tested by the too/pusher. Distribution: orig-Well File c - Oper./Rig c - Database c - Tdp Rpt File c - Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Chuck Scheve FI-021L (Rev. 12/94) Akhklaee ?.o"1/ GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11448 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 1 0/1 4/97 Field: Endicott (Cased Hole) Colored Well Job # Log Description Date Prints RF Sepia LIS Tape MPI 2-14/O-16 97474 USIT 97081 3 1 2-44A/Q-II 97474 USIT 971 006 I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received b~~ ~ TONY KNOWLE$, GOVEBNOFt ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 April 17, 1997 Steve Shultz Senior Drilling Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re; Duck Island 2-44A/Q-11 BP Exploration (Alaska) Inc. Permit No 97-71 Sur. Loc.: 2036'NSL, 2300'WEL, Sec. 36, T12N, R16E, UM Btmhole Loc: 303'NSL, 5205'WEL, Sec. 26, T12N, R16E, UM Dear Mr. Shultz: Enclosed is the approved application for permit to redrill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. 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 drilling 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 Chi BY ORDER OF THE COMMISSION dlf/enclosures cc: Department of Fish & Game. Habitat Section w/o encl. Department of Envinomment Conservation w/o encl. --" STATE OF ALASKA ALASKA ,.4L AND GAS CONSERVATION CON, MISSION PERMIT TO DRILL 2O AAC 25.OO5 [] Drill [] Redrill Ilb' Type of well [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work [] Re-Entry [] DeepenI [] 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. Plan RTE = 56' Endicott Field / Endicott Pool 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 034633 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2036' NSL, 2300' WEL, SEC. 36, T12N, R16E Duck Island At top of productive interval 8. Well Number Number 25100302630-277 233' NSL, 3850' WEL, SEC. 26, T12N, R16E 2-44A/Q-11 Attotal depth 9. Approximate spud date Amount $200,000.00 303' NSL, 5250' WEL, SEC. 26, T12N, R16E 04/18/97 12. Distance to nearest property lineI 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 034634, 30'I No Close Approach 2560 15349' MD / 10239' TVD 16. To be completed for deviated wells i17. Anticipated pressure (see 20 AAC 25.035 (e)(2)} Kick Off Depth 10600' Maximum Hole Angle 47 o Maximum surface 4055 psig, At total depth (TVD) 10000' / 5055 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" 29# L-80 511 3477' 10450' 8805' 13927' 10006' 300 sx Class 'G' 6" 4-1/2" 13# L-80 IBM 1548' 13800' 9980' 15349' 10239' 300 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 M D TVD Structural Conductor Surface Intermediate LPirn°edructiOn R E (~ E ~V ~, ORIGtNAL Perforation depth: measured Alas.ES .0i! .& Gas Cons. Co.m~ true vertical ~ch0ragei 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Chris West, 564-5089 Prepared By Name/Number: Kathy Campoamor, 564-5122 !21. I hereby certify that the foreg~i~tg is true ~z?~l corre~ict to the best of my knowledge // / SteveShultz Title Senior Drilling Engineer Date ¢- ~,, ~"o~mission Use Only ?,,~..,. ~'/' 50- 4:::) 2~_.~'--' ~r___,,," ,~ .,~ '-' 4:~// ¢~/'_-//7 '"/~ 7 for other requirements Conditions of Approval: Samples Required [] Yes~-~N° Mud Log Required [] Yes ,~ No Hydrogen Sulfide Measures "~'Yes [] No Directional Survey Required ~' Yes [] No Required Working B, ressumfp, r. BOPE~ []2M; []3M; ~5M; [] 10M; [] 15M other: b, ordero, q// :Approved By David W, Johnston Commissioner the commission Date Form 10-401 Rev. 12-01-85 Subn I Well Name: 12-44a/Q- 11 Weft Plan Summary Type of Well (Producer or injector): Producer Well Design (Conventional, slimhole, etc.)' SIDETRACK FSL FEL SEC TWP RNG Surface Location: 2036 2300 36 12N 16E Tie in survey Location' 3992 1119 35 12N 16E Target 1 Location: 233 3850 26 12N 16E Bottom Hole Location: 303 5250 26 12N 16E I AFE Number: 1727011 ] I Rig: I DOYON 15 Operating days to drill and complete: 27+6 Formation Markers Well Bore: Formation Tops MD TVDSS EMW RESERVOIR PRESSURE KBE -56 Max surface pressure =4055 psi TOP WEST SAK 6660 TOP SEABEE/AYLYAK 7535 TOP SHALE WALL/TUFFS 8685 KOP 10,600 MD / 8,908 TVDSS TOPHRZ 11,198 9140 BASE HRZ 94O5 TOP PUT RIVER Absent LCU 94O5 ITKILYARIAK 12,146 9405 KEKIKTUK - Top Flow 5 13,928 9975 9.72 2215 - 5055 psi @ 10,000 TVDSS Top Flow 4 14,233 10082 9.72 2215 - 5055 psi @ 10,000 TVDSS Top Flow 3 15,050 10,130 5045 psi Top Flow 2 15,149 10,170 4700 psi Top Flow 1 Top Zone 3A3(P3) TD 15,349 10,239 Logging Program: Logs: 8.5" Hole Tangent and Curve Wireline Logs - TD to HRZ Cased Hole: MWD-GR Only D I I_/LDT/CN L/G R None Casino./Tubinc. Proc.~ram: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg O.D. MD/TVD MD/TVD 8.5 7" 29 L-80 511 3477 10450/8805 13927/10006 6 4.5" 13 L-80 IBM 1548 13800/9980 15349/10239 TBG 4.5" 12.6 13Cr IBM 12,462 38 12500/9826 2-44a/Q-II Drilling Permit .~°R !4 1997 &laska 0il & t~as C0n$.'~ '"~'~'" Anchorage 4/11/97 Cementing Program: Hole Section Liner Size Depth Volume Cement Intermediate 7" Liner from Cement from _. 300 Sxs Class 'G' 10,600 to 13,927 12,927 to 0.5% CFR 2 with 7" x 9-5/8" 13,927 0.7% Halad 344 liner hanger 0.1% HR-5 2 pps Super CBL Production 4.5" Liner from Cement from _+ 300 Sxs Class 'G' 13,800 to 15,348 13,800 to 0.5% CFR 2 with 4.5" x 7" liner 15,348 0.7% Halad 344 hanger 0.1% HR-5 2 pps Super CBL Mud Program' Production Mud Properties: 18.5" and 6" hole section: LSND Depth Density Marsh Yield 10 sec LSR YP pH Fluid Flow (PPG) Viscosity Point 10 Min Loss Rate Gel Milling 10.0 - 70 - 100 25 - 35 8 - 16 8.5 - < 6 600 10.2 11 - 24 9.5 Reservoir 10.2 - 45 - 60 18 - 25 7 - 11 8.5 - <4 250 10.4 9.5 Hazards/Concerns Pore pressure (_+8.6 - 9.4 ppg EMW) based on offset SIBHP. Lost Circulation due to overbalance in Flow sands. Differential sticking with overbalance situation. Excessive Torque to be combated with lubricant additions after testing. WELLHEAD EQUIPMENT Casing Head: Casing Hanger: Tubinghead: X-mas Tree: McEvoy 13 3/8" X 13 5/8", 5M Flange McEvoy Mandrel Hanger McEvoy 13 5/8",5M X 13 5/8", 5M Cameron 6",5M DIRECTIONAL STATS FOR 9 5/8" CASING ON 2.44/R-12 Average Angle: Maximum Angle Maximum Dogleg 45° 47055'' @ 7400' 4.43°/100@4400' 5.43°/100' @ 4100' Centralizers 10 Turbo Clamps from 11,315 to 10,915 Top of Cement 9,922 (Calc. assuming 30% washout) Drilling Hazards DRILLING CLOSE APPROACH WELL SHUT-INS There are no drilling close approach wells after the sidetrack of the original 2-44/R-12 wellbore. PORE PRESSURE / LOST CIRCULATION Production Interval (8.5"): The Kekiktuk Sands reservoir pressure may be slightly higher than normal AND VARIES GREATLY, but the Asset pore pressure (based on nearby 3B BHP of 2500 - 4950 psi at 10,000' TVDss) should range from __. 8.6 to 9.5 ppg EMW. The formation also has the potential for lost circulation (see Geologic Prognosis for faulting details). Lubricant additions (see above) should be utilized if torque and drag become troublesome, and after extensive testing of mud on location. Flex collars should be utilized in the BHA to minimize 2-44a/Q-11 Drilling Permit 4/11/97 troublesome, and after extensive test, j of mud on location. Flex collars should b~ ,~dlized in the BHA to minimize potential differential sticking. Liquid casing and OM seal should be on location to help combat severe lost circulation. NOTE: See the Geologic Prognosis for a detailed description of the expected fault locations and sizes. Review the Pad Data Sheet for trouble highlights throughout MPI history. Well Control: Well control equipment consisting of 5,000 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. Disposal Cuttings Handling' Fluid Handling: CC2A Annular injection is not available at Endicott for this well. Contacts Office Home Pager Drilling Superintendent Adrian Clark 564-4720 345-9066 Sr Drilling Engineer Steve Shultz 564-5405 373-1657 Operations Drilling Engineer: Chris West 564-5089 345-4699 Production Engineer Bob Metzger 564-4613 Geologist: Doug Dickey 564-5474 348-0208 Geophysicist: Jeff Sauve 564-5141 Sperry Sun Directional Gordon Hecht 563-3256 Sperry Sun MWD/LWD Jim Galvin 563-3256 349-2746 Baroid Dave Higbie 248-3511 345-0398 275-1779 275-1789 275-7530 275-1337 2-44a/Q-11 Drilling Permit 4/11/97 Drilling Discussion General The 2-44a/Q-11 well on MPI at Endicott will target the Kekiktuk in the 3B/3C in accordance with the 1997 development plan. We will have to abandon the existing perforation in the 2- 44/R-12 well by pumping cement down tubing, cut production tubing, circulate KWM, pull tubing with the rig, set a whipstock, cut a window, and kick off through the 9-5/8" casing to the new M-40 BHL utilizing the 7" liner design. We will not pull the existing production packer or tailpipe in this well. The liner length will be __ 4138 feet, with the top of the liner hanger back into the 9-5/8" casing. A standard 6 valve slimhole (4.5" x 1" for 7" casing) GLM design will be run for the completion on a 4.5" 13-Chrome tubing design with a X/X/XN nipple profile. Directional Plan: The directional plan for the 2-44a/Q-II well consists of kicking off with a whipstock and conventional BHA's for the Kekiktuk Flow sands. Current plans call for 8°/100' doglegs in this section, but this may be adjusted pending results during the drilling process. After sidetracking, and steering directionally back into the Sands with 43° of inclination, the well will be drilled to __.15,348 MD (10,238' TVD). THE DIRECTIONAL TARGET CAN BE INTERSECTED ANYWHERE WITHIN THE TARGET BOUNDRY. THUS UNNECESSARY AND VERY EXPENSIVE SLIDING SHOULD BE AVOIDED TO KEEP THE WELL EXACTLY ON THE WELLPATH. THERE IS NOT ANY GEOSTEERING APPLICATION FOR THIS WELL. Ensure that any and all tolerance lines are not crossed to avoid policy violations. Please coordinate this through both the Operations Drilling Engineer and the Endicott Drilling Superintendent. There are not any known close approaches which require wells be shut in. Any BHA's indicating less than required BUR should immediately be pulled for a more aggressive assembly. Recommended BHA's All motors should NOT be jetted to account for the proposed flowrate and motor performance. Hole conditions and directional objectives should dictate actual flowrates. As mentioned previously, flex collars should be utilized in the 8.5" hole sections to minimize potential differential sticking. We will be using bent housing motors with either 7/8 for a roller cone or 5/6 rotor/stator configurations for PDC bits IF run. Sperry proposed BHA's are attached, however the actual BHA with motor design, MWD/LWD tool configuration, MWD battery life, bit hydraulics will be discussed at the daily wellsite meeting. Directional Survey Program The survey program for 2-44a/Q-11 calls for use of Sperry's DWD MWD surveys the entire well. Because of Sperry's standard practice of changing the MWD probes after every bit run, an electronic single shot (ESS) will not be needed, and a gyro is not warranted. Close attention to JORPS is required, with the use of checkshots and survey data validation. Bit Program We will kick off the in the Tuffs with a conventional directional BHA and roller cone bit, which should make it to the Kekiktuk. After milling the window, a 8.5" tangent section is planned to the Kekiktuk. The penetration rate will vary due to the variable lithology, but these bits have proven durable enough to drill through most of this interval. However, if there is any indication 2-44a/Q-11 Drilling Permit 4/11/97 of bit failure such as torque st.,,,~es, the bit should be pulled at th~ descretion of the rigsite team. Recommended Jet Sizes Expected Interval Bit Type Flowrate HSI Casing Section Standard Window Mills 500 - 550 gpm 8.5" Kickoff - only GTPS05 550 - 600 gpm 3 x 12 2.9 - 4.8 8.5" Tangent GTPS 09 550 - 600 gpm 3 x 15 2.9 - 4.8 8.5" Final Build GTPS11 550 - 600 gpm Reservoir Section GTPS18 550 - 600 gpm NOTE: Real time rigsite information such as condition of bits previously pulled, hole conditions, drilling fluids, downhole motor constraints (if any) will be instrumental in actual final bit selection. PDC bits will be run in the 8.5" hole section only if Sperry 6-3/4" performance motors are available. Mud Program' We will use LSND on this well. The problems of lubricant additions in a (high weight - high calcium carbonate - high chloride) system severely hampered the drilling process on the both SDI wells Sheardrill was used on. There should not be any additions of any lubricants in this well without extensive testing of the actual fluid on location. A new Gel/Biozan polymer will be used for milling the window. Ditch Magnets should be used and WEIGHED to ensure metal cuttings removal. Rheology control can be maintained using Gel and Biozan polymer. At this time raise the LSR YP to the recommended range using Biozan. Biozan sweeps should be pumped to assist in hole cleaning and to prevent the build up of cuttings beds. Additions of 3#/BBL each of Baranex and Barotrol should be maintained throughout this well. This treatment should result in an HPHT of <14 which is our target. Maintain the pH in the 9-9.5 range using caustic soda. If torque problems arise, a treatment of 1- 2% Lubetex should be used. If the torque persists, the ERD lubricant mix should be evaluated. The LSND mud will be taken to TD on this well. Maintain the weight at the density required in the intermediate section. The Barotrol and Baranex treatments should be maintained at 3#/bbl. The APl filtrate should be reduced to the 4 cc range with PAC and starch. This will reduce the chances of differential sticking and reduce filtration invasion. Tripping Practices / Stuck Pipe / Hole Cleaning Tripping in the 8.5" hole interval should be undertaken with caution due to swabbing possibilities with high viscosity fluids. The bottom hole pressure varies from 2500 psi to 4950 psi (8.6 to 9.5 ppg ). It is recommended that mud weights be maintained in the 10.2 to 10.4 ppg range to control the hydrocarbon intervals, maintain shale stability and minimize the possibility of differential sticking. Faulted intervals may require additions of LCM prior to tripping to insure that the hole remains full at all times. Keep the pipe moving and have an ample supply of lost circulation materials on hand. Baroid recommends utilization of Iow viscosity sweeps to assist with hole cleaning and to minimize the formation of cuttings beds on the Iow side of the hole. No potential hazardous levels of H2S are anticipated in the 2-44a/Q-11 well. There have been H2S reading on offset MPI wells of over 1000 ppm. Ensure rig gas detectors are calibrated prior to N/D tree and/or circulating to kill the well. 2-44a/Q-11 Drilling Permit 4/11/97 _ogging Program: _OgS: MWD/GR / RES / DEN / NEU 8.5" Hole Tangent and Curve 6" Hole Reservoir MWD / G R / RES Wireline Logs None planned Cased Hole: No Sample catchers and a wellsite Geologist are planned to be used while drilling reservoir. Casing and Cementing This sidetrack well will require a single 7" 29# L-80 liner to be run across the entire interval. This will be hung off in the 9-5/8" casing at 10,450 feet. Make sure we have 5000 feet of 5" "S" drill pipe to allow for the maximum overpull. Ensure that prior to running liner that the hole is in good condition and that the mud has been conditioned to run casing. Before POH to run liner spot lubricant across the open hole section. If this is considered essential to getting the pipe to bottom ensure that adequate lubricant testing has been performed prior to doing this. Aisc, consideration must be given to a hole opener trip prior to running liner if hole conditions suggest that there may be problems running pipe. This liner will use Hydrill 511 connections to allow rotation at much higher torque and reciprocation than any other connections. Special equipment will be required for this including XO for safety valve and having the liner hanger cut with a 511 connection on bottom. (Do not crossover from buttress as this would be a weak link in the string). The liner should be filled every 5 joints, and circulated prior to going into open hole. Any problem intervals identified while drilling, such as ledges in the Tuffs, will require special care while running casing through. The liner will require 2 straight blade centralizers on every joint to the 200 feet above the top of the Kekituk at _. 13,147', and then one straight blade centralizer on every other joint to the window. If the liner starts to packoff in the open hole, establish circulation and try to wash through. Do not continue to run casing without circulation. If necessary, we will pull casing and make a wiper trip prior to running the liner. The liner running procedure in the detail section should be reviewed. The cementing program is designed place cement 1000 feet above the top of the Kekiktuk formation. The approximate volume will be 300 sacks of Class 'G' with additives as speficied in the casing detail section. Cementing operations at Endicott are continue to be critical with the advancement of both the waterflood and gas fronts. Close attention to detail for this part of the well is critical for the economical success of our drilling program. DPC Perforating This sidetrack well will require a DPC perforating across the intervals picked from LWD logs. 2-44a/Q-11 Drilling Permit 4/11/97 SUMMARY PROCEDURE COMMENTS 1. The 9-5/8" x 4-1/2" production packer is a TIW permanent packer with a tubing seal assembly above. The 7" x 3-1/2" production packer is a TIW permanent packer with a tubing seal assembly above. Neither packer will be recovered. 2. This well will be sidetracked at app. 10,600 feet. PRE-RIG OPERATIONS 1. RU wireline, Pull the WL SSSV. Drift and dummy off gas lift mandrels. 2. Establish bullhead rate down 5.5" tubing and into perforations. 3. Pump 100 sx of class G cement and circulate down the tubing. Displace to a 11,500' MD. Squeeze cement into perforations up to 1500 psi. 4. RU wireline and cut tubing with chemical cutter above 5" x 9-5/8" packer at 10,940' MD. 5. Circulate the 5" tubing with 1.5 volumes of 9.5 ppg brine or milling fluid. Check that the well is dead. Freeze protect the top 200' with diesel. Set BPV. Note: Maintain contact with Drilling. If rig move is delayed to more than four days after the well kill, a deeper freeze protect will need to be done by the PE's. 6. Dig out the cellar and level the pad. Inspect the wellhead and tree. Replace the 9-5/8" packoff and function test the LDS's. RIG OPERATIONS (SUMMARY) , , . o , , , 10. 11. 14. 15. 16. 17. Mobilize Doyon 15. Review Endicott Simultaneous Operations Plan concerning rig moves. Check that the well is dead. If not circ well w/brine or milling fluid until dead. ND the tree, and NU the BOPE. Test the BOPE and pull BPV. (1/2 day) Screw into the landing joint. Pull and LD the tubing. (1 day) Run and set 9-5/8" wireline bridge plug at _. 10,600 MD with CCL to set BP 3 feet below collar. (1/2 day). P/U 9-5/8" whipstock and milling BHA and TIH to cut window from 10,600 - 10,616 MD. (2 days) POOH w/mills. (1/2 day) Pick up Sperry 6.75" directional BHA to turn and build @ 8°/100 feet to 73° at app 11,017' MD. Drill ahead as specified by the rig supervisor to ICP at 13,900. POOH. (12 days) Run a 7" solid liner from 10,450 to 13,900' MD, cement as per plan. (2 days). Pick up Sperry 6." bit and directional directional BHA to TD at appx 15,348 MD. POOH. (3 days) If there are hole problems, run a HO over whole interval and spot lubricant in OH section. POOH. Run a 4.5" solid liner from 13,750' to 15,348 MD. (2 days). Make a clean out trip with bit and scraper and displace with KW Brine. RIH w/7" x 4-1/2" packer, 4-1/2" Chrome tubing, and 6 GLM to expected setting depth at 10,800 MD. Drift packer, tubing and all jewlery before running. (1 day) Pump Corrosion inhibitor. Set the 7" packer. Test the tubing to 3500 psi. Test the packer and IA to 3500 psi. (1/2 day) Set the BPV. ND the BOPE, and NU the tree. Shear the RP valve and freeze protect the well. (1/2 day). 18. Turn the well over to Production. 2-44a/Q-11 Drilling Permit 4/11/97 j. BF. ELEV = ~ Abandoned 2-44/R-12 Wellbore 9-5/8' Csg II ~ 5' Concentric [L.~ --~- '/'liner Exact location of jewelry to be determined from open-hole logs. - Set production packer @ max. 55* to 60° to facilitate sr~ckline operations. - 100' two nipple tailpipe assembly. Top of Cement 1000' MD above Kekiktuk. DATE REV. BY COMMENTS .. TREE: 4-1/16', 50(% ~.,, CIW Wellhead: 13-5/8', 5000 psi, CIW SSSV LANDING NIPPLE ( 3.813' MIN. ID) W/SSSV MIN I.D. is 2.00' Surf Csg ! 2497' Uner Top Packer & Hanger '~ Sidetracked 2-44NQ-11 Wellborn ~ 4-1/2' Cr13'rbg Tubing Drift = 3.833' Minimum Drift thru stdng = 3.725' GAS LIFT MANDRELS 1-1/2' & Slimhole 1' pockets NO. MD-BKB 'rVD-SS ~6 3500' #5 5250' #4 6300' #3 7000' #2 7700' #1 8400' 4-1/2' 'X' NIPPLE ( 3.813' ID) Production Packer 4-1/2' L-80 Tailpipe 4-1/2~ 'X' NIPPLE ( 3.8-13' IDi- 4-1/2' "XN' NIPPLE (3.725' ID) solid liner ..~.~ 4-1/2' Solid Liner High Angle from Fy.to Fiii ENDICO'i-r WELL 2-44A/Q-11 APl NO: BP EXPLORATION,-INC. APR '14 1997 A_ la~_~'.Oil & Gas Co~s. C0~ni~iss,~;' ~ch0rage 2-44a/Q-11 Vertical Section RKB Wp2 293.07° 56.00' MD Inc. Azi. 14000.00 80.57 272.90 14100.00 80.57 272.90 14200.00 80.57 272.90 14233.13 80.57 272.90 14300.00 80.57 272.90 14400.00 80.57 272.90 14500.00 80.57 272.90 14600.00 80.57 272.90 14700.00 80.57 272.90 14 .00 80.57 272.90 14900.00 80.57 272.90 15000.00 80.57 272.90 15100.00 80.57 272.90 15148.66 80.57 272.90 15200.00 80.57 272.90 15300.00 80.57 272.90 15348.66 80.57 272.90 TVDss TVDrkb Rect. Coordinates Grid Coordinates Northing Easting Easting Northing 9961.80 10017.80 2274.85n 6902.38w 252079.17 5984880.90 9978.19 10034.19 2279.84n 7000.90w 251980.87 5984889.09 9994.57 10050.57 2284.84n 7099.42w 251882.56 5984897.29 10000.00 10056.00 2286.50n 7132.06w 251850.00 5984900.00 10010.96 10066.96 2289.84n 7197.94w 251784.26 5984905.48 10027.34 10083.34 2294.84n 7296.47w 251685.96 5984913.67 10043.72 10099.72 2299.83n 7394.99w 251587.65 5984921.86 10060.11 10116.11 2304.83n 7493.51w 251489.35 5984930.05 10076.49 10132.49 2309.83n 7592,03w 251391.05 5984938.25 10092.88 10148.88 2314.82n 7690.55w 251292.74 5984946.44 10109.26 10165.26 2319.82n 7789.07w 251194.44 5984954.63 10125.64 10181.64 2324.82n 7887.59w 251096.14 5984962.82 10142.03 10198.03 2329.81 n 7986.11w 250997.83 5984971.01 10150.00 10206.00 2332.25n 8034.05w 250950.00 5984975.00 10158.41 10214.41 2334.81n 8084.63w 250899.53 5984979.21 10174.80 10230.80 2339.81n 8183.16w 250801.22 5984987.40 10182.77 10238.77 2342.24n 8231.10w 250753.39 5984991.38 DLS deg/100ft 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 Vertical Section 7241.79 7334.39 7426.99 7457.67 7519.59 7612.19 7704.79 7797.39 7889.99 7982.59 8075.19 8167.79 8260.39 83O5.45 8352.99 8445.59 8490.65 Comment TFU 4: 14233 MD Target 2/TFU 2 · 15149 MD TD/7" Liner: 15349 MD 4/4/97 10:16 AM Page 2 of 2 STATE OF ALASKA " ALASKA OIL AND GAS CONSERVATION COMMISSION 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 Plug Back for Sidetrack 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2036' SNL, 2300' WEL, SEC. 36, T12N, R16E At top of productive interval 1050' SNL, 2008' WEL, SEC. 35, T12N, R16E At effective depth 916' SNL, 2479' WEL, SEC. 35, T12N, R16E At total depth 903' SNL, 2525' WEL, SEC. 35, T12N, R16E 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) KBE = 55.10' 7. Unit or Property Name Duck Island Unit/Endicott 8. Well Number 2-44/R-12 9. Permit Number 87-119 10. APl Number 50-029-21767 11. Field and Pool Endicott Field / Endicott Pool 12. Present well condition summary Total depth: measured 12869 feet true vertical 10698 BKB feet Effective depth: measured 12788 feet true vertical 10633 BKB feet Plugs (measured) Junk (measured) Top of 452' of Packer assembly and perf guns at 12034' Casing Length Structural Conductor 92' Surface 2458' Intermediate 11277' Production 1652' Liner 1812' Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Size Cemented MD TVD BKB BKB 30" Driven 131' 131' 13-3/8" 4185 c.f. Permafrost 2497' 2496' 9-5/8" 575 c.f. Class 'G' 11316' 9489' 5" 189 c.f. Class 'G' 11033'-12685' 9278'-10552' 7" 964 c.f. Class 'G' 11057'-12869' 9293'-10698' DUPLICATE 11942'-11967', 12116'-12132', 12188'-12146', 12176'-12186', 12276'-12286', 12361'-12382', 12393'-12399', 12404'-12424', 12428'-12436', 12448'-12468', 12482'-12496', 12508'-12546' (Subsea) 9913'-9933', 10047'-10059', 10064'-10070', 10093'-10101', 10171'-10179', 10238'-10255', 10264'-10269', 10273'-10289', 10292'-10298', 10308'-10324', 10335'-10346', 10356'-1Q386'-~ 5-1/2" 17# L-80 TDS Tubing to 10938' ~; ~, Packers and SSSV (type and measured depth) 9-5/8" Packer at 10940'; 5-1/2" SSSV at 1578' 13. Attachments [] Description summary of proposal [] Detailed operations program [] BOP sketch ~.. ~te ~or~~~~ -- 15.~at~l~ions as:-- ~~ April 16, 1997 [] Od [] Gas [] Suspended ..... Service Water Injection rqame o~ approver ua~e approveo ~ 17.1 hereby certify that the ~going is ~' and ~orrect to the best of my knowledge Signed St~Sh~ ..~~-..~',j ~~ Title Senior Drilling Engineer Date l/,/"/"/~ ~ '- % Commission Use Only / IApproval Conditions of Approval: Notify Commis~e_nI ~ti~witness Plug integrity~__._ BDI~ est ~ ~:;~--4., ocation clearance Approved by order of the Commission ~ ~. "~ _~'~ Commissioner Form 10-403 Rev. 06/15/88 ~_~ Date Submi( In TCip~cate 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. Sperry-Sun Drilling Services LIS Scan Utility Wed Dec 03 14:47:46 1997 Reel Header Service name ............. LISTPE Date ..................... 97/12/03 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 97/12/03 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER ENDICOTT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MM-70280 E. CRIBBS J. CARLILE MICIilOi::ILMED - 0 / 2-44A/Q-ii 500292176701 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 03-DEC-97 MWD RUN 2 AK-MM-70280 G. GRIFFIN J. CARLI LE MWD RUN 3 AK-MM-70280 G. GRIFFIN E. VAUGHN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 AK-MM-70280 G. GRIFFIN E. VAUGHN MWD RUN 5 AK-MM-70280 G. GRIFFIN E. VAUGHN MWD RUN 6 AK-MM-70280 G. GRIFFIN E. VAUGHN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 7 AK-MM-70280 M. WORDEN E. VAUGHN MWD RUN 8 AK-MM-70280 M. WORDEN E. VAUGHN MWD RUN 9 AK-PIM-70280 M. HANIK J. CARLILE JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 10 AK-MM-70280 M. HANIK J. CARLI LE MWD RUN 11 AK-MM-70280 M. HANIK J. CARLI LE MWD RUN 11 AK-MM-70280 M. HANIK J. CARLI LE 36 12N 16E 2036 2300 .00 55.20 14.50 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 9.625 10510.0 3RD STRING 8.500 7.000 13744.0 PRODUCTION STRING 6.000 14905.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 THROUGH 7 ARE DIRECTIONAL WITH NATURAL GAMMA RAY PROBE (NGP). 3. MWD RUN 8 IS DIRECTIONAL, DUAL GAMMA RAY (DGR), ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4),COMPENSATED NEUTRON POROSITY (CNP), AND AND STABILIZED LITHO-DENSITY (SLD). NGP CHANGES TO DGR AT 13589'MD, 9901'TVD 4. MWD RUS 9 THROUGH 11 ARE DIRECTIONAL, DGR, AND EWR4. 5. EWR4 DATA IN THE INTERVAL 14300'MD, 10027'TVD TO TD IS REPROCESSED OWING TO ANTENNA DAMAGE ON ALL RECEIVERS. THE POINT AT WHICH EACH RECEIVER BECAME DAMAGED IS UNKNOWN: ABOVE 14300'MD PROCESSING APPEARS TO OVERCORRECT RESIS- TIVITY VALUES, AND BELOW THAT POINT APPEARS TO YIELD REASONABLE VALUES. A MAD PASS WAS PERFORMED OVER THE INTERVAL 13730'MD TO 14453'MD(RESISTIVITY DEPTHS) WHILE TRIPPING IN THE HOLE AFTER MWD RUN 11. ALL MAD DATA WAS RE- PROCESSED, AND SHOULD BE CONSIDERED THE MOST RELIABLE DATA INASMUCH AS MOST DAMAGE LIKELY OCCURRED PRIOR TO THE END OF DRILLING. 6. DEPTH SHIFT/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN B VOORHEES OF BP EXPLORATION (ALASKA), INC. AND A TURKER OF SPERRY- SUN DRILLING SERVICES ON 11/24/97. 7. THIS WELL REACHED A TOTAL DEPTH (TD) OF 14905'MD, 10256'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SPSF = SMOOTHED COMPENSATED NEUTRON POROSITY(SANDSTONE MATRIX FIXED HOLE SIZE) SBDC = SMOOTHE BULK DENSITY-COMPENSATED. SCOR = SMOOTHED STANDOFF CORRECTION. SNPE = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. ENVIRONMENTAL PARAMETERS USED FOR PROCESSING NUCLEAR LOGS: HOLE SIZE: 8.5" MUD FILTRATE SALINITY: 2300PPM CHLORIDES MUD WEIGHT: 10.2 PPG FORMATION WATER SALINITY: 16000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name..~. Version Number ........... 1.0.0 Date of Generation ....... 97/12/03 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR ROP FCNT NCNT NPHI FET RPD RPM RPS RPX -PEF DRHO RHOB $ .5000 START DEPTH 10480.0 10512.0 13515.5 13515.5 13515.5 13541 0 13541 0 13541 0 13541 0 13541 0 13551 0 13551 0 13551 0 STOP DEPTH 14858.0 14905.5 13632.5 13632.5 13632.5 14865.0 14864.5 14864.5 14864.5 14864.5 13667.0 13667.0 13667.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD $ REMARKS: BIT RUN NO MERGE TOP MERGE BASE 1 10512.0 11244.0 2 11244.0 11694.0 3 11694.0 12120.0 4 12120.0 12366.0 5 12366.0 12750.0 6 12750.0 13190.0 7 13190.0 13654.0 8 13654.0 13744.0 9 13744.0 13810.0 10 13810.0 13890.0 11 13890.0 14905.5 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD AAPI 4 1 68 ROP MWD FT/H 4 1 68 RPX MWD OH3{M 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OH>~ 4 1 68 NPHI MWD P.U. 4 1 68 FET MWD HOUR 4 1 68 FCNT MWD CNTS 4 1 68 NCNT MWD CNTS 4 1 68 RHOB MWD G/CC 4 1 68 DRHO MWD G/CC 4 1 68 PEF MWD BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Min Max Mean DEPT 10480 14905.5 12692.8 GR 13.386 293.375 73.4516 ROP 1.9373 2214.84 25.2001 Nsam 8852 8757 8788 First Reading 10480 10480 10512 Last Reading 14905.5 14858 14905.5 RPX 1.0515 2000 21.5138 2498 RPS 1.6813 2000 24.1281 2498 RPM 3.6633 2000 36.9037 2498 RPD 4.4513 2000 38.304 2498 NPHI 6.2572 34.7783 17.5521 235 FET 0.9814 29.9993 6.82546 2479 FCNT 622.369 1751.55 1069.25 235 NCNT 2760.06 4802.34 3679.19 235 RHOB 2.3824 2.8921 2.59333 233 DRHO 0.0364 0.7116 0.217085 233 PEF 2.9134 4.9606 3.77014 233 13541 13541 13541 13541 13515.5 13541 13515.5 13515.5 13551 13551 13551 14864.5 14864.5 14864.5 14864.5 13632.5 14865 13632.5 13632.5 13667 13667 13667 First Reading For Entire File .......... 10480 Last Reading For Entire File ........... 14905.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/03 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/03 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 13719.5 FET 13726.5 RPD 13726.5 RPM 13726.5 RPS 13726.5 RPX 13726.5 RAT 13768.0 $ MERGED DATA SOURCE PBU TOOL CODE STOP DEPTH 14446.0 14452.5 14452.5 14452.5 14452.5 14452.5 14493.5 MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE MWD 11 REMARKS: MERGED MAD PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 13719.5 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 RAT MAD FT/H 4 1 68 GR MAD AAPI 4 1 68 RPX MAD OHMM 4 1 68 RPS MAD OHM~ 4 1 68 RPM MAD OHMM 4 1 68 RPD MAD OHMS4 4 1 68 FET MAD HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 14493.5 Name Min Max Mean Nsam DEPT 13719.5 14493.5 14106.5 1549 RAT 24.1692 218.233 65.8129 1452 GR 14.6403 149.59 68.9018 1454 RPX 0.9028 2000 26.1557 1453 RPS 1.2092 2000 28.1934 1453 RPM 2.612 2000 38.2173 1453 RPD 5.7859 2000 63.1913 1453 FET 55.1309 149.349 80.9649 1453 First Reading 13719.5 13768 13719.5 13726.5 13726.5 13726.5 13726.5 13726.5 Last Reading 14493.5 14493.5 14446 14452.5 14452.5 14452.5 14452.5 14452.5 First Reading For Entire File .......... 13719.5 Last Reading For Entire File ........... 14493.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/03 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 'Physical EOF .File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/03 Maximum Physical Record..65535 File Type ........... ~ .... LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10480.0 ROP 10512.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 5.03 DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11179.5 11243.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS · MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL 11-OCT-97 ISC VERSION 5.07 PCD 2.00/PCG 6.74/SP4 MEMORY 11244.0 10512.0 11244.0 41.7 52.5 TOOL NUMBER PCG 47 8.500 8.5 LSND-HT 10.20 52.0 9.2 2200 5.2 .000 .000 .000 .000 56.1 MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 AAPI 4 1 68 4 2 ROP MWD 1 FT/H 4 1 68 8 3 First Name ~Min Max Mean Nsam Reading DEPT 10480 11243.5 10861.8 1528 10480 GR 42.063 293.375 125.555 1400 10480 ROP 3.4564 1550.86 40.2304 1464 10512 Last Reading 11243.5 11179.5 11243.5 First Reading For Entire File .......... 10480 Last Reading For Entire File ........... 11243.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/03 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/03 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11180.0 ROP 11244.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 5.03 DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11630.0 11695.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : 13-OCT-97 ISC VERSION 5.07 PCD 2.00/PCG 6.74/SP4 MEMORY 11694.0 11244.0 11694.0 43.0 73.7 TOOL NUMBER PCG 50 8.500 8.5 LSND-HT 10.20 57.0 9.1 2200 3.6 .000 .000 .000 .000 61.1 .6 REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 AAPI 4 1 68 4 2 ROP MWD 2 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 11180 11695 11437.5 1031 11180 GR 19.5549 257.232 94.4882 901 11180 ROP 3.9351 473.73 23.2913 896 11244 Last Reading 11695 11630 11695 First Reading For Entire File .......... 11180 Last Reading For Entire File ........... 11695 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/03 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/03 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FI LE HEADER FILE NUMBER: RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11630.5 ROP 11695.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 5.03 DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: M3%XIMUMANGLE: STOP DEPTH 12054.5 12119.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: · MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STAaNDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type .................. 0 16-OCT-97 ISC VERSION.5.07 PCD 2.00/PCG 6.74/SP4 MEMORY 12120.0 11694.0 12120.0 79.5 85.8 TOOL NUMBER PCG 4 7 8.500 8.5 LSND-HT 10.20 59.0 9.2 2000 3.8 .000 .000 .000 .000 65.6 .6 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 AAPI 4 1 68 4 2 ROP MWD 3 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 11630.5 12119.5 11875 979 11630.5 GR 17.6134 107.277 48.0058 849 11630.5 ROP 2.7113 183.516 12.3074 849 11695.5 Last Reading 12119.5 12054.5 12119.5 First Reading For Entire File .......... 11630.5 Last Reading For Entire File ........... 12119.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/03 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/03 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12058.0 ROP 12120.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 5.03 DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 12300.5 12365.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined 18-OCT-97 ISC VERSION 5.07 PCD 2.00/PCG 6.74/SP4 MEMORY 12366.0 12120.0 12366.0 81.7 85.1 TOOL NUMBER PCG 50 8.500 8.5 LSND-HT 10.20 60.0 9.3 2000 3.6 .000 .000 .000 .000 65.6 .6 Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT~ 4 1 68 0 1 GR MWD 4 AAPI 4 1 68 4 2 ROP MWD 4 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 12058 12365.5 12211.8 616 12058 GR 16.1954 63.9907 32.5331 486 12058 ROP 3.6834 648.047 17.2947 492 12120 Last Reading 12365.5 12300.5 12365.5 First Reading For Entire File .......... 12058 Last Reading For Entire File ........... 12365.5 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/03 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/03 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE GR ROP $ LOG HEADER DATA DATE LOGGED: START DEPTH STOP DEPTH 12301.0 12684.0 12365.5 12749.5 20-0CT-97 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 5.03 DATA TYPE (MEMORY OR REAL-TIME): 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 NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 ISC VERSION 5.07 PCD 2.00/PCG 6.74/SP4 MEMORY 12750.0 12366.0 12750.0 79.9 81.4 TOOL NUMBER PCG 47 8.500 8.5 LSND-HT 10.20 65.0 9.3 2000 3.2 .000 .000 .000 .000 65.6 .6 Name Service Order Units Size Nsam Rep Code Offset Channel .DEPT FT 4 1 68 0 1 GR MWD 5 AAPI 4 1 68 ROP MWD 5 FT/H 4 1 68 4 2 8 3 Name Min Max Mean Nsam DEPT 12301 12749.5 12525.2 898 GR 20.5982 104.107 46.7332 767 ROP 3.8844 551.992 16.2972 769 First Last Reading Reading 12301 12749.5 12301 12684 12365.5 12749.5 First Reading For Entire File .......... 12301 Last Reading For Entire File ........... 12749.5 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/03 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF File Header Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/03 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12686.5 13126.5 ROP 12751.0 13190.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNH©LE SOFTWARE VERSION: 5.03 DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): 23-OCT-97 ISC VERSION 5.07 PCD 2.00/PCG 6.74/SP4 MEMORY 13190.0 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 NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY {LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 12750.0 13190.0 79.6 81.4 TOOL NUMBER NGP SPC 317 8.500 8.5 LSND-HT 10.20 59.0 9.1 2000 3.4 .000 .000 .000 .000 72.8 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 6 AAPI 4 1 68 4 2 ROP MWD 6 FT/H 4 1 68 8 3 First Last Name Min Max Mean Nsam DEPT 12686.5 13190 12938.2 1008 GR 39.9285 129.41 73.6791 881 ROP 4.4057 2214.84 27.7792 879 Reading Reading 12686.5 13190 12686.5 13126.5 12751 13190 First Reading For Entire File .......... 12686.5 Last Reading For Entire File ........... 13190 File Trailer Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/03 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.009 Physical EOF File Header Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/03 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.008 Comment Record FILE HEADER FILE NUMBER: 9 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 13127.0 13589.0 ROP 13191.5 13654.0 $ LOG HEADER DATA DATE LOGGED: 25-OCT-97 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 5.03 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 13654.0 TOP LOG INTERVAL (FT): 13190.0 BOTTOM LOG INTERVAL (FT): 13654.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 76.4 MAXIMUM ANGLE: 85.0 ISC VERSION 5.07 PCD 2.00/PCG 6.74/SP4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OH/~4) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 TOOL NUMBER PCG 47 8.500 8.5 LSND-HT 10.20 65.0 9.1 2000 3.4 .000 .000 .000 .000 63.3 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 7 AAPI 4 1 68 4 2 ROp MWD 7 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 13127 13654 13390.5 1055 13127 GR 22.7048 198.409 58.1709 925 13127 ROP 2.5868 615.234 20.3081 926 13191.5 Last Reading 13654 13589 13654 First Reading For Entire File .......... 13127 Last Reading For Entire File ........... 13654 File Trailer Service name ........ - ..... STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/03 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.010 Physical EOF File Header Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/03 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.009 Con~nent Record FILE HEADER FILE NUMBER:. 10 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FCNT 13515.5 NCNT 13515.5 NPHI 13515.5 FET '13541.0 RPD 13541.0 RPM 13541.0 RPS 13541.0 RPX 13541.0 PEF 13550.5 DRHO 13551.0 RHOB 13551.0 GR 13589.5 ROP 13654.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 5.03 DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : STOP DEPTH 13632.5 13632.5 13632.5 13658.5 13658.5 13658.5 13658.5 13658.5 13667.0 13667.0 13667.0 13678.0 13743.5 27-OCT-97 ISC VERSION 5.07 PCD 2.00/PCG 6.74/SP4 MEMORY 13744.0 13654.0 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 DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. CNP COMPENSATED NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 13744.0 82.2 82.1 TOOL NUMBER P0854CRDGP6 P0854CRDGP6 P0854CRDGP6 P0854CRDGP6 8.500 8.5 LSND-HT 10.20 65.0 9.2 2000 3.2 1.100 .410 .750 1.920 83.9 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 8 AAPI 4 1 68 4 2 RPX MWD 8 OHMM 4 1 68 8 3 RPS MWD 8 OHMM 4 1 68 12 4 .RPM MWD 8 OHMM 4 1 68 16 5 RPD MWD 8 OHMM 4 1 68 NPHI MWD 8 P.U. 4 1 68 ROP MWD 8 FT/H 4 1 68 FET MWD 8 HOUR 4 1 68 RHOB MWD 8 G/CC 4 1 68 DRHO MWD 8 G/CC 4 1 68 PEF MWD 8 BARN 4 1 68 FCNT MWD 8 CNTS 4 1 68 NCNT MWD 8 CNTS 4 1 68 20 24 28 32 36 40 44 48 52 6 7 8 9 10 11 12 13 14 Name Min Max Mean Nsam DEPT 13515.5 13743.5 13629.5 457 GR 28.382 76.9218 49.2643 178 RPX 7.0548 30.1248 16.8852 236 RPS 9.0084 31.8116 21.6464 236 RPM 10.1561 37.5254 23.8626 236 RPD 11.8091 42.6749 26.8114 236 NPHI 6.2572 34.7783 17.5521 235 ROP 3.6323 371.953 29.4131 179 FET 11.6391 29.9993 27.5499 236 RHOB 2.3824 2.8921 2.59333 233 DRHO 0.0364 0.7116 0.217085 233 PEF 2.9134 4.9606 3.76785 234 FCNT 622.369 1751.55 1069.25 235 NCNT 2760.06 4802.34 3679.19 235 First Reading 13515.5 13589.5 13541 13541 13541 13541 13515.5 13654.5 13541 13551 13551 13550.5 13515.5 13515.5 Last Reading 13743.5 13678 13658.5 13658.5 13658.5 13658.5 13632.5 13743.5 13658.5 13667 13667 13667 13632.5 13632.5 First Reading For Entire File .......... 13515.5 Last Reading For Entire File ........... 13743.5 File Trailer Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/03 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.011 Physical EOF File Header Service name ............. STSLIB.011 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/03 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.010 Comment Record FILE HEADER FILE NUMBER: .RAW MWD 11 Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 13678.5 13770.0 RPD 13734.0 13777.0 RPM 13734.0 13777.0 RPS 13734.0 13777.0 RPX 13734.0 13777.0 FET 13744.0 13777.0 ROP 13744.0 13810.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE 5.03 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): 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 DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): 01-NOV-97 ISC VERSION 5.07 PCD 2.00/PCG 6.74/SP4 MEMORY 13810.0 13744.0 13810.0 81.9 81.9 TOOL NUMBER P0867SP4 P0867SP4 6.000 6.0 LSND-HT 10.20 54.0 9.2 2000 2.5 .85O .480 · 650 1.320 67.8 .6 REMARKS: $ Data Format Specification Record Data Record Type .... ~ ............. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 GR MWD 9 AAPI 4 1 68 RPX MWD 9 OHMM 4 1 68 RPS MWD 9 OHMM 4 1 68 RPM MWD 9 OHMM 4 1 68 RPD MWD 9 OHMM 4 1 68 ROP MWD 9 FT/H 4 1 68 FET MWD 9 HOUR 4 1 68 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean Nsam DEPT 13678.5 13810.5 13744.5 265 GR 16.2366 75.8499 36.6477 184 RPX 1.0515 2000 86.5891 87 RPS 1.6813 2000 90.914 87 RPM 3.8684 2000 415.609 87 RPD 9.5718 2000 443.378 87 ROP 2.5828 311.719 13.776 134 FET 7.6846 8.9976 8.27519 67 First Reading 13678.5 13678.5 13734 13734 13734 13734 13744 13744 Last Reading 13810.5 13770 13777 13777 13777 13777 13810.5 13777 First Reading For Entire File .......... 13678.5 Last Reading For Entire File ........... 13810.5 File Trailer Service name ............. STSLIB.011 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/03 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.012 Physical EOF File Header Service name ............. STSLIB.012 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/03 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.011 Comment Record FILE HEADER FILE NUMBER: 12 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 13771.0 13849.5 FET 13778.0 13856.5 RPD 13778.0 13856.5 RPM 13778.0 13856.5 RPS 13778.0 13856.5 RPX 13778.0 13856.5 ROP 13812.5 13890.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE 5.03 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): 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 DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: 03-NOV-97 ISC VERSION 5.07 PCD 2.00/PCG 6.74/SP4 MF24ORY 13890.0 13810.0 13890.0 78.8 79.2 TOOL NUMBER P0867SP4 P0867SP4 6.000 6.0 LSND-HT 10.20 62.0 8.9 2000 47.0 .830 .450 67.8 MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .600 1.300 .6 Name Service Order Units Size Nsam DEPT FT 4 1 GR MWD 10 AAPI 4 1 RPX MWD 10 OHMM 4 1 RPS MWD 10 OHMM 4 1 RPM MWD 10 OHMM 4 1 RPD MWD 10 OHMM 4 1 ROP MWD 10 FT/H 4 1 FET MWD 10 HOUR 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 Name Min Max Mean DEPT 13771 13890 13830.5 GR 49.4019 92.0042 67.3118 RPX 12.6823 33.7452 21.1212 RPS 13.555 32.272 21.9985 RPM 13.1801 29.533 20.72 RPD 14.7488 32.2574 23.7629 ROP 1.9373 56.7993 6.94458 FET 6.7735 29.699 16.7322 First Last Nsam Reading Reading 239 13771 13890 158 13771 13849.5 158 13778 13856.5 158 13778 13856.5 158 13778 13856.5 158 13778 13856.5 156 13812.5 13890 158 13778 13856.5 First Reading For Entire File .......... 13771 Last Reading For Entire File ........... 13890 File Trailer Service name ............. STSLIB.012 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/03 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.013 Physical EOF File Header Service name ............. STSLIB.013 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/03 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.012 Cormment Record FILE HEADER FILE NUMBER: 13 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 11 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FET 13846.0 RPD 13846.0 RPM 13846.0 RPS 13846.0 RPX 13846.0 GR 13850.0 ROP 13890.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 5.03 DATA TYPE (MEMORY OR REAL-TIME): 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 DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : STOP DEPTH 14864.5 14864.5 14864.5 14864.5 14864.5 14858.0 14905.5 06-NOV-97 ISC VERSION 5.07 PCD 2.00/PCG 6.74/SP4 MEMORY 14905.5 13890.0 14905.5 58.4 80.7 TOOL NUMBER P0867SP4 P0867SP4 6.000 6.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMS)AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 LSND-HT 10.20 60.0 9.0 1800 2.8 1.150 .456 .650 1.300 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 11 FT/H 4 1 68 4 2 GR MWD 11 AAPI 4 1 68 8 3 RPX MWD 11 OHM~ 4 1 68 12 4 RPS MWD 11 OHN~4 4 1 68 16 5 RPM MWD 11 OHMM 4 1 68 20 6 RPD MWD 11 OHMM 4 1 68 24 7 FET MWD 11 HOUR 4 1 68 28 8 75.0 First Name Min Max Mean Nsam Reading DEPT 13846 14905.5 14375.8 2120 13846 RO? 2.2448 145.109 28.845 2031 13890.5 GR 13.386 155.556 71.6892 2017 13850 RPX 2.6533 89.7928 19.2303 2038 13846 R?S 2.927 78.6177 21.638 2038 13846 RPM 3.6633 110.266 23.265 2038 13846 RPD 4.4513 95.5398 23.235 2038 13846 FET 0.9814 26.4837 3.80992 2038 13846 Last Reading 14905.5 14905.5 14858 14864.5 14864.5 14864.5 14864.5 14864.5 First Reading For Entire File .......... 13846 Last Reading For Entire File ........... 14905.5 File Trailer Service name ............. STSLIB.013 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/03 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.014 Physical EOF File Header Service name ............. STSLIB.014 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/03 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.013 Comment Record FILE HEADER FILE NUMBER: 14 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 11 MAD PASS NUMBER: FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 13719.5 14446.0 FET 13726.5 14452.5 RPD 13726.5 14452.5 RPM 13726.5 14452.5 RPS 13726.5 14452.5 RPX 13726.5 14452.5 RAT 13768.0 14493.5 $ LOG HEADER DATA DATE LOGGED: 06-NOV-97 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 5.03 DATA TYPE (MEMORY OR REAL-TIME : MEMORY TD DRILLER (FT): 14905.5 TOP LOG INTERVAL (FT): 13890.0 BOTTOM LOG INTERVAL (FT): 14905.5 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 58.4 ISC VERSION 5.07 PCD 2.00/PCG 6.74/SP4 MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 .ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction..' ............... Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 80.7 TOOL NUMBER P0867SP4 P0867SP4 6.000 6.0 LSND-HT 10.20 60.0 9.0 1800 2.8 1.150 .456 · 650 1.300 75.0 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD 11 FT / H 4 1 68 4 2 GR MAD 11 AAPI 4 1 68 8 3 RPX MAD 11 OHMM 4 1 68 12 4 RPS MAD 11 OHMM 4 1 68 16 5 RPM MAD 11 OHMM 4 1 68 20 6 RPD MAD 11 OHMM 4 1 68 24 7 FET MAD 11 HOUR 4 1 68 28 8 Name Min Max Mean Nsam DEPT 13719.5 14493.5 14106.5 1549 RAT 24.1692 218.233 65.8129 1452 GR 14.6403 149.59 68.9018 1454 RPX 0.9028 -2000 26.1557 1453 RPS 1.2092 2000 28.1934 1453 RPM 2.612 2000 38.2173 1453 RPD 5.7859 2000 63.1913 1453 FET 55.1309 149.349 80.9649 1453 First Reading 13719.5 13768 13719.5 13726.5 13726.5 13726.5 13726.5 13726.5 Last Reading 14493.5 14493.5 14446 14452.5 14452.5 14452.5 14452.5 14452.5 First Reading For Entire File .......... 13719.5 Last Reading For Entire File ........... 14493.5 File Trailer Service name ............. STSLIB.014 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/12/03 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.015 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/12/03 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trai~er Service name ............. LISTPE Date ..................... 97/12/03 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF ~End Of LIS File
