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MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, October 16, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC 3-01 DUCK IS UNIT SDI 3-01 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/16/2024 3-01 50-029-21678-00-00 186-190-0 W SPT 9476 1861900 2500 445 450 453 460 177 437 471 474 REQVAR P Bob Noble 8/19/2024 MIT-IA as per AIO 1.010 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:DUCK IS UNIT SDI 3-01 Inspection Date: Tubing OA Packer Depth 170 2755 2712 2692IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN240820141233 BBL Pumped:7.6 BBL Returned:7.2 Wednesday, October 16, 2024 Page 1 of 1 9 9 9 9 9 9 999 99 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.10.16 12:40:31 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, September 1, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Lou Laubenstein P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC 3-01 DUCK IS UNIT SDI 3-01 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/01/2022 3-01 50-029-21678-00-00 186-190-0 W SPT 9476 1861900 2500 85 85 85 85 610 780 790 800 REQVAR P Lou Laubenstein 8/8/2022 2 year MIT-IA to maximum anticipated injection pressure 2500 psi per AA AIO 1.010 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:DUCK IS UNIT SDI 3-01 Inspection Date: Tubing OA Packer Depth 1312 2768 2753 2745IA 45 Min 60 Min Rel Insp Num: Insp Num:mitLOL220808122540 BBL Pumped:3.7 BBL Returned:3.8 Thursday, September 1, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 2 year MIT-IA AA AIO 1.010 James B. Regg Digitally signed by James B. Regg Date: 2022.09.01 14:09:43 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, August 21, 2020 To: Jim Regg P.I. Supervisor �fJ�fl� q(5lzfSUBJECT: Mechanical Integrity Tests `/ Micorp Alaska, LLC 3-01 FROM: Guy Cook DUCK IS UNIT SDI 3-01 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry� NON -CONFIDENTIAL Comm Well Name DUCK IS UNIT SDI 3-01 Insp Num: mitGDC200818110157 Rel Insp Num: API Well Number 50-029-21678-00-00 Inspector Name: Guy Cook Permit Number: 186-190-0 Inspection Date: 8/18/2020 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3-01 Type Inj F w TVD 9476 Tubing 2215 - 2204 2214 ' 2231 PTD 1861900 - Type Testi SPT Test psi2500 IA 516 2801 2780 - 2767 BBL Pumped: 5.6 - 'BBL Returned: i5.8 - OA 540 - 640 - 660 680 REQVAR --- _ Interval P/I+ -- f Notes: AA AIO 1.010 for slow IA x OA communication. 2 year MITIA to max anticipated injection pressure. The test was done with a triplex pump, bleed trailer and calibrated gauges. Friday, August 21, 2020 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Tuesday,August 30,2016 P.I.Supervisor ?ep 'tC1C(4? SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC 3-01 FROM: Matt Herrera DUCK IS UNIT SDI 3-01 Petroleum Inspector Src: Inspector Reviewed 1!.y). P.I.Supry .j NON-CONFIDENTIAL Comm Well Name DUCK IS UNIT SDI 3-01 API Well Number 50-029-21678-00-00 Inspector Name: Matt Herrera Permit Number: 186-190-0 Inspection Date: 8/26/2016 Insp Num: mitMFH160827153544 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3-01 ' Type Inj W TVD 9476 Tubing 2225 2325 _ 2250 2290 PTD 1861900 (Type Test SPT Test psi 2369 - IA 603 2813 2790 . 2773 - Interval REQVAR P/F P ✓ OA 640 865 - 860 865 Notes: IA pressure tested to 2800 PSI per Operator AIO-1.010 AA Variance SCANNED JUN 2 32017 Tuesday,August 30,2016 Page 1 of 1 • • t 3-0 Regg, James B (DOA) From: Regg, James B (DOA) k Sent: Tuesday, August 16, 2016 10:22 AMl �� B(i�'Iiw To: 'Wyatt Rivard' Cc: Wallace, Chris D (DOA); Brooks, Phoebe L (DOA) Subject: RE: END 3-01 (PTD # 1861900) MIT-IA Test Date Timing is acceptable. Jim Regg Supervisor, Inspections AOGCC SEWED JAN 2 7 2017 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or jim.reggPalaska.gov. From: Wyatt Rivard [mailto:wrivard©hilcorp.com] Sent: Tuesday, August 16, 2016 10:00 AM To: Regg, James B (DOA) Subject: END 3-01 (PTD # 1861900) MIT-IA Test Date Jim, Endicott water injector END 3-01 (PTD# 1861900)operates under admin approval A10 1.010 for slow IAxOA communication. As per A10 1.010,the well requires an MIT-IA to max injection pressure once every two years by August 20th. The last witnessed MIT-IA was on 6/17/14. The well has been shut-in since 7/29/16 along with all Endicott wells for the ongoing summer turnaround maintenance work.The TAR work is currently expected to wrap up by the end of the week with wells starting to return to production/injection on 7/19/16. Hilcorp would like to return END 3-01 to injection by the end of the week but the well will likely not be stable enough for a,n 11QIT by 8/20/16. Alternatively, Hilcorp can ensure that 3-01 has a witnessed MIT-IA as soon as the well is stable, no later than 8/31/16. Please let me know if this an acceptable alternative for this test cycle. Thank You, 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 1 S • zivo c014- pit IBC,f1oc-3 SDI 3-01 TIO Plot 3,000 - - 20,000 - 18,000 2,500 - 16,000 14,000 2,000 - - 12,000 EU_ v 1,500 - - 10,000 j ti 0_ - 8,000 1,000 - - 6,000 4,000 500 - - 2,000 0 lllllllllllllllllllllllllllllllllllllllllllllllllllllllllllllllllllllllll 0 LO L LD LD LD L LO LD tD LID LID LULID to 'U LU LU LU LD LID LU LU LU LU LU LU LU LU LULC, L.0 LSD LU to LU LU tD tD OD tD tD tD tD .-1 .-1 .-1 .-1 ti 1 - ti .-1 ti .-1 -1 - 'L ti - - - - - - ti .-1 -L -1 ,1 0000000000000000000000000000000000000000000000 N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N 00 O N V' LD CO 0 .\-I M 1\N 0 ,-1 t+) V\) N Cr, *-1 Into N Ol .-1 M t/1 N O) .\i tv) Ln N 0) .\-1 M t./1N Cr) .-I N V LD CO 0 N V l\0 .--I N N \ N \ O O O O O .ti N N N N 0 0 0 0 0 .--1 ti ci N .-I N N N N N M O O O O \ .-1 tl1 If) LI) V1 t!1 to tf1 lD LD tD lD lD LID LU tD lD lD LU LID LI/ LU LD N N N N N N N N N N N N N N N N CO CO 00 0000 00 00 00 CO 0000000000000000000000000000000000000000000000 —Tubing —IA —OA —Water Inj 1:01 RECEIVED Post Office Box 244027 c} /� Anchorage,AK 99524-4027 Hilcorp Alaska,LLC JUL 3 0 20h 3800 Centerpoint Drive Suite 100 AOGCC Anchorage,AK 99503 Phone: 907/777-8300 Fax: 907/777.-8301 July 29, 2015 Commissioner Cathy Foerster Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 p Q D Anchorage, AK 99501 (y 6 ` � _p D1 Re: Duck Island Unit Well Renaming Request 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 ill New API_WeliNo l • PermitNumberl WelIName I WellNumber WellNumber 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 2-288/019 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 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/S14 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/S09 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 2-66SD12 2-66 50029218580000 1880970 DUCK IS UNIT MPI 2-68/S17 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 7 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/K33 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 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 22, 2012 5LAI NED SEP 0 31Z ! q� 1�`1 Mr. Jim Regg n � I It ` 0 Alaska Oil and Gas Conservation Commission �� 3 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of Endicott Row 3 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from Endicott Row 3 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 • • I I I BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Endicott Row 3 Date: 10/03/10 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 - ND3-01 / N -29 1861900 50029216780000 7.0 4.4 0.3 9/6/2010 1.70 10/3/2010 END3-03 / J -33 1921210 50029223060000 8.0 6.1 0.3 9/6/2010 2.55 10/3/2010 END3-05 / 0-29 1861300 50029216240000 3.0 2.0 0.5 9/6/2010 3.40 10/3/2010 END3-07A / L -29 1981470 50029219110100 2.0 0.5 0.3 9/6/2010 1.70 10/3/2010 END3-09 / L -28A 1950190 50029217800100 0.1 NA 0.1 NA 1.00 10/3/2010 END3-15 / K-33 1870940 50029217510000 0.1 NA 0.1 NA 1.00 10/3/2010 END3-17F / K -30 2032160 50029219460600 1.5 0.5 0.5 9/6/2010 2.55 10/3/2010 END3 -19 / R -28 1940490 50029224630000 10.0 17.0 0.3 9/6/2010 1.70 10/3/2010 END3-21 / L -34 1870330 50029217140000 23.0 14.5 1.1 9/6/2010 13.60 10/3/2010 END3-23 / N-32 1861550 50029216450000 1.5 1.0 0.5 9/6/2010 3.40 10/3/2010 END3-27 / M-33 1860830 50029215860000 1.0 0.1 0.6 9/6/2010 2.55 10/2/2010 END3 -29 / J-32 1901560 50029221060000 2.0 1.0 0.6 9/6/2010 3.40 10/2/2010 END3 -31 / K -32 1972270 50029228380000 2.0 3.0 0.5 9/6/2010 3.40 10/2/2010 END3 -33A / J -35 2032150 50029216680100 0.5 NA 0.5 NA 3.40 10/2/2010 END3 -35 / L -36 1870200 50029217010000 10.0 7.0 0.4 9/6/2010 3.40 10/2/2010 END3 -37 / L -35 1950510 50029225540000 8.0 7.3 0.3 9/6/2010 1.70 10/2/2010 END3 -39A /1-37 1970910 50029217640100 1.0 0.8 0.7 9/6/2010 3.40 10/2/2010 END3 -49A / M-40 1970570 50029217350200 0.4 NA 0.4 NA 1.70 10/2/2010 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission G"~ DATE: Monday, August 09, 2010 To: Jim Regg j~~ v q/l~ P.I. Supervisor '' l1 ~~ SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 3-O]/N29 FROM: Chuck Scheve DucK Is UNIT sDI 3-olmrz9 Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Comm Well Name: DUCK IS UNIT SDI 3-01/N29 API Well Number: 50-029-21678-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS100804060215 Permit Number: 186-190-0 Inspection Date: 8/3/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3-01/N29 - Type Inj. W TVD 9475 ~ IA 370 2590 2560 2540 2530 ' P.T.D 1861900 ypeTest sPT ,Test psi 2369 ~ QA 360 550 600 620 640 Interval REQvAR p/F P Tubing 1910 1910. 1910 1910 1910 Notes: packer depth taken from operator report. Well has AA for IA x OA comunication, AIO 1.010. JBR- Passing test based on TIO data trend; confirms IAxOA but no deterioration of conditions evident since AIO 1.010 approved. h.. Monday, August 09, 2010 Page 1 of 1 • • SChli~ib8rger Alaska Data & Consulting Services 2525 Gambell Slreet, Su#e 400 Anehorage, AK 99503-2836 ATTN: Beth Well Job # N0.5553 Company: State of Alaska Alaska Oil & Gas Cons Comm Ann: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Log Description Date BL Color CD J-13 K-068 PWDW3-1 8148.00109 BCUE-00027 BCRC-00027 USIT MEM PROD PROFILE t ~ RST WFL ~ s ~ /pL ~ 06/23/10 06/14/10 06/22/10 1 1 1 1 1 1 1-11/SN-04 3-O1M-29 B148-00107 BD88-00021 LDL MEMMIJ. R FILE 06/12/10 O6H3/10 1 1 1 1 15-168 10AKA0047 OH MWD/LWD EDIT 04/04/10 2 1 15-166P81 03-22 t0AKA0047 BSJN-00047 OH MWD/LWD EDIT RST 04/01/10 03/30!10 2 1 1 1 G-30C A22F-00038 MCNL 04/22/10 1 1 BP Exploration (Alaska)Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. ~ rl ~. 06/30/10 04/29/09 91~r`ti~~~~~s~~~r~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth won ~_~ ,. N0.5209 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 2-34/P-14 12017519 =a~~~ ~~~~~ RST - ~ uate BI_ Color CD 3-03/J-33 AZ4D-00013 RST 09/27/09 04/05/09 1 1 1 1 15-29A J-09A AXBD-00022 AP3O-00024 CH EDIT PDC-GR (LDL) - RST L - 04/18/09 1 3-01/N-29 15-29A 12-07A AYKP-00008 AXBD-00022 RST () - MEMORY LDL ~~~ ~ (~/ ~ ~'~~~ 03/24/09 01/20/09 04/18/09 1 1 1 1 1 1 AY3J-00021 USIT a 04/20/09 1 1 PLEASE ACKNOWLEDGE RE CEIPT BY SIGNI N[; nNn RFr~iQti~Nn nrac rnov ecru rn. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: i1 Alaska Data & Consultin ervices 2525 Gambell Street, Suit 00 Anchorage, AK 03-2 ATTN: Beth Received by: ~`~ • ,'- UNDER EVALUATION: 3-01/1-29 (PTD #1861900) TxIA Communic n Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~ 4~~(~~ Sent: Thursday, March 26, 2009 3:33 PM ~~ I To: Regg, James B (DOA); Maunder, Thomas E (DOA); END/BAD Area Manager; END, Operations Lead Tech; END, Production Coordinator; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Soto, Jose A; Garing, John D Cc: Townsend, S. Eliot; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: 3-01/N-29 (PTD #1861900) TxIA Communication Attachments: 3-01.pdf; 3-01.ZIP All, Well 3-01/N-29 is a produced water injector with confirmed IAxOA communication as evidenced by recent bleed events. The OA pressure was bled to from 740 psi to 0 psi on 03/22/09 and was found to have equalized with the IA pressure on 03/25/09. The IA pressure was then bled from 580 psi to 0 psi on 03/25/09 and~the OA pressure decreased over 100 psi. The well passed an AOGCC witnessed MITIA to 3000 psi on 03/20/09 post-initial injection. The well has been reclassified as Under Evaluation and will remain on water injection while an AA application is drafted and mailed to the AOGCC. A wellbore schematic, TIO plot and injection plot have been included for reference. Please call with any questions or concerns. Thank you, Winton Aubert Office: 659-5102 «3-01.pdf» «3-01.ZIP» 4/6/2009 DIU 3-01/N-29 PTD 1861900 3/26/2009 TIO Pressures 4,000 • 3,000 ~ 2.000 ~ Tbq ^ IA -~-- OA OOA -~- OOOA -~- On 1,000 ^~~-~~^a+•^~ Et~f^ ^f ~ ~ ^ fa ~afaiai~ ~f ~ ^---~~-~ 12!27105 01!03109 01!10/09 01/17/09 O1i24/09 01/31/09 02/07/09 02!14109 02/21J09 02/28/09 03/07/09 \~ ll • R I, • DIU 3-01/N-29 PTD 1861900 3/26/2009 Injection Plot z,soD 2,500 2,400 2,300 2,200 2,100 2,000 1,900 1,800 1,700 1,600 1,500 a_ 1 400 1,300 1,2~ 1,100 1,000 800 700 600 500 4D0 300 200 100 z.~o 1.900 1,BOD 1,700 1,600 1,500 t d00 1.000 ~ n 4W 300 200 1D0 - WHIP SW PvJ - MI GI - Other ~- On • • 12,"7108 01/03/09 01/10/09 01/17/09 01/24/09 OV31/09 02/0?/09 02!14/09 02/21/09 02!'8/09 03/07/09 03/14/09 03/21/09 TREE= 4-1/16" CNV WELLHEAD = 11' FMC ACTUATOR= BAKER KB. ELEV..- - 56' BF. ELEV - 16.4' KOP = -_ Max Angle = 50° @ 8080' Datum MD = 12458' Datum TVD = 10000 SS END 3 ~0 ~ S NOTES:'"**4-112" CHROMETBG``*" ~J 30" CONDUCTOR, ID = ? 106' 13-3/8" CSG, 68#, L-80 BUTT, ID = 12.415" 2480' 9-5/8" CSG, 47#, NT80S XO NT95HS 10304' 4-1/2" OTIS HXO SSSV LANDING NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 7 3588 3556 22 MMGM DMY RK 0 03!03!09 6 5881 5302 45 MMGM DMY RK 0 03/03/09 5 7358 6337 46 MMGM DMY RK 0 08/17/94 4 8425 7047 48 MMGM DMY RK 0 08/17/94 3 9474 7764 45 MMGM DMY RK 0 08/17/94 2 10448 8458 42 MMGM DMY RK 0 08/17/94 1 11335 9152 37 MMGM DMY RK 0 08/17/94 11715' I~ 4-1 /2" OTIS X NIP, ID = 3.813" Minimum ID = 3.725" @ 11863' 4-1 /2" OTIS XN NIPPLE TOP OF 7" LNR I-i 11830' 11735' -~ 4-1 /2" X 5-1 /2" XO, ID = 3.958" 11738' 9-5/8" X 5-1/2" TM/ HBBP PKR, ID = 4.750" 11743' 5-1/2" X 4-1/2" XO, ID = 3.958" 11830' 9-5/8" X 7" BKR LNR HGR w /6-1/2' TIEBK, ~ = 6.844" 11842' 4-1/2" OTIS X NIP, ID = 3.813" 4-1/2" TBG, 12.6#, 13CR-80 NSCT, .0152 bpf, ID = 3.958" 9-5/8" CSG, 47#, NT95HS, ID = 8.681" 11L 12112' PERFORATION SUMMARY REF LOG: DLL-GR ON 01/21/87 ANGLE AT TOP PERF: 36° @ 12151' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 12151 - 12171 O 05/28/00 2" 1 12166 O 11/22/95 2" 6 12286 - 12304 O 09/23/99 2-1/8" 4 12286 - 12326 S 06/19/94 3-3/8" 6 12304 - 12324 O 05/31/95 3-3/8" 4 12304 - 12326 S 05/24/95 2-1/8" 4 12360 - 12380 S 06/19!94 3-3/8" 4 12360 - 12380 S 05/24/95 2-1/2" 4 12360 - 12380 O 05/27/95 3-3/8" 4 12390 - 12426 S 05/24/95 2-118" 4 12390 - 12460 S 06/19/94 5" 4 12480 - 12520 S 06/19/94 5" 4 12546 - 12564 S 06/19/94 5" 4 12570 - 12600 S 06/19/94 2-7/8" 6 12642 - 12662 O 02/25!09 2-7/8" 6 12668 - 12708 O 02/25/09 2-7/8" 6 12729 - 12739 O 02/25/09 2-7/8" 6 12742 - 12762 O 02/25/09 7" LNR, 29#, SM-110 BUTT, .0371 bpf, ID = 6.184" ~~ 13050' 1~ 1863' I-~4-1/2" OTIS XN NIP, ID = 3.725" 11875' 4-1/2" WLEG, ID = 3.958" ELMD NOT LOGGED 12546' I~ PBTD -POST SOZ (??/??/??) 12630' 7" MARKERJOINT 12810' CTM MILLED CEMENT, ID = 3.70" (02/06/09) 12926' PBTD DATE REV BY COMMENTS DATE REV BY COMMENTS 08/29/87 PA #7 INITIAL COMPLETION 02/07/09 LLUSV MILL CMT SOZ (02106/09) 08/25/94 D15 RWO 03/03/09 MV/SV ADPERF (02/25/09) 05/28/00 DBR ADPERF 03/18/09 MEF/SV GLV C/O (03/03/09) 09/24/05 E71/TLH WAIVER CANCELLED 11/19/07 DTR/PJC GLV C/O 03/18/08 JAS/PJC CONVERT NEW FORMAT ENDICOTT UNIT WELL: 3-01 / N-29 PERMIT No: 1861900 API No: 50-029-21678-00 SEC 8, T11N, R17E, 2536' FNL & 879' FEL BP Exploration (Alaska) • MEMORANDUM To: JimRegg ~ 3~Z~'~r~ P.I. Supervisor ~ l FROM: Bob Noble Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Tuesday, Mazch 24, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 3-O]/N29 DUCK IS UNIT SDI 3-011N29 Src: Inspector NnN_CnIVTTt)F.NTiAL Reviewed By: P.I. Suprv J ~- Comm Well Name: DUCK IS UNIT SDI 3-01/N29 ApI Well Number 50-029-21678-00-00 • Inspector Name: Bob Noble Insp Num: mitRCN090321152242 186-190-0 - Permit Number: Inspection Date: 3/20/2009 Ret Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3-OllN29 Ty'pC ~~ TVD 9475 ~ 330 3000 2980 2970 ~ 2970 P.T. 1861900 TypeTe9t Te$t pSl 3000 ~f~ 360 560 640 660 b90 Interval °T~R P/F X ~ ~ Tubing zooo zooo 17~ 1700 1700 Notes • MIT-IA to 3000 psi pre AA. Well is being evaluated for IA to OA com. Held for an extra 15 min becouse of a change in tubing pressure. I did not • make a pass or fail call. Tuesday, March 24, 2009 Page 1 of 1 s • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Saturday, March 21, 2009 3:04 PM To: Gary Preble (SAIC) Subject: 3-01/N-29 (186-190) Gary, I am reviewing the 404 submitted for the recent CT squeeze. It does not appear that the CT work reported for 1/10/09 is complete. Would you check with the engineer and see if there was additional work? Thanks in advance. Tom Maunder, PE AOGCC Maunder, Thomas E (DOA From: Preble, Gary B (SAIC) [Gary.Preble@bp.com] Sent: Tuesday, March 24, 2009 10:13 AM To: Maunder, Thomas E (DOA) Subject: Emailing: 3-01-n-29-well-service-report-.pdf Attachments: 3-01-n-29-well-service-report-.pdf 3-O1-n-29-well-sere ice-report-... Tom, Attached is the full description of work that was performed on 1/10/09 on 3-01/n-29 (186-190) The message is ready to be sent with the following file or link attachments: 3-O1-n-29-well-service-report-.pdf Note: To protect against computer viruses, e-mail programs may prevent sending or receiving certain types of file attachments. Check your e-mail security settings to determine how attachments are handled. «3-O1-n-29-well-service-report-.pdf» 3/25/2009 STATE OF ALASKA ~~~~J n ALASKA OIL AND GAS CONSERVATION COMMIJ~I'l7~ REPORT OF SUNDRY WELL O#~~I~~S 3-/~~7 1. Operations Abandon ~ Repair Well ~ Plug Perforatio 8~ ~~ ti {~ ulate~ Other Q CONV'T TO WINJ ~ ' ~ ,~ Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ W'a~ ~:. ~;f~~Q ~~ ynsion ~ SQUEEZE - Change Approved Program ~ Operat. Shutdown ~ Perforate 0, ~ItOti ter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~ ~' Exploratory 186-1900 - 3. Address: P.O. Box 196612 Stratigraphic r Service _ ~ 6. API Number: Anchorage, AK 99519-6612 50-029-21678-00-00 - 7. KB Elevation (ft): 9. Well Name and Number: 56 KB - 3-01/N-29, 8. Property Designation: 10. Field/Pool(s): _ ADLO-047502 - ENDICOTT Field/ ENDICOTT OIL Pool 11. Present Well Condition Summary: Total Depth measured 13050 , feet Plugs (measured) 11842' 2/12/08 true vertical 10525.91 , feet Junk (measured) None Effective Depth measured 12546 feet true vertical 10127 feet Casing Length Size MD TVD Burst Collapse Conductor 161 30" Surface - 161 Surface - 161 Surface 2480 13-3/8" 68# L-80 Surface - 2480 Surface - 2478 4930 2270 Intermediate 12111 9-5/8" 47# NT80S Surface - 12111 Surface - 9774 6870 4760 Liner 1220 7" 29# SM 11830 - 13050 9459 - 10526 11220 8510 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13CR-80 SURFACE - 11875' 0 0 - Packers and SSSV (type and measured depth) 9-5/8"X5-1 /2" TIW HBBP PKR 11738' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): T t t d i i i l i l rea men escr pt ons nc ng vo ud umes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: Subsequent to operation: SI 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run EXplOratOry ~ Development ~ Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ Gas WAG r GINJ WINJ WDSPL ~` 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-391 Contact Gary Preble Printed Name Gary Pr ale Title Data Management Engineer Signature Phone 564-4944 Date 3/9/2009 Form 10-404 Revised 04/2006 R P ~ A '°"' '"'" ~~/~ Submit Original Only 3-01/N-29 186-190 PERF ATTACHMENT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 3-01/N-29 8/27/87 PER 12,480. 12,520. 10,074.24 10,106.57 3-01/N-29 8/27/87 PER 12,546. 12,564. 10,127.42 10,141.8 3-01/N-29 8/27/87 PER 12,570. 12,600. 10,146.58 10,170.44 3-01/N-29 5/13/91 APF 12,286. 12,326. 9,915.58 9,948.22 3-01/N-29 5/13/91 APF 12,360. 12,380. 9,976.03 9,992.43 3-01/N-29 5/13/91 APF 12,390. 12,460. 10,000.64 10,057.97 3-01/N-29 6/16/94 SQZ 12,286. 12,326. 9,915.58 9,948.22 3-01/N-29 6/16/94 SQZ 12,360. 12,380. 9,976.03 9,992.43 3-01/N-29 6/16/94 SQZ 12,480. 12,520. 10,074.24 10,106.57 3-01/N-29 6/16/94 SQZ 12,546. 12,564. 10,127.42 10,141.8 3-01/N-29 6/16/94 SQZ 12,570. 12,600. 10,146.58 10,170.44 3-01/N-29 10/11/94 APF 12,304. 12,326. 9,930.26 9,948.22 3-01/N-29 10/11/94 RPF 12,360. 12,380. 9,976.03 9,992.43 3-01/N-29 10/11/94 RPF 12,390. 12,426. 10,000.64 10,030.17 3-01/N-29 5/24/95 SQZ 12,304. 12,326. 9,930.26 9,948.22 3-01/N-29 5/24/95 SQZ 12,360. 12,380. 9,976.03 9,992.43 3-01/N-29 5/24/95 SQZ 12,390. 12,426. 10,000.64 10,030.17 3-01/N-29 5/27/95 RPF 12,360. 12,380. 9,976.03 9,992.43 3-01/N-29 5/31/95 RPF 12,304. 12,324. 9,930.26 9,946.59 3-01/N-29 11/18/95 APF 12,166. 12,167. 9,818.51 9,819.32 3-01/N-29 11/22/95 RPF 12,166. 12,167. 9,818.51 9,819.32 3-01/N-29 9/23/99 RPF 12,286. 12,326. 9,915.58 9,948.22 3-01/N-29 5/28/00 APF 12,151. 12,165. 9,806.46 9,817.71 3-01/N-29 5/28/00 APF 12,168. 12,171. 9,820.12 9,822.53 3-01/N-29 5/28/00 RPF 12,166. 12,167. 9,818.51 9,819.32 3-01/N-29 1/10/09 SQZ 11,600. 12,600. 9,365.11 10,170.44 3-01/N-29 2/24/09 APF 12,729. 12,739. 10,272.41 10,280.25 3-01/N-29 2/24/09 APF 12,742. 12,762. 10,282.6 10,298.25 3-01/N-29 2/25/09 APF 12,642. 12,662. 10,203.74 10,219.59 3-01/N-29 2/25/09 APF 12,668. ~ 12,688. 10,224.34 10,240.14 3-01/N-29 2/25/09 APF 12,688. 12,708. 10,240.14 10,255.91 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SANb PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • 3-01/N-29 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 1/7/2009 ASRC Unit #2, standby for botlup on well 3-14. MIRU **job in progress** 1/8/2009 ASRC unit #2 complete rig uF progress*" _ 1 /8/2009 " CTU# 6 1.75' CTstart rig up. Standby time for CTU. CTU MIRU **job in **job continued on WSR 01-09-09** 1/9/2009 ASRC Unit #2 CTU rigged up, held pre-job safety meeting. open well to sep and continues to assist CTU *''job in progress** 1/9/2009 CTU 6 W/ 1.75" CT, Scope; FCO/cmt sqz **continued from WSR 01-08-09** cont 'rig upstart BOP test.RlH w /nozzle tag at 12378' pereform FCQ~g~Q~„~Qu,I~,. ;not go deeper. got clean pickups. circ btms up. PJSM w/ acid pumpers. **job continued on WSR 01-10-09** 1/10/2009 CTU #6 1.75' CT Scope; fco/ cmt sqz «interact publishing» **continued from ,WSR 01-09-09** reciprocate from 12428- 12151 while pumping 20 bbl acid. over- displace w/ 60 bbl KCL. pooh. Estimate 5 bbls cement behind pipe. Walk ,pressure up in 500 psi increments. Hold squeeze pressure at 2500 psi for 1 hr. Swap to bio and jet down to 12507. Make 2 contaminate passes and chase ooh @ 80% . FP well w/ 76 bbls diesel. Trap 500 psi on tbg. ** Cement squeeze job complete*"" ~ will WOC and return later for cmt milling)RDMO 1/10/2009 ASRC Unit #2 assist CTU. Orders to RDMO, move in equipment *"job in 'progress** 1/11/2009 ASRC Unit_#2 complete RDMO **job complete** 1/13/2009~T/I/0=450/450/400. MIT-T **FAIL'`'` to 2000 psi. (Post Cement Squeeze). Pumped 6 bbls of neat to reach test pressure. TP fell off rapidly. Established LLR at .29 bpm @ 2000 psi. with 10 bbls of neat methanol. Final WHP = 420/380/400 1/14/2009 '**W ELL S/I ON ARRIVAL*"* (post sqz) RAN 3 3/8" DMY GUN TO 12,480' CORRECTED TO MD - S. BAILER EMPTY RAN 2 7/8" DMY GUN TO 12,493' CORRECTED TO MD - RECCOVERED CEMENT SET 4.5" SLIP STOP CATCHER AT 5,995' SLM PULLED STA.# 6 (1.5" RK-DMY) AT 5,851' SLM PULLED STA.# 7 (1.5" RK-DMY) AT 3,557' SLM ***CONT WSR ON 1-15-09*** 1/15/2009***CONT WSR FROM 1-14-09**" (post sqz) ISET STA.#7 1.5" RK-DOME (16/64", 1500 TRO) AT 3,557' SLM aSET STA.#6 1.5" RK-S/O 20/64" AT 5,851' SLM ;PULLED SLIP STOP CATCHER FROM 5,995' SLM (EMPTY) ''**LEFT WELL S/I, NOTIFY DSO ON DEPARTURE*** .~ 1/20/2009:*""WELL SHUT IN ON ARRIVAL*** 31NITIAL T/I/0 = 400/250/400. RIG UP E-LINE FOR RST BORAX / LDL. EBY FOR LRS. *"*JOB CONTINUED ON 21-JAN-2009"** STAND ~~-~ ~~ C ~~~ Well5erviceReport • WELL SERVICE REP©RT • Page 1 of 2 WI=LL JOB SCOPE UNIT END3-01 INJECTION CONVERSION CTU #6 DATE DAILY WORK DAY SUPV 1/10/2009 CEMENT SQUEEZE• FILL CLEAN OUT IMM COST CODE PLUS KEY PERSON NiGWT SUPV ENU716267-Q bS-IAVERGNE HARRIS MIN ID DEPTH TTL SIZE 4° 4FT o° CTU #6 1.75` CT Scope; fco/ cmt sqz «interact publishing» •"con4nued from WSR 01-09-09** reciprocate from 12428- 12151 while pumping 20 bbl acid. over-displace w160 bbl KCL. pooh. Estimate 5 obis cement behind pipe. Walk pressure up in 500 psi increments. Hold squeeze pressure at 2500 psi for 1 hr. Swap to bio and jet down to 12507. Make 2 contaminate passes and chase ooh @ 84% . FP well w176 bbls diesel. Trap 504 psi on tbg. ** Cement squeeze job complete*** (will WOC and return later for cmf millinal. ROMO LOG ENTRIES Inif Tb , IA, OA 246 340 TIME DEPTH TBG CTP BPM BBLS COMMENTS 00:01 11675 319 1599 1.7 ilk um rs rime u 00:22 11675 314 360 0 31 um ers rea . line u down coil w1 meth to coil um 00:28 11675 252 832 1 31 m on line w/ meth 00:30 11675 252 111 0 33 line u um ers down coil 00:32 11675 246 117 1 33f came online fresh water 00:41 12374 246 274 .5 3$ um ers t to 4k 00:50 12404 246 465 1.7 38a come online down ,coil w1 acid 01:05 12404 249 3556 1.6 59f swa to f-water 01:22 12428 262 3$79 1.5 72 acid at nozzle. close choke, start reci u to 12151. swa to KCL 01:29 12151 260 32$0 1 82 RBIH 01:35 12401 256 2633 1 $9 circ ressure decreasin noticeabl . 01:39 12151 257 707 0 92 acid out of nozzle. 01:44 12037 252 2066 2.7 Ok ilne kcl down col far over dis lacement 01:59 12037 603 842 4 35m line u down backside w160/40 to finsih dls lacement and 02:11 11773 944 556 0 68 down on um .swa down coil 02:14 11662 290 457 .7 0m come online down coil f . oh 03:09 7643 336 552 0 38 down on um .coil freeze rotected. 04:47 0 168 0 0 43 ooh close swab 17.5 turns 05:13 0 0 0 0 43 0 off of wellhead and BD tools 05:56 0 MU BHA ;1.9" CTC , hvo 2" stin ers, 2' x-over 2,5" BON oah- 9.2' 06:04 0 stab onto weiihead. 07:08 0 250 250 LPT 25fl si 07:15 0 4000 4000 H PT 4000 si 07:31 0 243 250 O en swab 17.5 #ums RIH 08:01 2540 256 237 Wt ck 5 k 08;33 54}00 277 341 Wt ck 9 k u 5 k down 09:1$ 8500 305 487 IA 300 si OA 400 si 09:24 9000 285 500 Wt ck 15 k u 9 k down 10:00 12000 326 638 Wt ck 22 k u 12 k down 10:12 12513 326 597 Ta bottom PUH 10' fla i 10:20 0 PJSM with all ersonal on location 10:35 0 Batch u cement 10:53 12501 78 3400 Circulate methanol out of coil 11:13 12207 80 Shut choke in and reform in'ectivi test 1 b m 250 si 1.5 b m 300 si 2 b m 450 si b m 600 si 12:27 12475 55 Cement is u to wei ht line u to t cementers line #c 4000 si 12:41 12475 40 2400 1.6 Start um in cement 13:01 12475 32 2$19 1.4 25 Cement is in the coil um 5 bbls of water behind cement 13:12 12475 33 28 PUH 32' f m 13:25 12140 38 1200 1.2 51 Close choke looki fora 540 si bum 13:30 12000 38 400 59 PUH to safte 11600' 13:56 11600 1000 1418 69 Hold 1000 si 15 min 14:19 11600 1536 2056 0.5 74 Hold 1500 si or 15 min 14:31 11600 IA 540 si OA 550 si 14:38 11600 2000 2500 0.5 85 Hold 2000 si for 15 min http:/lapps2-alaska.bpweb.hp.com/awgrs-wellservicereport/default.aspx?id=F6194C2F4DB24116... 3/24/2009 We1lServiceReport • Page 2 of 2 14:52 11600 2500 3034 0.5 93 Hold 2500 si for 1 hr 15:35 0 IA 500 si OA 550 si 15:54 11557 2500 3058 0.5 123 Dro ressure to 500 si shut and line u with biozan 16:99 11557 500 3560 2.3 126b Come online down coil w /biozan 16:36 11557 500 RIH to to 16:49 1180q 500 3288 2.4 16 o a come online w / um biozan at nozzle 16:51 19800 500 3299 2.4 161 tart elfin cemen 17:02 12507 500 3519 2.5 203k Swa to wafer at FLAG PUH CHASE cement #o tail i e 17:15 19875 500 3800 2.5 223 RIBH to fla 97:49 12507 546 3800 2.5 243 KCL at nozzle POOH chasin cement out of hole 18:42 8807 100 387 1.9 371 con! ooh 19:03 8087 200 480 1 Od swa to diesel cont. oh. 20;23 1834 256 2877 1.3 76m swa to meth for coif f . 20:56 0 500 0 0 120 ooh tra 500 si on tb .dose swa 17.5 turns 21:18 0 PJSM for RD 23:59 0 end of ticket Final Tb , IA, OA 500 500 620 FLUIQ SUMMARY bbls of 2% xs kcl 360 bbis of 2% xs kcl w/ .fi % safe tube 123 bbis of 60!40 meth 76 bbis of diese bbis of fresh water http://apps2-alaska.hpweb.bp.corn/awgrs-wel lservicereportJdefault.aspx?id=F6194C2F4DB24116... 3/24/2409 1 /21 /2009 1/21/2009 T/I/0=450/250/400 Temp= SI Assist E-line with Borax Log (Eval for Inj) Pumped ~2 bbls meth, 210 bbls sea water, 66 bbls borax, 118 bbls sea water while E-line made logging passes. *"" Job continued on 1-22-09 WSR*** 1/22/2009;""*JOB CONTINUED FROM 21-JAN-2009**" X30 BBLS BORAX IN FORMATION FOR FIRST PASS. 46 BBLS BORAX IN FORMATION ON SECOND BORAX PASS. ONCE 66 BBL BORAX PUMPED, 'WELL FLUSHED WITH 260 BBL SEAWATER, FREEZE PROTECT TBG WITH 35 BBLS DIESEL. BORAX PASSES CON ' SQUEEZED PERF INTERVAL. WELL SI ON DEPARTURE. WELL TENDER NOTIFIED OF VALVE POSITIONS. FINAL T/I/O 350/400/200 PSI. *""JOB COMPLETE*** 1/22/2009 ""'` Job continued from 1-21-09 WSR*** Assist E-line with Borax log (Injection Conversion) Pumped 267 bbls seawater, 5 bbls meth and 35 bbls diesel down :the Tbg For E-line Borax log. Final WHP's=400/225/400. E-line has control of well on LRS departure. 1/25/2009 T/I/O = SSV/220/370. Temp = SI. Tbg & IA FLs (pre CTD). AL spool dropped. Tbg FL unavailable, well safed out. IA FL near surface. Integral on IA. WV, SSV =Closed. SV, MV =Open. IA & OA = OTG. NOVP. _.__ 1/26/2009~T/I/O=270/220/370. Temp=S1. TBG ~FL~(pre CTD). TBG FL @ surface. SV,WV,MV,SSV=Closed IA,OA=OTG NOVP a """JOB CONTINUED FROM 20-JAN-2009"** PERFORM STP PASSES WHILE LRS PUMPS SEAWATER AND BORAX .SOLUTION AT 0.3 BPM AT 2000 PSI. LOG 2-30 FPM UP PASSES, 1-30 FPM DOWN PASS, 1-60 FPM UP PASS, AND 1-60 FPM DOWN PASS. PERFORM STOP COUNTS AT 12460', 12385', 12340', AND 12270'. LEAK CONFIRMED BY SPINNER RESPONSE IN SQUEEZED INTERVAL AT 12320'. LOG RST BORAX BASELINE PASSES FROM 12490' TO 11900' AT 30, 30, AND 60 FPM. ***JOB CONTINURED ON 22-JAN-2009*** 2/1/2009 CTU #6 w/ 1.75" OD CT. Road unit to END. Job continued on WSR 02/02/09 2/2/2009 CTU #6 w/ 1.75" OD CT. Objective: mill cement. Continued from WSR 02/01/09 MIRU CTU. MU and RIH with Weathertord 2-7/8" motor with 3.70" OD 5-blade concave mill. Ambient temperature dropped to -40 deg F and trending down. Pull to surface and standby for weather. Job continued on WSR 02/03/09. ~ s 2/5/2009.. CTU#6 1.75" CT Job scope: mill cement plug with 3.70" mill. Preform weekly BOP test. «< InterAct is Publishing»> RIH w/3.70" 5 Bladed Junk mill. Stopped at 11516 CTM. Begin milling. Stopped at 11527 CTM. Motor stalled 1 'time. Unable to get motor to work. POOH. Change out Motor. RIH w/3.70" Bladed Junk mill. ***Continue on WSR on 2/6/09*** 5 2/6/2009 CTU#6 1.75" CT Job scope: Mill cement plug with 3.70" mill. «< InterAct is Publishing»> Continue from WSR on 2/5/09 Continue RIH w/ 3.70 5 bladed mill. Stop at 12518 CTM. Beain millinc,LMilled to 12810' CTM, Freeze protect well from 2500' w / 60/40 methanol 38 bbls"""""Job complete"""""' 2/7/2009 ''** WELL SHUT IN PRIOR TO ARRIVAL *** (post sqz & mill out /pre inj conversion) DRIFTED W/ 10' X 2 7/8" DUMMY GUN TO 12,800'SLM. *** TURN WELL OVER TO WELL TENDER, LEFT WELL SHUT IN **" 2/23/2009 ***PERF*** WELL SHUT IN ON ARRIVAL INITIAL T/I/O = 400/0/450 DRIFT RUN ADDED TO JOB TO DETERMINE WELL PRESSURE AT SHOOTING DEPTH, ENSURE WE DO NOT SHOOT OVERBALANCED. TAKE CONTROL OF SSV. ***JOB CONTINUED ON 24-FEB-09*** 2/24/2009***CONTINUED FROM 23-FEB-2009*** PERF LOGGED PRESSURE/TEMPERATURE GR/CCLJEWELRY LOG FROM TD 12842' TO 11280'. ?BLED OFF PRESSURE AT SURFACE TO ZERO AND BHP EQUALS 4400 PSt. GUN RUN 1: PERFORATED INTERVAL 12742'-12762' GUN RUN 2: PERFORATED INTERVAL 12729'-12739'. CHARGE TYPE: 2906 PJ OMEGA 6 SPF, 36" PENE, 0.34" EH, 16 GMS. ***CONTINUED ON 25-FEB-2009*"" --- __ _. 2/25/2009 ***CONTINUED FROM 24-FEB-09*** PERF GUN RUN 3: PERFORATED INTERVAL 12688'-12708' GUN RUN 4: PERFORATED INTERVAL 12668' - 12688' GUN RUN 5: PERFORATED INTERVAL 12642'-12662' CHARGE TYPE: 2906 PJ OMEGA 6 SPF, 36" PENE, 0.34" EH, iWELL LEFT SHUT IN j FINAL T/I/O = 0/0/400 ~***JOB COMPLETE*** 16 GMS. 3/2/2009?T/I/O=150/100/370. Temp=S1. T & IA FL's (SL call-in). T FL near surface. IA FL @ 500'. 3/2/2009:***WELL SHUT IN ON ARRIVAL*** (conversion to WI) ATTEMPTED TO SET SLIP STOP CATCHER...UNABLE TO SHEAR PIN. ~ ***JOB CONTINUED ON 3/3/09 WSR*** ; 3/3/2009 ~~_____ ~.ed "**JOB CONT. FROM SET 4-1/2" SLIP STOP CATCHER @ 5994'SLM. PULLED RK-LGLV'S FROM STA #6(5881'MD) & #7 (3588'MD) SET RK-DGLV'S IN STA #6 (5881'MD) &STA #7 (3588'MD) PULLED 4-1/2" SLIP STOP CATCHER FROM 5994' SLM BRUSHED SVN W/4 1/2" BRUSH & 3.805" GAUGE RING SET 4 1/2 MCX @ 1516'MD (8 X 1/8" EO PORTS, 1.56" BEAN) SER# M-626. RAN 4 1-1/2" CHECK SET -GOOD SET "*"TURN WELL OVER TO WELL TENDER*** 3/4/2009'T/I/0= SSV/90/360. Temp= SI. Pre MITxIA FL. IA FL @ 1032' (58 bbl). SV,WV,SSV= C. MV= O. IA,OA= OTG. NOVP. 3/7/2009T/I/0= 100/20/420. Temp=S1 MIT-IA "*PASS** to 3000 psi.(Convert well to injection) Pumped 5 bbls of neat and 33 bbls of 20" diesel into IA to reach test pressure. 15 min. No loss on IA. 30 min. No loss on IA. bleed pressure off IA rig 'down FWHP=100/150/400 (wing closed swab closed ssv closed master open annulus valves opn to gauges well tender notified of welll status) FLUIDS PUMPED BBLS 1128 2% KCL W/SAFELUBE 1909 2% KCL 18.5 METH 71.25 DIESEL 128 GEOVIS 363 60/40 METH 32 NEAT 66 BORAX 3715.75 Total RE: OPERABLE: 3-01/N-2~I'D #1861900) MIT-IA Passed for Inj~on Conversion Page 1 of 1 Regg, James B (DOA) From: END, 08~M TL [ENDOMTL@BP.com] ~~ ~t~~,~~~i Sent: Saturday, March 14, 2009 2:16 PM (,~ To: NSU, ADW Well Integrity Engineer; Regg, James B (DOA); Maunder, Thomas E (DOA); END/BAD Area Manager; END, Operations Lead Tech; END, Production Coordinator; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Soto, Jose A; Garing, John D Cc: Quy, Tiffany; Holt, Ryan P (ASRC) Subject: RE: OPERABLE: 3-01/N-29 (PTD #1861900) MIT-IA Passed for injection Conversion 3-01 was put on injection just after midnight on March 10th. Jason Caldwell Endicott O&M Team Leader Alternate: Dan Harris (907) 659-6527 (907) 659-6799 / 187 pager ~;`,~,w~~'~ Q~~ ~ ~Du (907) 659-6533 fax From: NSU, ADW Well Integrity Engineer Sent: Sunday, March 08, 2009 10:56 AM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; END/BAD Area Manager; END, O&M TL; END, Operations Lead Tech; END, Production Coordinator; Rossberg, R Steven; Engel, Harty R; NSU, ADW Well Operations Supervisor; Soto, Jose A; Garing, John D Cc: NSU, ADW Well Integrity Engineer; Quy, Tiffany; Holt, Ryan P (ASRC) Subject: OPERABLE: 3-OL/N-29 (PTD #1861900) MIr-IA Passed for Injection Conversion All, Well 3-01/N-29 (PTD #1861900) passed an MIT-IA to 3,000 psi on 03/07/09. The MIT-IA was performed to complete the testing required for injection conversion per Sundry Number 308-391. The well has been reclassified as Operable and may be placed on produced water injection. Once the injection temperature and rates have stabilized, the well will require an AOGCC witnessed MIT-IA. Please notify Well Integrity once the well has been placed on injection and we will schedule the MIT-IA with the AOGCC slope inspectors. Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 3/24/2009 OPERABLE: 3-01/N-29 (PTI~861900) MIT-IA Passed for Injectionlnversion Page 1 of 1 Regg, James. B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Sunday, March 08, 2009 10:56 AM `~~ ~ ~' / ~Z~ j To: Regg, James B (DOA); Maunder, Thomas E (DOA); END/BAD Area Manager; END, O&M TL; END, Operations Lead Tech; END, Production Coordinator; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Soto, Jose A; Garing, John D Cc: NSU, ADW Well Integrity Engineer; Quy, Tiffany; Holt, Ryan P (ASRC) Subject: OPERABLE: 3-01/N-29 (PTD #1861900) MIT-IA Passed for Injection Conversion All, .~ Well 3-01/N-29 (PTD #1861900) passed an MIT-I to . 000 psi on 03/07/09. The MIT-IA was performed to complete the testing required for injection conversion per Sundry Number 308-391. The well has been reclassified as Operable and may be placed on produced water injection. Once the injection temperature and rates have stabilized, the well will require an AOGCC witnessed MIT-IA. Please notify Well Integrity once the well has been placed on injection and we will schedule the MIT-IA with the AOGCC slope inspectors. Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator OfFce: (907) 659-5102 Pager: (907) 659-5100 x1154 3/9/2009 3-01 Water Movement Log • • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, January 20, 2009 8:55 AM To: 'Soto, Jose A' Cc: Lau, John, Jack; Doshier, Ron (ORBIS} Subject: RE: 3-01/N-29 (186-190) Water Movement Log Page 1 of 1 Jose, et al, Either log is acceptable. The goal regardless of log type is to demonstrate no movement above the reservoir. I look forward to viewing the results. Call or message with any questions. A couple of points; please include the permit number in the message header. It helps filing and pulling information. Also, it is important to include the full well name. Just using 3-01 can lead to some confusion since there is also a 03-01 {DS 03-01) at Prudhoe. Call or message with any questions. Tom Maunder, PE AOGCC From: Soto, Jose A [mailto:jose.soto@bp.com] Sent: Monday, January 19, 2009 1:39 PM To: Maunder, Thomas E (DOA) Cc: Lau, John, Jack; Doshier, Ron (ORRIS) Subject: 3-01 Water Movement Log it~~ ~~1~ ZQ~ Tom, Well 3-01 is in it's way to get converted to a water injector. A recent cement squeeze done in the open horizons lead to a 0.3 bpm leak. The well has proof of poor cement behind the casing and a Borax log has been scheduled to demonstrate na upward movement of the injected water will occur. However, Ron Doshier form the Wells Group suggested a water movement log as a faster and also viable alternative to the Borax. We would like to know if you have any objections or comments with regards to using this type of log proving injection is staying in zone. Thanks; Jose Sota PE -Endicott Field -ACT East BP Exploration (Alaska) Inc. Off: 907 564 5972 Mob: 907 244 0529 1 /20/2009 • ~ ~, :r~4 ~i AI.ASIfA OIL AHD GrAS COHSERQA7'IOPIT C01-II~IIS5IOI~T Jack Lau PE BP Exploration Alaska Inc. • SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 PO Box 196612 ~~~~~~ x;c1~'? ~ '~ ~~G~ Anchorage, AK 99519-6612 Re: Endicott Field, Endicott Oil Pool, 3-01 /N-29 d Sundry Number: 308-391 (, `~ ti~j(~ Dear Mr. Lau: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at {907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~~~i~ Daniel T. Seamount, Jr. Chair l~ ~~~ DATED this =day of November, 2008 Encl. ..~ ~~ , ;; /~ ~ t 1 0 ~~ G STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSIO(~~'aj ~~ APPLICATION FOR SUNDRY APPROV~-L ~n aar. ~~ ~Rn 1. Type of Request: Abandon Suspend Operational shutdown Perforate ~ ~ Waiver ^ Othe ~ Alter casing ^ Repair well ^ Plug Pertorations^ Stimulate ^ Time Extension ^ CONVERT TO Change approved program^ Pull Tubing ^ Perforate New Pool^ Re-enter Suspended Well ^ WATER INJECTOR 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development , Exploratory ^ 186-1900 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-21678-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: 3-01/N-29 Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): ADLO-047502 56 KB ENDICOTT Field / ENDICOTT OIL Pool 11 • PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13050 ~ 10525.91 ~ 12546 10127 11842' 2/12/08 NONE Casing Length Size MD TVD Burst Collapse CONDUCTOR 161' 30" URFACE 161' SURFACE 161' SURFACE 2480' 13-3/8" 68# L-80 URFACE 2480' SURFACE 2478' 4930 2270 INTERMEDIATE 12111' 9-5/8" 47# NT80S URFACE 12111' SURFACE 9774' 6870 4760 LINER 1220' 7" 29# SM-110 11830' 13050' 9459' 10526 11220 8510 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 4-1/2" 12.6# 13CR-80 SURFACE - 11875' Packers and SSSV Type: 9-5/8"X5-1/2" TIW HBBP PKR Packers and SSSV MD (ft): 11738' 12. Attachments: Descriptive Summary Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 11/13/2008 OIL ^ GAS ^ PLUGGED ^ ABANDONED ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^~ WDSPL ^ Commission Representative: Prepared by Gary Preble 564-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact JACK LAU Printed Name ACK U Title P.E. Signature Phone 564-5102 Date 10/30/2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ~ Location Clearance ^ ~ ~ 5~'~ErC l/ ®S \ w 4 C vV`~~~~~ Other: Subsequent Form Required: y ~ `` ~. j ,/ APPROVED BY ~/~ ~~ %/ Approved by: COMMISSIONER THE COMMISSION Date: 'T Form 10-403 Revised 06/2006 c ~ ~ Submit in Duplicate 3-01 /N-29 186-190 PERF ATTArHMENT • Sw Name _ Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 3-01/N-29 8/27/87 PER 12,480. 12,520. 10,074.24 10,106.57 3-01/N-29 8/27/87 PER 12,546. 12,564. 10,127.42 10,141.8 3-01/N-29 8/27/87 PER 12,570. 12,600. 10,146.58 10,170.44 3-01/N-29 5/13/91 APF 12,286. 12,326. 9,915.58 9,948.22 3-01/N-29 5/13/91 APF 12,360. 12,380. 9,976.03 9,992.43 3-01/N-29 5/13/91 APF 12,390. 12,460. 10,000.64 10,057.97 3-01/N-29 6/16/94 SQZ 12,286. 12,326. 9,915.58 9,948.22 3-01/N-29 6/16/94 SQZ 12,360. 12,380. 9,976.03 9,992.43 3-01/N-29 6/16/94 SQZ 12,480. 12,520. 10,074.24 10,106.57 3-01/N-29 6/16/94 SQZ 12,546. 12,564. 10,127.42 10,141.8 3-01/N-29 6/16/94 SQZ 12,570. 12,600. 10,146.58 10,170.44 3-01/N-29 10/11/94 APF 12,304. 12,326. 9,930.26 9,948.22 3-01/N-29 10/11/94 RPF 12,360. 12,380. 9,976.03 9,992.43 3-01/N-29 10/11/94 RPF 12,390. 12,426. 10,000.64 10,030.17 3-01/N-29 5/24/95 SQZ 12,304. 12,326. 9,930.26 9,948.22 3-01/N-29 5/24/95 SQZ 12,360. 12,380. 9,976.03 9,992.43 3-01/N-29 5/24/95 SQZ 12,390. 12,426. 10,000.64 10,030.17 3-01/N-29 5/27/95 RPF 12,360. 12,380. 9,976.03 9,992.43 3-01/N-29 5/31/95 RPF 12,304. 12,324. 9,930.26 9,946.59 3-01/N-29 11/18/95 APF 12,166. 12,167. 9,818.51 9,819.32 3-01/N-29 11/22/95 RPF 12,166. 12,167. 9,818.51 9,819.32 3-01/N-29 _ 9/23/99 RPF 12,286. 12,326. 9,915.58 9,948.22 3-01/N-29 5/28/00 APF 12,151. 12,165. 9,806.46 9,817.71 3-01/N-29 5/28/00 APF 12,168. 12,171. 9,820.12 9,822.53 3-01/N-29 5/28/00 RPF 12,166. 12,167. 9,818.51 9,819.32 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMO VED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • Endicott DIU ~-o1~N-29 (1861A00) Current Status End 3-of/N-2g is a gas lifted oil producer currently shut in due to IAxOA communication to gas. No leaks were located during a subsequent LDL performed on 9/8/07 demonstrating the IAxOA communication is to gas only. In 2/08, both a MITT and MITIA passed to 300o psi and 3500 psi, respectively. The reservoir management plan forward is to convert ENDS-ol to 2A water injection as a replacement for former water injector END3-37. 3-01 will be in compliance with BP internal well integrity policy for operation seeing that the IA passes a MITIA to liquid and will be liquid packed for the duration of water injection operations. Comuletion c (~ In the well of interest, 3-of/N-2g (PTD 1861900), a 7" liner was run to ~°' S~c~ s~\\`~ 13,o5o'MD and hung off at 11,83o'MD. It was cemented with 6g bbls of class G ~2~sS~sc cement with no recorded losses. The g 5/8" production casing was run from surface to 12112'MD and cemented with l02 bbls of class G cement with no ~~ l recorded losses. The completion crossed the Kekiktuk formation at 12,150 MD. ~~ A CET log run 3/4/87 indicates a minimum of 60' of uncontinuous cement behind the 7" liner above the proposed 2A injection interval of 12,642- 12,8oo'MD. The K3A and K2B are perforated and contributing in the current completion of the well. The K2M was perforated but was squeezed in 1994• The K2A has never been perforated and is isolated from the K2M perforations by a 20' thick shale and siltstone. Multiple water shutoff cement squeezes with differing objectives where performed in 1994 and 1995• Subsequent production logs verified the squeezes were successful in the isolating producing intervals and shutting off water ,~ production. In addition, the cement squeezes likely added to the girth of cement behind the 7" liner and attested to the Kekiktuk's ability to be successfully squeezed. Plan Forward• 1) Obtain Sundry for conversion to water injection 2) Obtain Administrative Approval to inject with IAxOA communication to gas. 3) Squeeze existing open perforations with cement from 12,151' to 12,546'MD 4) Contaminate and mill squeezed cement to 12,546' MD 5) Mill existing cement top from 12,546' to 12,815'MD 6) Add perfs to unperfed 2A sands from 12,642-12,8oo'MD 7) Place well on water injection (confirm AOGCC approval prior to injection) 8) AOGCC witnessed MITIA to 2500 psi once injection has stabilized • • Wi3LF~AD = 17' FMC ACTl14TOR= BAKH2 103. 13.E\/ = 58' BF. IiEV = 18.4' KOP= Marc Angls = 50" ~ ' Datum MD = 72458' D~atumND= 1000033 1.80 Bll~'T, ID=12A75" END 3-01 ~ s~ErrNt~s;•"•a.,n-~~IE,~• r_ea r aT aye ar7oo c ST h0 TVD DEV TYPE VLV LATCH PORT DATE 7 3588 3558 22 MiAGAI OMY Fa( 0 17109A7 8 5687 5302 45 ITAGM DRAY RK 0 17/0.9107 5 7358 8337 48 IuM(rY~l DMY RK 0 0&17184 d 8425 7047 48 MIuKa'hl DRAT RK 0 08/17194 3 9474 7784 45 RA1+~M OKAY F8( 0 08/1794 2 10448 8458 42 RAoK~RI DMY RK 0 06!1794 1 91335 9152 37 RTAGM pNY taC 0 0&17184 Minimum ID = 3.725" Q 11863' I I I' 4112" OTIS XN NIPPLE ll Il ,1735' 4-tJrx st/rxo, D= 4112" ftl(3, 12.6A, 13C RAO NSGT, .0752 bof. D = 3.956' S¢E SPF MEINAL OPNSgz LATE 2' 8 72157- 12777 C 05J28A10 2' 1 72188 C 11/2295 Y 8 72288 - 12304 C 09123199 2-78" 4 72288 - 12328 S 0617994 3-318' 6 12304 -12324 C 05!3195 3-318" 4 72304 - 12326 S 0512495 2-ti8' 4 12360 - 72360 S 08!19!94 3-318' 4 12360 - 72360 S 05/2495 2-7t2' 4 12380 - 12380 C 05/2795 3.378' 4 72390 - 72428 S 0512495 2-118" 4 12390 - 12480 S 08!1994 5' 4 #2480-12520 S 0&1994 5' 4 72548 - 72564 S 08/19194 5' 4 72570-12800 S 0811994 Isar x a-ur Xo, D = as56" I 9-&8'X7" BlQ2 Ltii HGR w t&917 TE$IC, D = 8.844" O76 XNNP,D=3. WLEG, D = 3.958" Squeeze needed Proposed 2A add perfs for water injection: 12645-12815' MD Q4TE RE1/ BY COAAMB4~S DATE REV BY OtTS 08/29/87 PA 97 OYTIAL COM PL EfpN 09/24105 tZL/TlN WANER CANCgL® 08/2SJ94 D,S RWO 11119!07 (7TWP.X; GlVC1O 10111!94 JLH P06T SQZ F$7FS 02/20!08 JCRM'RH TTP SET (02112/08) 05/28/95 JTP SDZ 03118A.18 JA5IPJC ODNVERTNtINFq~AAT 1tN8195 TLR ADD7FID1-E FOR (i. 05!28100 DBR ADPERF (3~DI~TI' IAJfT WELL 3-0t J 8129 l~7Mtf No: 1881900 API No: 50.029-21878-00 5~8, T11N, R77~ 2538' FNL 8879' Fa BP Expbretion (A W ka) J • ~ Area of Review -Endicott DIU ~-ol f N-29 (1861A00) Subsequent to the conversion of we113-of/N-2g from producer to water injector an Area of Review (AOR) is obligatory. This AOR will discuss the wells within 1/4 mile of said well's entry point into the Kekiktuk Formation to the bottom of well bore completion. Eight individual well bores enter the AOR of 3-oi at the top of the Kekiktuk to bottom of wellbore completion. The following table illustrates the eight wells within the AOR, their respective distances from 3-oi, and any annulus integrity comments based on an in depth review of each well. y~p~~~~}~ ; g-al/N-29 1861900 S ~c ~a~• .» ~a pia- r. TOC calculated to be above injection zone 3-07 N-28 1890120 1057 P&A, TOC calculated to be above injection zone 3-o7a L-29 1981470 1175 TOC calculated to be above injection zone 3-05 0-29 1861300 1337 TOC calculated to be above injection zone -u/M-3o 1880870 u48 TOC calculated to be above injection zone 3-17b M-gl 1971080 1520 P&A, TOC calculated to be above injection zone 3-17c M-31 1g8o21o 1225 P&A, TOC calculated to be above injection zone 3-17d/M-31 1982080 1008 P&A, TOC calculated to be above injection zone 4-1oa/L-28 2022380 1490 TOC calculated to be above injection zone Figure ~: Wells within AOR ,~~~~ ~~3~ ~~t ~~w tE3~. ~~t~~f _ ". -ol N-2g 7" 8~/z" 69 bbls 12,150' MD 3-07 N-28 8~/z" bbls 12,48 ' MD 3-o7a L-2g 2 7 8" 3/a" 2 bbls ~2, 8' MD 3-05 O-2 7" 8'/z" 100 bbls ii,7 7' MD 3-i1 M- 0 7" 8'/z" 57 bbls 12,6 7' MD -i b M-3i 41/2' 6'~ 39 bbls 12,5 0' MD -i c M-3i Abandoned durin drillin 25 bbls 3-17d M-31 2 7 8" 3/a" 22 bbls X2,668' MD -ioa L-28 41/2" 63/a" 75 bbls 13,208' MD Figure 2: Completion Detail In we113-o5/O-2g (PTD 1861300) a ~" liner was run to 12,'714' MD and hung off at 11,421' MD. The completion crossed the Kekiktuk formation at 11,757' MD. The ~" liner was cemented with loo bbls of class G cement. A cement bond indicated the primary cement job was successful in isolating the receiving zone. ~ • In we113-o~/N-28 (PTD 18go12o) a ~" liner was run to 13,550' MD and hung off at i2,2o~' MD. The completion crossed the Kekiktuk formation at 12,48' MD. The ~" liner was cemented with 73 bbls of class G cement and no losses were noted. A cement bond log ran 3/8/89 indicated good to adequate cement behind the ~" from 13550' to i2,3oo' and fair cement to top of ~" liner lap at 12,211. The well was plugged and abandoned in 1998 with 6 bbls of class G cement placed from TD to 12,968' and sidetracked at 12,go6'. We113-o~A/L-2g (PTD 1981470) was sidetracked from parent we113-o~/N-28 in 1998. A 2-~/8" liner was run to 14995' MD and hung off at 12,o85'MD. The 2- ~/8"liner was cemented with 25 bbls of class G cement and no losses were indicated. In well 3-11/M-3o (PTD 188080) a ~" liner was run to 13,520' MD and hung off at 12,416' MD. The completion crossed the Kekiktuk formation at 12,697' MD. The ~" liner was cemented with 57 bbls of class G cement and no losses were noted. A cement bond log ran 9/x/88 indicated good cement behind the ~" liner over the entire interval of 13,520' to 12,416'. The well was abandoned in 1998 with 6 bbls of class G cement placed from TD to 12,968' and sidetracked, at 12,906'. The wellbore has been abandoned with a cement retainer at 12,954', san ack to 12,60', and class G cement to 12,605' demonstrating zonal isolation. In we113-1~b/M-31 (PTD 1g~1o8o) a 41/2" liner was run to 13,182' MD and hung off at 10,312'. The completion crossed the Kekiktuk formation at i2,59o' MD. The 41/2" liner was cemented with 39 bbls of class G cement and no losses were noted. The well was plugged and abandoned with 14 bbls of class G cement placed from TD to 12,306' and sidetracked at 12,182'. 3-lac/M-31 (PTD 1980210) was sidetracked out of the 41/2" liner in 3-lib/M-31 at 12,182'. It was plug & abandoned during drilling operations with 25 bbls of class G cement demonstrating zonal isolation. Well 3-lid/M-31(PTD 1g82o8o) was sidetracked out of the 41/2" liner in 3- 1~b/M-31 at 11,193'. A 2-~/8" liner was run to 13,o1o'MD and hung off at 10,304'. The completion crossed the Kekiktuk formation at 12,668' MD. The 2-~/8" liner was cemented with 22 bbls of class G cement and no losses were noted. The well was plugged and abandoned with 25 bbls of class G cement demonstrating zonal isolation. TOC at 10,318'MD. We114=1oa/L-28 (PTD 2022380) was sidetracked from parent we114-1o/L-28 in 2003. A 41/2" liner was run to 13,864'MD and hung off at ii,57o'MD. The 41/2" liner was cemented with 75 bbls of class G cement and no losses were indicated. The completion crossed the Kekiktuk formation at 13,208' MD. 1 t7' =;~ __/._ RJ6A_?R - Figure 2: K2A Structure Map ~J 3-t ~~ '~•.~tK-3Q ~~ 14,' 3 ~i ~/ ting AOR .1V`' " "FW: Cancellation of END 3-01 / N-29 RWO Page 1 of 2 • • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, March 18, 2008 1:55 PM To: 'Hubble, Terrie L' Subject: RE: Cancellation of END 3-01 / N-29 RWO Terrie, ~ ~~ ,_ `~~ think this is sufficient. Tom Maunder, PE AOGCC From: Hubble, Terrie L [mailto:Terrie.Hubble@bp.com] p ~"~~~~ ~` Sent: Tuesday, March 18, 2008 12:34 PM Q \~S~ cca~e~ ~~~ To: Maunder, Thomas E (DOA) ~` ~~ Subject: FW: Cancellation of END 3-01 / N-29 RWO ~~ ~~,v~~ Importance: High `~-- ' / ~~ ~ ~~R `~ ~ ~~~~ ~ ~ t~ Hi Tom, We would like to cancel the Approved 10-403 for this well. The planned RWO will not occur at this time. _. , Well Name: END 3-01 / N-29 Permit to Drill #: 186-190 API #: 50-029-21678-00-00 Approval #: 308-059 ~~ Will this be sufficient? Thanks! Terrie From: Chan, Paul (PRA) Sent: Thursday, March 06, 2008 4:49 PM To: Robbins, Brian W. (BAKER OIL TOOLS); Hubble, Terrie L Subject: F1N: Cancellation of END 3-Ol RWO Importance: High FYI Paul Chan workover Engineer BP Alaska/wells Group (907) 564-5254 (907) 440-0183 (cell) 3/18/2008 FW: Cancellation of END 3-01 / N-29 RWO Page 2 of 2 • (907) 564-5510 (fax) From: Soto, Jose A Sent: Thursday, March 06, 2008 4:40 PM To: Reem, David C; END/BAD Area Manager Cc: Chan, Paul (PRA); Worthington, Aras ]; Daring, John D Subject: Cancellation of END 3-Ol RWO Importance: High As per today's meeting outcome with ACT management, it is now official the decision of_not performing the RWO on 3-01. The group is taking a look at most profitable options down the non-rig well work path. Regards, Jose Soto PE -Endicott Field -ACT East BP Exploration (Alaska) Inc. Off: 907 564 5972 Mob: 907 244 0529 3/18/2008 • n,.~ P, P ALASSA OIL ArTiD GAS CO1~TS~RQA7`I011T C011'Il-IISSIOIQ David Reem BP Exploration Alaska, Inc. PO Box 196612 • SARAH PAL/N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Anchorage, AK 99519-6612 ~~ Re: Endicott Field, Endicott Oil Pool, END 3-01 /N-29 Sundry Number: 308-059 ~o~b ~~~~~' FEB ~ 200 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Corrunission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~ Daniel T. Seamount, Jr. Chair S ~' DATED this ~ day of February, 2008 Encl. "-~,~~~S~TATE OF ALASKA -~~~~~~ ry ALASKA OIL AND GAS CONSERVATION COMMI~ N DEB ~ Q Z~~ ~~~ APPLICATI N F ~~`~~ . O OR SUNDRY APPROVALAIaska Qll & Gas ~nnsa Camm~cs~~r~ 20 AAC 25.280 . _ _ ,_ _ _ 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ^ Alter Casing ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 186-190 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21678-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: END 3-01 / N-29 Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 047502 - 56' ~ Endicott Field / Endicott Pool 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured):, 13050 ~ 10526 12546 10127 None None in Len h i e M TVD Burst Colla se Struc ural ondu or 161' 161' 161' Surface 2480' 13-3/8" 2480' 2478' 493 2270 Interm diate 12111' 9-5/8" 12111' 9774' 6870 4760 Pr du i n Liner 1220' 7" 11830' - 13050' 9549' - 10526' 11220 8510 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 12151' - 12380' 9806' - 9992' 4-1/2", 12.6# 13Cr80 11875' Packers and SSSV Type: 9-5/8" x 5-1/2" TIW 'HBBP' packer Packers and SSSV MD (ft): 11738' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Detailed Operations Program ^ Exploratory ®Development ^ Service 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: April 1, 2008 ®Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Paul Chan, 564-5254 Printed Nam avid Reem Title Engineering Team Leader Prepared By Name/Number: Signature ay-`~ Phone 564-5743 Date 2~2p p Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: - Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity ,(-BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: ~`,~~5~ ~ \ "~ S`t ~-S p`G~t~r~ 1 Subsequent Form Required: ~.-~~ ~ ~ APPROVED BY A ~° ~- ~ roved B : COMMISSIONER THE COMMISSION Date Form 10-403 Re~eddit~ ~ Submit In Duplicate ORIGINAL ~~ - :t_ ~ ~~~ ~ ~~a~ ~~ ~~ bP r~ _ ~'; Endicott 3-01 /N-29 Rig Workover • Scope of Work: Expense RWO. Pull 4-'/2" completion, mill and retrieve TIW HBBP packer, run and cement 4-1/2" scab liner inside 7" production liner, run USIT log, cut and pull 9-5/8" casing, run and cement to surface new 9-5/8" casing, and run 4-'h" 13Cr-80 completion. MASP: 3427 psi Well Type: Producer Estimated Start Date: April 1, 2008 Production Engineer: Jose Soto InterventionEngineer: Paul Chan Pre-ri re work: S 1 Drift 4-1/2" tubing to the tailpipe in preparation for setting the plug and the jet cut. Set XXN lu at 11863' MD. E 2 CMIT T x IA to 3500 psi. Power jet cut 4-~/z" 13CR-80 tubing at 11685' MD, in the middle of the first full ~oint above the TIW HBBP acker. Reference tubin tall dated 08/17/94. F 3 Circulate well with kill wei ht fluid and diesel thru the cut. .MIT-OA to 2000 si. W 4 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaka a check one at a time . PPPOT-T & IC. O 5 Set a BPV in the tubin han er. O 6 Remove the wellhouse & flow line. Level the ad as needed for the ri . Proposed Procedure 1. MIRU. ND tree. NU and test BOPE to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Pull and LD 4-~h" tubing string to the cut. 3. Mill and retrieve the TIW HBBP packer. 4. Run USIT log from 2500' to 11830' MD. ~lS~~s," Lint ~~ ~~~ ~ (~ ~ 5. Cleanout 7" liner to 12960' MD 6. Run and cement 4-1 /2" scab liner from11800' to 12960' MD. ~~.ovrc ry '~~~ \ ~ ~Qr~ `\ 7. Cut and pull 9-5/8" casing from above the top of cement. Note: Pipe rams will not be change too ~ ~;~ ~ 9-5/8" as the well has two tested barriers (Newly cemented 4-1/2" scab liner and RBP) to the ~ ~~ Za\ reservoir. ~A , 8. Run and cement to surface 9-5/8" casing. /~11 9. Run 4-1h" 13Cr-80 completion with Baker S-3 packer. Set packer at 11690' MD. ~(,y, 10. Displace the IA to packer fluid and set the packer. 11. Test tubing and IA to 3360 psi. Freeze protect to 200' MD. 12. Set BPV. ND BOPE. NU and test tree. RDMO. • Note: Doyon 16 will be using a 4 preventer "drilling" stack configuration (reference PBU Well V-212, PTD: 205150) TREE= 4-1/16" CIW WELLHEAD= 11' FMC • ACTUATOR= BAKER KB. ELEV = 56' I BF. ELEV.- 16.4' KOP Max Angle= 50° @ 8080' Datum MD = 12458' Datum TV D = 10000 SS 30" CONDUCTOR ID = ? 106' 13-3/8" CSG, 68#, L-80 BUTT, ID = 12.415" 2480' 9-5/8" CSG, 47#, NT80S XO NT95HS 10304' Minimum ID = 3.725" @ 11863' 4-1 /2" OTIS XN NIPPLE TOP OF 7" LNR 4-1/2" TBG, 12.6#, 13CR-80 NSCT, .0152 bpf, ID = 3.958" 9-5/8" CSG, 47#, NT95HS, ID = 8.681" i 12112' PERFORATION SUMMARY REF LOG: DLL-GR ON 01/21/87 ANGLE AT TOP PERF: 36° @ 12151' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 12151 - 12171 O 05/28/00 2" 1 12166 O 11/22/95 2" 6 12286 - 12304 O 09/23/99 2-1/8" 4 12286 - 12326 S 06/19/94 3-3/8" 6 12304 - 12324 O 05/31 /95 3-3/8" 4 12304 - 12326 S 05/24/95 2-1/8" 4 12360 - 12380 S 06/19/94 3-3/8" 4 12360 - 12380 S 05/24/95 2-1/2" 4 12360-12380 O 05/27/95 3-3/8" 4 12390-12426 S 05/24/95 2-1/8" 4 .12390 - 12460 S 06/19/94 5" 4 12480 - 12520 S 06/19/94 5" 4 12546 - 12564 S 06/19/94 5" 4 12570 - 12600 S 06!19/94 7" LNR, 29#, SM-110 BUTT, .0371 bpf, ID = 6.184" H 13050' END 3 -O ~ S NOTES: ***4-1 /2" CHROME TBG'*" 1516 -i4-1l2" OTIS HXO SSSV LANDING NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 7 3588 3556 22 MMGM DMY RK 0 11/09/07 6 5881 5302 45 MMGM DMY RK 0 11/09/07 5 7358 6337 46 MMGM DMY RK 0 08/17/94 4 8425 7047 48 MMGM DMY RK 0 08/17/94 3 9474 7764 45 MMGM DMY RK 0 08/17/94 2 10448 8458 42 MMGM DMY RK 0 08/17/94 1 11335 9152 37 MMGM DMY RK 0 08/17/94 11715' ~ 4-1 /2" OTIS X NIP, ID = 3.813" I 11735 4-1/2" X 5-1/2" XO, ID = 3.958" 11738' 9-5/8" X 5-1/2" TNV HBBP PKR, ID = 4.750" 11743' 5-1/2" X 4-1/2" XO, ID = 3.958" 11830' 9-5/8" X 7" BKR LNR HGR w /6-1 /2' TIEBK, ID = 6.844" 11842' 4-1/2" OTIS X NIP, ID = 3.813" 11863' 4-1l2" OTIS XN NIP, ID = 3.725" 11875 4-1/2" WLEG, ID = 3.958" ELMD NOT LOGGED 12546' 1 PBTD -POST SOZ 12630' 7" MARKERJOINT 12926 PBTD DATE REV BY COMMENTS DATE REV BY COMMENTS 08/29/87 PA #7 INITIAL COMPLETION 09/24/05 QL/TLH WAVER CANCELLED 08/25/94 D15 RWO 11/19/07 DTR/PJC GLV GO 10/11/94 JLH POST SCZ PERFS 02/12/08 ?/ PJC CONVERT TO NEW FORMAT 05/29/95 JTP SOZ 11/18/95 TLR ADD 1 HOLE FOR GL 05/28/00 DBR ADPERF END~OTT UNIT WELL: 3-01 / N-29 PERMIT No: 1861900 API No: 50-029-21678-00 SEC 8, T11 N, R17E, 2536' FNL i£ 879' FEL BP 6cploration (Alaska) TREE: 4-1/16" / 5000 CIW WELLHEAD: 11" / 500tMC Hydril-563 Casing Fully Cemented L- 80, BTRS. CSG 2,480' HES"HXO"SSSV O NIPPLE 1,500' (3.813" MIN. ID) W/SSSV MIN I.D. is 2" GAS LIFT MANDRELS END 3-01 Proposed~prkover MIN ID = 3.725" JEWELRY TYPE _ "XN" Nipple NT80S XO TO 10,304' NT95HS ~ TOP OF 11,830' 7" LINER 9-5/8", 47#/ft, 12,112' NT95HS, PERFORATION SUMMARY REF LOG: DLL-GR(01/21/87) ANGLE AT TOP PERF: Note: Refer to Production DB for historical pert data SQE SPF INTERVAL "* DATE 2" 1 HOLE @ 12166 O 5" 4 12480 - 12520 S 12546 - 12564 S 12570 - 12600 S 2-1/8" 4 12286 - 12326 S 4 12360 - 12380 S 4 12390 - 12460 S 3-3/8" 4 12304 - 12326 S 4 12360 - 12380 S 4 12390 - 12426 O 3-3/8" 4 12304 - 12324 O 2-1/2" 4 12360 - 12380 O 2" 6 12286 - 12304 O 2" 6 12151 - 12171 O '"' KEY: O = OPt3N / G = CLOS®/ SOZ=SQUEFZm 4-1/2" 12.6 #/ft, 13Cr-80 Fully -~ Cemented Scab Liner PBTD -12, 900' 7" - 29 #/ft, SM-110, 13, 050' -~ BTRS ST MD GLMx VALVE 5 - 4-1/2" x 1-1/2" 4 - 4-1/2" x 1-1/2" 3 - 4-1/2" x 1-1/2" 2 - 4-1/2" x 1-1/2" 1 - 4-1/2" x 1-1/2" 4-1/2" "X"NIPPLE 3.813" ID 9-5/8" x 4-1/2" PACKER 11,690' (BAKER "S-3" 3.875" ID) 4-1/2" "X" NIPPLE (3.813" ID) 4-1/2" "XN" NIPPLE (3.725" ID) 4-1/2" WLEG DATE REV BY COMMENTS DATE REV BY COMMENTS 10/11!94 JLH POST SOZ PERFS 05/29/95 JTP SOZ 11/18/95 TLR ADD 1 HOLE FOR GL 05/28!00 DBR ADPERF 09/24/05 EZL/TLH WANERCANCELLED ENDICOTT UNff WELL: 3-01 / N-29 PERMIT No: ?? API No: 50-029-21678-00 SEC T N R E BP Exploration (Alaska) 07/13/2005 16:31 TEL 8076586533 ') 141001/001 ) 011 and/or Gas Release Reporting Require~~nts - APPENDIX Page 1 I?f ~_ BP Exploration (Alaska) Inc. P.O. Box 196612, Anchorage, AK 99519-6612 REPORT OF ACCIDENTAL GAS RELEASE (S-day and 30-day report) i""·,~ i'~$¿:1.=t~,~ To: ACT Tom Maunder, Senior Petroleum Engineer Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage. AK 99501 Cc: Jim Regg Ph: (907) 279-1433 Jim_regg@Admin.State.AK.us GPB Ms. Cammy Taylor . Alaska Oil and Gas Conservation Commission 333 W _ 7'1'1 Ave., Suite 100 Anchorage. AK 99501 " " . 'QJ" '. i~"'L " ,;,~~('" ~~~~','~, . "",~, ,~it..., , I:¡~ '" ~~ .,~, '~~(Ö) Date= \ l6~ .. ~qo Fax: 276-7542 DESCRIPTION OF INCIDENT 1. Date and Time: 2. Location: _Prudhoe Bay Unit _X_Endicott _Milne Point _Badami _Northstar _Other '-3'. Vo~ume of natural gas lost: 4. Cause of loss: 5. Actions taken and planned to prevef1t further loss: 6. Equipment or procedural changes to prevent loss from recurrinQ: 7. Contact (Name and telephone number): July 9, 2005 9:30am Detailed Locatíon Endicott Well 3-01 18117 set Packing failure .. Rigged up emergency bleed off into tank; repairs planned during upcoming ~hutdown _ Valve actuatór to be disassembled and examined for further info SjQ!:1~ture: Qa0lvi ley, ..BP EnVironm~n,tal 907-670-338? ~ Cy-- L ~ U ,u;¿./r.. ~ BPX Environmental Manager MB 2-6 (Fax: 564-5020) BPX Volume Accounting MB 12·4 (Fax: 564-4094) Endicott Ops Support Technical Assistant GPB Operations Manager, PRS 10 Production Optimization Team Leader, PRB 6 cc: SCANNEC JUL 2 2. 2005 STATE OF ALASKA Al~.t~ OIL AND GAS CONSERVATION COMMiSSI~ ~ REPORT L. SUNDRY WELL OP,....IATIONS 1. Operations performed: Operation shutdown __ Stimulate__ Plugging__ Pull tubing__ Alter casing __ Repair well __ Perforate X Other~ 2. Name of Operator BP Exlaloration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchora.cTe, Alaska 99519-6612 4. Location of well at surface 2535' SNL, 878' WEL, Sec. 8, T11N, R 17E At top of productive interval 1742' SNL, 2434' WEL, Sec. 5, T11N, R17E At effective depth 1500' SNL, 2402' WEL, Sec. 5, T11N, R17E At total depth 1546' SNL, 2396' WEL, Sec. 5. T11N, R17E 5. Type of Well: Development .. Exploratory ~ Stratigraphic __ Service ~ 6. Datum elevation (DF or KB) KBE = 55.34 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 3-01/N-29 SDI 9. Permit number/approval number 86-190/not re~uired 10. APl number 50- O29-21678 11. Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 13050 feet 10525 BKB feet 12960 feet 10453 BKB feet Plugs (measured) Junk (measured) ORIGINAL Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth BKB BKB 122' 30" Driven 161' 161' 2441' 13 3/8" 3534 c.f. Permafrost 2480' 2477' 12073' 9 5/8" 575 c.f. Class G 12112' 9774' 1220' 7" 387 c.f. Class G 11830'- 13050' 9548'- 10525' measured 12151-12171'(Open), 12286'- 12304' (Squeezed), 12304'- 12326'(OPen), 12360'- 12380'(Open), 12390'- 12426', 12426' -12460', 12480'- 12520', 12546'- 12564', 12570'- 12600'(all squeezed) true vertical (Subsea) 9750'-9762' (Open), 9860'- 9874' (Squeezed), 9874'- 9892'(Open), 9920'- 9936'(Open), 9945'- 9974', 9974'- 10002', 10018'- 10051', 10071'- 10086', 10091'- 10114' (all squeezed) Tubing (size, grade, and measured depth) 4 1/2" 12.6#, 13CR80 to 11875' MD Packers and SSSV (type and measured depth) 9 5/8" TIW HBBP packer at 11,738'; 4 1/2" HXO SVLN at 1516' MD 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 390 300 6103 0 64 49 6346 0 Tubing Pressure 4O2 422 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil × Gas__ Suspended m Service 17. I hereby certify that the, foregoing is true and correct to the best of my knowledge. I~--, Signed ~ [~ (~.~,~d~ Title Senior T~_chnic~l Assi.qt:~nt IV 1'~;6,~-~;2:~,~) Date $150188, Form 10-404 Rev 0(~05/88 SUBMIT IN DUPLICATE'"'-~ :'1'o: END Wells Team .... ;rvisor I tion: Endicott From: Sean Petersen 5/28/00 Well: Endicott 3-01/N-29 Cost Code: N12301-120 Job Id: Detail Code: CS/ADD PERF/ELINE Operation: Add Perforations Summary 5/28 - RU SWS 2158. Safety meeting, PT lubricator and RIH. At 12,205' PUll at 50 fpm and tie in to SWS DLUMSFL dated 1/21/87. Continue to log up through jewelry. RIH to 12,225' and PUH to shooting depth of 12,145.5' (CCL to top shot is 5.5'). Verify on depth while PUH. CCL located at 12,145.5' - perforations shot from 12,151' to 12,171'. PUH to 12,023' logging at 35 fpm and RIH logging at 80 fpm to 12,191'. PUH at 30 fpm and watch CCL - indicates perforations were successful. POH. At surface RD SWS 2158 - verified all shots fired. Call Endicott Wells Team Supervisor to have Operations POP well. Perforation Gun Information: 20' perforating gun, 2" PowerJet, 6 spf, 60 degree phasing, random orientation. Charge Data: 2" PJ 2006, HMX, 0.20" EH, 18.6" PENE Estimated Cost: $16,000 Initial Well Status Siwhp psi I lap psi 350 I 1150 1000 I - Oap psi ] Olp psi I I FIp Fit psi °F . TimeI Operation 0800 RU SWS 2158 0900 Safety meeting, PT lubricator and RIH 0937 Pick up weight is 960 lbs at 7000'. RIH 0942 Pick up weight is 1120 lbs at 9000'. RIH 0954 Pick up weight is 1500 lbs at 11500'. RIH 1000 12203' - PUH and log at 50 fpm to tie in to SWS DLL/MSFL dated 1/21/87 1004 WHp = 600 psig. On depth - logging up through jewelry 1011 11664'- finished logging jewelry. RIH 1013 CCL to top shot is 5.5'. Need to locate CCL @ 12145.5' 1015 At 12225', PUH to 12145.5' 1018 CCL at 12145.5'. Verified on depth while PUH. Perforations shot between 12151'- 12171' 1020 See loss in tension. PUH logging at 35 fpm. 1021 12023'. RIHIogging at80fpm. 1024 12191'. Stop log down. PUH logging at 30 fpm- looks like shots were fired based on CCL. 1027 Stop log and POH 1032 WHp = 625 psig, IA = 1100 psig, OA = 1000 psig 1110 Atsurface, RD2158. 1117 Verify shots fired 1130 Call Endicott Wells Team Supervisor - perforating complete and Endicott operator to POP well Final Well Status Siwhp lap 0ap GIp FIp Fit psi psi psi psi psi °F SI 700 1150 940 - 000528 3-01 Add Perfs.doc Page 1 of 2 *-~Vell: END 3-01/N-29 Operation: Add Perforations SWS Perforating Assembly ~Tool String Descriptions MH-22 EQF-43 PGGT-A AH-SAFE SAFE SHM GUN Bottom Hole Assembly # 1 O.D. I.D. Length Comments i , Maximum 1.6' Diameter 6.0' is 6.4" 2.00" 1.3" 21.7' Total Length 37.0' 000528 3-01 Add Perfs.doc Page 2 of 2 STATE OF ALASKA AL~;.,, ~ OIL AND GAS CONSERVATION COMMISSIO~ REPORT OF SUNDRY WELL OPERATIONS 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, Anchorage, Alaska 99519-6612 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 2535' SNL, 878' WEL, Sec. 8, T11N, R17E At top of productive interval 1742' SNL, 2434' WEL, Sec. 5, T11N, R 17E At effective depth 1500' SNL, 2402' WEL, Sec. 5, T11N, R17E At total depth 1546' SNL, 2396' WEL, Sec. 5, T11N, R17E ORIGINAL 12. Present well condition summary Total depth: measured true vertical 13050 feet 10525 BKB feet Plugs (measured) 6. Datum elevation (DF or KB) KBE = 55.34 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 3-01/N-29 SDI 9. Permit number/approval number 86-190/not required 10. APl number 50- 029-21678 11. Field/Pool Endicott Off Pool Effective depth: measured true vertical 12960 feet 10453 BKB feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth BKB BKB 122' 30" Driven 161' 161' 2441' 13 3/8" 3534 c.f. Permafrost 2480' 2477' 12073' 9 5/8" 575 c.f. Class G 12112' 9774' Tubing (size, grade, and measured depth) 1220' 7" 387c. f. Class G 11830'-13050' 9548'-10525' measured 12166',(Open), 12286'- 12304' (Squeezed), 12304'- 12326'(Open), 12360'- 1238,0'(Open), ~ 12390 - 12426', 12426'-12460', 12480'- 12520', 12546'- 12564', 12570'- 12600 (all squeezed) true vertical (Subsea) 9763' (Open), 9860'- 9874' (Squeezed), 9874'- 9892'(Open), 9920'- 9936'(Open), 9945'-9974', 9974'- 10002', 10018'- 10051', 10071'- 10086', 10091'- 10114'(all squeezed) 4 1/2" 12.6#, 13CR80 to 11875' MD Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary 9 5/8" TIW HBBP packerat 11,738'; 4 1/2" HXO SVLN at 1516' MD '-- ~---.~ ..,~ .', Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 425 0 1507 0 315 Subsequent to operation 215 1078 3688 0 399 15. Attachments I 16. Status of well classification as: Copies of Logs and Surveys run __ I Daily Report of Well Operations X Oil X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed (~_Z~/"&~, r-~' /~~'~ TitleSeniorTechnicalAssistantll Form 10-~;)4 Rev 06/15/88 ' Service Date /~'/~///~' ~ SUBMIT IN DUPL/ICATE Endicott Production Engineering Department DATE' WELL N-°: 3-01 / N-29 BP EXPLORATION REP: Addition of a Single Perf (1 I 1/1 8/95 hole for all Mankind) THOMAS RUT SERVICE COMPANY: ATLAS (Ken Brunner, Johnny, Strubel) ,, DATE/TIME OPERATIONS SUMMARY , ] 11/18 0800 MIRU ATLAS. OAP = 240 PSI; lAP = 220 PSI; FWHT = 136° F; CHK = 176 BEANS; FWHP = 320 PSI. . .... 0930 ARM GUN & PRESSURE TEST LUBRICATOR TO SIWHP. RIH WITH GUN #1 (1 FOOT). SIWHP = 575 PSI. 1030 LOG TIE-IN STRIP UP WITH WELL SHUT-IN. DO NOT WANT TO RISK GE-I-I'ING A STRONG GAS JET AS OBJECTIVE IS TO ONLY ADD 1 GAS LIFT HOLE. NOTE: TIED-IN WITH 1/21/87 DLL/MSFL & OVERLAYED WITH 1/26/87 CBT. 1035 LOG A CONFIRMATION PASS. 1040 LOG UP TO TOP & ONLY SHOT AT 12166' MD. FIRE GUN. SAW GOOD CURRENT INDICATION BUT NO WEIGHT CHANGE (TINY GUN!). LOG UP 3 COLLARS AND POOH. 111 5 AT SURFACE. CLOSE SWAB, BLEED LUBRICATOR, & LOWER GUN. OUR SOLO SHOT HAS BEEN FIRED. 1130 POP WELL & REQUEST WELL TEST FROM CONTROL ROOM OPERATORS. PERFORATION SUMMARY: GUN DLL DEPTH FEET SUBZONE I 12166' I HOLE 3B OUR HOLE WAS SHOT WITH A 2" HSC ALPHA-JET AT 0© ORIENTATION (SHOT'TOP SIDE OF HOLE), 6.5 GM CHARGE, EHD = 0.28", PEN = 12.2". THE OBJECTIVE OF THIS SOLO HOLE WAS TO SHOOT A GAS ZONE IN THE 3B TO PROVIDE NATURAL FORMATION GAS, GAS LIFT. IT HAS BEEN DESIGNED TO PASS NO MORE THAN 3 MMSCFPD UNTIL THE HOLE MIGHT ERODE. A CASING LEAK ABOVE THE PACKER PREVENTS USING CONVENTIONAL MEANS. LET'S HOPE IT WORKS! Endicott Production Engineering Department , DATE: WELL N-°: 3-01 / N-29 BP EXPLORATION REP: SERVICE COMPANY: Addition of a Single Perf (1 1 1/21-22/95 hole for all Mankind) THOMAS RUT ATLAS (WAYNE #1, KEN & CREW #2) DATE/TIME OPERATIONS SUMMARY ' " #1 11/21 1700 MIRU ATLAS. CAP = 220 PSI; lAP = 200 PSI; SIWHP = 500 PSI. WELL SI AFTEiR CAMCO PULLED SSSV PRIOR TO RU. 1830 ARM GUN & PRESSURE TEST LUBRICATOR TO SIWHP. RIH WITH GUN #1 (1 FOOT). 1900 CAN'T DROP BELOW 7100' MD. YO-YO, RIH FAST, SLOW, ETC. POOH TO LUBRICATOR. CLOSE SWAB & FLOW WELL. 2015 RIH AGAIN. THIS TIME HIT TAR BALL AT 5300' MD. CAN'T DROP THRU. POOH. 2100 AT SURFACE. DECIDE TO RDMO ATLAS & FLOW WELL OVERNIGHT TO SEE IF WE CAN FLOAT THICK OIL TO SURFACE. #2 11/22 1230 MIRUATLAS. OAP=220PSI; IAP=190 PSI; FWHP=270PSI; FWHT=80°F; CHOKE = 176 BEANS. THE WELL NEVER WARMED UP ABOVE 85° F OVERNIGHT ACCORDING TO TRENDS ON DCS. WILL LOAD UP WITH 4 WEIGHT BARS, ELIMINATE MAGNETIC DECENTRALIZER, & HOPE FOR BEST! 1430 SHUT-IN WELL & RIH. SlWHP = 330 PSI. 1600 LOG TIE-IN STRIP up'WITH WELL SHUT-IN. DO NOT WANT TO RISK GE'I-TING A STRONG GAS JET AS OBJECTIVE IS TO ONLY ADD 1 GAS LIFT HOLE. NOTE: TIED-IN WITH 1/21/87 DLL/MSFL & OVERLAYED WITH 1/26/87 CBT. 1620 LOG A CONFIRMATION PASS. 1630 LOG UP TO TOP & ONLY SHOT AT 12166' MD. FIRE GUN. SAW GOOD CURRENT INDICATION AND ~30 LBS WEIGHT GAIN. LOG UP 3 COLLARS AND POOH. 1710 AT SURFACE. CLOSE SWAB, BLEED LUBRICATOR, & LOWER GUN. OUR "' SOLO SHOT HAS BEEN FIRED. , , 1830 RDMO ATLAS. 1900 POP WELL & REQUEST WELL TEST FROM CONTROL ROOM OPERATORS. PERFORATION SUMMARY: GUN DLL DEPTH FEET SUBZONE I 12166' I HOLE 3B OUR HOLE WAS SHOT WITH A 2" HSC ALPHA-JET AT 180° ORIENTATION (SHOT LOW SIDE OF HOLE), 6.5 GM CHARGE, EHD = 0.28", PEN = 12.2". THIS JOB NOW ADDS 2 HOLES AT 12166' MD (ONE ON THE HIGH SIDE FROM 1ST ATTEMPT, NOW 1 ON THE LOW SIDE FOR BETTER PENETRATION). LARRY GRANT ~' Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCH©P~AGE Al{, 99501. Date: 28 November 1995 RE: Transmittal of Data Sen~ by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL 2-48/O-13 PH DESCRIPTION -1-PFC/PERF FINAL BL+RF 1 PDK FINAL BL+RF 1 ZDL/CN FINAL BL+RF 1 DIFL FINAL BL+RF 1 BH PRO FINAL BL+RF 1 SSVD FINAL BL+RF ECC No. Run # 1 5756.08 Run # 1 6185.13 Run # 1 Run # 1 Run # 1 Run ~ 1 6530.00 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 ~ ~AX to (907) 563-7803 Received ~/~p~~~~ Date: RECEIVED DEC 1 4 1995 Alaska Oil & Gas Cons. Commissior Anchorage LARRY GRANT ' Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 21 November 1995 Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL i PLS FINAL BL+RF ECC No. Run # 1 2628.11 Run ~ ! 5756.07 Run # 1 6192.10 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 D~e~k~ · ' 0 Received by: STATE OF ALASKA ALA~,~ OIL AND GAS CONSERVATION COMMISSION ' REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate__ Plugging__ Pull tubing__ Alter casing __ Repair well __ Perforate__ Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2535' SNL, 878' WEL, Sec. 8, T11N, R17E At top of productive interval 1742' SNL, 2434' WEL, Sec. 5, T11N, R17E At effective depth 1500' SNL, 2402' WEL, Sec. 5, T11N, R17E At total depth 1546' SNL, 2396' WEL, Sec. 5, T11N, R17E 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 55.34 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 3-01/N-29 SDI 9. Permit number/approval number 86-190inet required 10. APl number 50- 029-21678 11. Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: true vertical measu red true vertical Length 13050 feet Plugs (measured) 10525 BKB feet 12960 feet Junk (measured) 10453 BKB feet Size Cemented Measured depth A!'t';h~r~vertical depth BKB BKB 122' 30" Driven 161' 161' 2441' 13 3/8" 3534 c.f. Permafrost 2480' 2477' 12073' 9 5/8" 575 c.f. Class G 12112' 9774' 1220' 7" 387 c.f. Class G 11830'- 13050' 9548'- 10525' measured 12286'- 12304' (Squeezed), 12304'- 12326', 12360'- 12380', 12390'- 12426' (ail open), 12426' -12460', 12480'- 12520', 12546'- 12564', 12570'- 12600' (ail squeezed) true vertical (Subsea) 9860' - 9874' (Squeezed), 9874'- 9892', 9920' - 9936', 9945' - 9974' (Afl open), 9974' - 10002', 10018'- 10051', 10071'- 10086', 10091' - 10114' (ail squeezed) Tubing (size, grade, and measured depth) 4 1/2" 12.6#, 13CR80 to 11875'MD Packers and SSSV (type and measured depth) 9 5/8" TIW HBBP packer at 11, 738'; 4 1/2" HXO SVLN at 1516' MD 13. Stimulation or cement squeeze summary Scale Inhibitor Squeeze 9/23/95 Intervals treated (measured) 12304'- 12326', 12360'- 12380', 12390'- 12426' Treatment description including volumes used and final pressure 177 Bbls seawater/scale inhibitor mix, 412 Bbls seawater/2% surfactant, 196 Bbls seawater tubing volume FSlWHP = 450 psia 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 112 952 2182 0 301 Subsequent to operation 134 36 1537 0 307 15. Attachments I 16. Status of well classification as: Copies of Logs and Surveys run __ I Daily Report of Well Operations __ Oil X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~.~/?.v,'t..F-~ %,~-,. ,~-~' Title Senior Technical Ass istantll Form 107~ Rev 06/15/88 Service Date ,/ r SUBMIT IN DU/PLI~ATE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate Plugging__ Pull tubing Alter casing Repair well __ Perforate X Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2535' SNL, 878' WEL, Sec. 8, T11N, R17E At top of productive interval 1742'SNL, 2434' WEL, Sec. 5, T11N, R17E At effective depth 1500' SNL, 2402' WEL, Sec. 5, T11N, R17E At total depth 1546' SNL, 2396' WEL, Sec. 5, T11N, R17E 5. Type of Well: Development Exploratory Stratigraphic Service Datum elevation (DF or KB) KBE = 55.34 feet Unit or Property name Duck Island Unit/Endicott 8. Well number 3-01/N-29 SDI 9. Permit number/approval number 86-190~not required 10. APl number 50- 029-21678 11. Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: true vertical measured true vertical Length 13050 feet Plugs(measured) RECI iV£D 10525 BKB feet 12960 feet Junk (measured) JUL 'i 8 995 10453 BKB feet · At,sku, 0ii & Gas Cons. Commission Size Cemented r~e~sured'deptltl~ch0~'; ,' True vertical depth BKB BKB 122' 30" Driven 161' 161' 2441' 13 3/8" 3534 c.f. Permafrost 2480' 2477' 12073' 9 5/8" 575 c.f. Class G 12112' 9774' 1220' 7" 387c. f. C/ass G 11830'-13050' 9548'-10525' measured 12286'- 12304' (Squeezed), 12304'- 12326', 12360'- 12380', 12390'- 12426' (all open), 12426' -12460', 12480'- 12520', 12546'- 12564', 12570'- 12600' (al/squeezed) true vertical (Subsea) 9860'- 9874' (Squeezed), 9874'- 9892', 9920'- 9936', 9945' - 9974' (All open), 9974'- 10002', 10018'- 10051', 10071'- 10086', 10091'- 10114'(al/squeezed) Tubing (size, grade, and measured depth) 4 1/2" 12.6#, 13CR80 to 11875'MD Packers and SSSV (type and measured depth) 9 5/8" TIW HBBP packer at 11, 738'; 4 1/2" HXO SVLN at 1516' MD 13. Stimulation or cement squeeze summary Water shut off coiled tubing cement squeeze #1 and 2 (5/23-24/95), post squeeze perforations (5/27/95) and more post squeeze perforations (5/31/95). Intervals treated (measured) 12286'-12326', 12360'-12380', 12390'-12460', 12480'-12520', 12546'-12564', 12570'-12600' Treatment description including volumes used and final pressure See attachments Squeeze #1 FBSlP ..- 380 Squeeze #2 FBSlP = 2060 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 452 556 4571 O0 275 ~ 223 2479 0 Tubing Pressure 584 3O3 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations × 16. Status of well classification as: Oil X Gas, Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~lned ~,~-~..., ~ ~ Title Senior Technical Assistant ll Date SUBMIT IN DUPLICATE "' Form 10~:~ Rev 06/15/88 Well: 3-01 Operation: WSO #4 & 5 Date: 5/23-24/95 (ft) (BPM) (psi) (psi) I VOL INOZZLE RETURN REMARKS SUMMARY Squeeze #1 (grand total is 4): Well has been recently jetted clean with coil. Bullhead killed with 320 bbl SW. Saw a 40 psi increase when SW reached the perfs, otherwise injectivity was stable. Pumped 27 bb115% HCI with 10 % Xylene. Injectivity increased from 1 bpm at 510 psi to 2.1 bpm at 570 psi. Laid in 17 bbl of cement, and ramped up pressure to 3000 psi in 30 minutes. Held squeeze pressure, and LRO'd down to 12,545'. Squeeze appeared to start leaking while reversing out across the lower perfs 12,390 -12,426. Camco's pressure line froze up at the same time, so hard to tell exactly what was going on. Pressure increased briefly to 3800 psi before we realized the pressure indications were bad, but the densiometer suggested that the leak preceeded the pressure increase. Observed injectivity of 0.25 bpm at about 1800 psi. Suspected that we had damaged some nodes during the reverse out. Compledted jet passes and final reverse out. Discussed with well operations supervisor, and planned for an immediate resqueeze. Squeeze #2 (grand total is 5): Post squeeze PT to 2000 bled 120 psi/3 min. Underbalanced w/N2 to approx 2000' (approx 900 psi underbalanced). Surged down the flowline for 30 min. Re-fluid packed. 2000 psi PT bled 460 psi/5 min. No injectivity. Pumped 10 bbls acid with nzl parked at lower perfs. Pressure break occurred with 1 bbl acid out (leak at lower perfs). Overdisplaced with 20 bbls. Final injectivity was 1 BPM/800 psi. Pumped 12 bbls cement, closing chokes as soon as lower perfs covered. Ramped to 3000 psi in 4 minutes. Less than 1 bbl cement put behind pipe. 3000 psi PT bled 80 psi/25 min. Held final squeeze pressure for 35 min. LRO to 12535'. Hung up briefly in a node at 12315'. (Didn't see the node during any other passes). Recovered 10 bbls cement. 1900 psi PT was JFT. Trace additional cement recovered after final jet passes. Underbalanced w/N2 to approx 3000', 1300 psi underbalanced based on 4800 formation pressure (SIWHP = 380). Saw liquid level at 3400 ft while POOH. (6 bbl fallout will leave the final level at about 3000 ft). Note: Recent production logs indicate that the old squeeze perfs are holding. There have been three previous squeezes on this well. CEMENT SUMMARY SQZ I I I (grand total is 4) 15.8 ppg Class "G" cement including .. Lab thickening time: 7 hrs, 0 min @ 170 BHCT 0.47 % FL-33 Lab fluid loss: 50 CC 0.1% CD-32 Field fluid loss: 51 CC 0.38 % R-11 Live cell loss: 94 CC I gHS FP-6L LC loss extrapolated to end of 94 CC reverse out Lab APl filter cake: 22 mm 17 BBL pumped Field APl filter cake: 22 mm 13 BBL recovered Live cell cake 80 mm (not extrapIoated): RECEIVED 1995 0il & Gas Cons, Commission Well: 3-01 Operation: WSO #4 & 5 Date: 5/23-24/95 (ft) (BPM) (psi) (psi) I VOL INOZZLE RETURN BBLS I REMARKS CEMENT SUMMARY SQZ 2 I I (grand total is 5) 15.8 ppg Class "G" cement including Lab thickening time: 7 hrs, 0 min @ 170 BHCT 0.47 % FL-33 Lab fluid loss: 50 CC 0.1% CD:32 Field fluid loss: 51 CC 0.38 % R-11 Live cell loss: 38 CC (froze up) ,, 1 gHS FP-6L LC loss extrapolated to end of N/A reverse out Lab APl filter cake: 22 mm ,, ,, 12 BBL pumped Field APl filter cake: 22 mm 10 BBL recovered Live cell cake 33 mm (not extraploated): Cost Code: N10301 Tag: Tagged at 12,575 CTD. Left bottom at 12,535 FLUIDS PUMPED BBLS. DESCRIPTION 320 Bullhead Sea Water 222 SW Circulate Sump, rtns to surface. 27 15 % HCI with 10 % Xylene 70 SW Overflush Acid and Displace Coil 18 Effluent Water (Preflush) 17 Class "G" Cement ) 18 Effluent Water (Postflush) 31 Sea Water (Displacement) ' 605 Sea Water (Jettin~l and Reversing) 34,000 N2 for surge scf 120 SW circulate sump, rtns to surface 10 15 % HCI with 10 % Xylene 113 SW displace and flush coil 5 FW (preflush) 12 Class "G" Cement 21 FW (postflush) 20 SW (displacement) 247 SW (reversing and jetting) 72,000 SCF Nitrogen 0 Methanol LARRY GRANT ~ Date: Attn. ALASKA OIL + GAS CONSERVATI~--N 3oo~ PORCUPiNe. DRAYS ANCHO~GE ~, 99501. 22 June 1995 Transmittal of Data Sent by: PRIORITY MAIL Dear Sir/Madam, Enclosed, please find the data as described below: 1-45/Q-26 1 PLS FINAL BL+RF RUn # 1 Run # 1 ECC No. 4143.10 5756.06 Please sign and return to: Attn. Rodney D. Paulson Atlas Wir 56 Street Anchorage, AK 99518 FAX to (907) 563-7803 Received by: Date .=--~-. Endicott Production Engineering Department DATE: WELL N;: BP EXPLORATION REP: SERVICE COMPANY: POST SOUEEZE PERFORATIONS 5~27~95 3-01/N-29 POWERS ATLAS (BARBA) DATE/TIME OPERATIONS SUMMARY 13:00 MIRU ATLAS. WELL SI. SIWHP = 1300 PSIG~ lAP 300 PSIG~ OAP 200. 14:25 RIH WITH 20' 3 3/8" HSCr 4 SPF~ 60-120° PHASING~ 0° ORIENTATION. 14:40 FL 3290' 15:20 BLEED WHP TO 400. SAT DOWN IN NODES. STUCK. 12r335' 15:57 FREE POOH. 16:45 AT SURFACE WITH GUN. REHEAD AND WAIT FOR 2.5" GUNS. 18:43 RIH W/20' 2.5" HSC~ 4 SPF~ 0° PHASING~ 0° OREINTATION 18:56 FL 1780'. MUST HAVE KNOCKED A CEMENT NODE OFF. 19:45 TIE IN TO DLL DATED 1/21/87. TAKE OUT 19'. 20:07 HANG CCL AT 12357.5'. SHOOT12360' TO 12380'. LOST 200 LBS. 20:15 LOG OFF~ SI WELL~ FLAG LINEr AND POOH. 20:47 AT SURFACE. SIWP--900 PSIG. 21:10 RIH W/22' 2.5" HSC~ 4 SPF, 0° PHASING, 0° OREINTATION 22:33 SAT DOWN AT 7800'-8450'. COULDN'T WORK THROUGH. POOH TO SHORTEN TOOL STRING. 23:02 AT SURFACE 0:32 RIH WITH 20' GUN. 1:10 SAT DOWN BETWEEN 8800'-9300'. WE MUST HAVE DRAGGED SOME CEMENT INTO THE TUBING AFTER FIRST GUN. TRIED FLOWING WELL BUT IT DIDN'T HAVE ENOUGH HORSEPOWER TO DO ANY GOOD. 1:39 CAN'T WORK THROUGH. NO SKATES AVAILABLE FR 2 1/2" GuNs. POOH 3:03 OOH. ALL SHOTS FIRED ON FIRST GUN. 3:45 RDMO. POP WELL ~ FOC. PERFORATION SUMMARY: GUN .DLL DEPTH FEET SUBZONE I 12360-12380 20 3A All intervals were shot using 2 1/2" Alpha Jet (HSC) guns at 4 spf, 0 degree phasing and 0 degree orientation. Note: I would try a 10' 3-3/8" gun with a skate on the reperf. We got stuck with a 20' gun below the top interval probably on the CCL 3.5" OD. I believe the top interval can be shoot with the bigger guns. icott Production Engineering Department POST SOUEEZE PERFORATIONS DATE: 5/31/95 WELL N;: 3-01/N-29 BP EXPLORATION REP: Thomas Rut SERVICE COMPANY: ATLAS (Don Barba, Mike Grlglione, Sam Grlffiths) DATE/TIME OPERATIONS SUMMARY 5/31 0800 MIRU ATLAS. INSTALL SSV FUSIBLE CAP; SSSV IS OUT. WELL FLOWING. FWHP = 250 PSI; CHK = 176; FWHT = 108° F; lAP = 800 PSI; OAP = 250 PSI; NOT TAKING LIFT GAS. 0810 SI WELL TO RIH. RIH WITH CABLE HEAD, PFC, GUN, BULL PLUG TO MINIMIZE TOOL LENGTH. 0830 RIH WITH 10' 3-3/8" HSC, 6 SPF, 60° PHASING, RANDOM ORIENTATION, 21 GRAM CHARGES. WILL MAKE 2 SEPARATE 10 FT GUN RUNS AS LAST ADD PERF ATTEMPT ON 5/27/95 HUNG UP ON NODES. (TOOL LENGTH 16.1 F'r). 1000 SAT DOWN AT 13318' MD. SQZ NODE RESTRICTION AS PER LAST GUN RUN ATTEMPTS. MADE 2 ATTEMPTS TO RUN PAST, BUT TAG'D EACH TIME. PULLING ABOUT 1400 LBS GETTING OUT. DECIDED TO TIE IN AND SEE IF UPPERMOST 10' INTERVAL CAN BE PERFORATED - WHICH MAY DISLODGE SOME DEBRIS AND ALLOW US TO SPUD WITH A DEAD GUN VS. LIVE. 1010 TIE IN TO DLL DATED 1/21/87 LOGGING UP AND MAKE A +1 FT CORRECTION TO E-LINE ODOMETER. 1020 LOST SIGNAL TO PFC (GR) WHILE TRYING TO LOG UP CONFIRMING TIE-IN. POOH TO REPAIR CABLE HEAD. LOST SIGNAL FROM PULLING TOO MUCH WEIGHT. WILL HAVE SLICKLINERS BROACH BEFORE NEXT ATTEMPT. 1120-1630 POOH AND LAY DOWN TO RU CAMCO. SLICKLINERS RAN 3.65 BROACH AND RECIPROCATED. THEN RAN 3.70 BROACH AND FOUND SEVERAL NODES. POOH AND RD SLICKLINE TO RU ATLAS. 1700 RU ATEAS & RIH WITH 10' 3-3/8" HSC, 6 SPF, 60° PHASING, RANDOM ORIENTATION~ 21 GRAM CHARGES. 1800 TIE IN TODLL DATED 1/21/87 LOGGING UP FROM 12200' MD AND MAKE A +15 FT CORRECTION TO E-LINE ODOMETER. 1810 DROP DOWN TO 12290' MD AND LOG CONFIRMATION PASS FOR TIE-IN. TIE-IN STILL ON DEPTH~ THOUGH PULLING ~75LBS MORE WEIGHT. 1830 DROP DOWN AND TAGGED UP AT 12331' MD. PULLED UP UNTIL PICK UP WEIGHT WAS SEEN AND STOPPED AND HUNG TOP SHOT @ 12314' MD. FIRED GUNS AND SAW GOOD WEIGHT & CURRENT INDICATIONS. PULLED UP TO 12100° MD AND FLAGGED E-LINE. POOH. SIWHP BEFORE RIH = 1000 PSI. SIWHP AFTER SHOT = 1100 PSI. SIWHP HAS BEEN BUILDING THROUGHOUT DAY ($1WHP = 875 PSI DURING BROACHING). DID NOT FLOW WELL DURING PERFS TO PROTECT SQZ NODES AND TO PREVENT ANY MORE DEBRIS FROM FALLING ON TOP OF GUNS. 1925 AT SURFACE. ALL SHOTS FIRED. 1945 RIH WITH 10' 3-3/8" HSC, 6 SPF, 60° PHASING, RANDOM ORIENTATION, 21 GRAM CHARGES. 2045 TIE IN TO DLL DATED 1/21/87 LOGGING UP FROM 12200' MD AND MAKE A +1 FT CORRECTION TO E-LINE ODOMETER. (FLAG CLOSELY ON DEPTH). 2055 DROP DOWN TO 12330' MD AND LOG UP TO TOP SHOT AT 12304' MD. 2100 FIRE GUNS. SAW ABOUT 60 LBS OF WEIGHT LOSS BUT WEAK CURRENT SIGNAL. LOG UP FOR TATTLE TALE. POOH. SIWHP = 1100 PSI. 2200 GUNS AT SURFACE. ALL SHOTS FIRED. 2300 RDMO ATLAS AND RETURN WELL TO PRODUCTION OPERATIONS. PERFORATION SUMMARY: GUN DLL DEPTH I 12314 - 12324 FEET ~UBZQNE 10 3A3 LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501° Date: 6 June 1995 Transmittal of Data Sent by: PRIORITY MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION PFC/PERF FINAL BL+RF PFC/PERF FINAL BL+RF PFC/PERF FINAL BL+RF GR/CCL FINAL BL+RF Run # 1 Run # 1 Run # 1 Run # 1 ECC No. 5756.05 6034.05 6432.03 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: Please sign and ~,eturn ~o; Petrotechntcal Data Cente~ Exploration (Alaska) In~ 0 East Benson Boulevard ge, Alaska 99505 .- RECEIVE D .. ' '^ ..... JUN u~ 19.9b.. -- I)~t~ ' -- Alaska. Oil &-Gas Cons. Commission Anchorage LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501° Date: 1 June 1995 RE: Transmittal of Data Sent by: PRIORITY MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION 1PFC/PERF FINAL BL+RF 1 PFC/PERF FINAL BL+RF 1 PDK FINAL BL+RF 1 PFC/PERF FINAL BL+RF 1 SBT/GR FINAL BL+RF Run # 1 Run // 1 Run # 1 Run ~ 1 Run # 1 ECC No. 3842.06 5756.04 6006.04 6185.12 6432.02 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: Please sign and return ~! Petrotechnical Data Cente~ BP Exploration (Alaska) I~$ 90_0~ast Benson Boulevard ~~~e~, ~as~a ~0s ~c~ee ired b:7 .... JUN 0 8 1995 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA AL,~$KA OIL AND GAS CONSERVATION COMMI,.'5~51ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing Alter casing Repair well Perforate X Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development X Exploratory Stratigraphic Service 4. Location of well at surface 2535'SNL, 878' WEL, Sec. 8, T11N, R17E At top of productive interval 1742' SNL, 2434' WEL, Sec. 5, T11N, R17E At effective depth 1500' SNL, 2402' WEL, Sec. 5, T11N, R17E At total depth 1546' SNL, 2396' WEL, Sec. 5, T11N, R17E 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: true vertical measured true vertical Length 122' 2441' 12073' 1220' 13050 feet Plugs (measured) 10525 BKB feet 12960 feet Junk (measured) 10463 BKB feet Size Cemented Measured depth BKB 6. Datum elevation (DF or KB) KBE = 55.34 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 3-01/N-29 SDI Permit number/approval number 86-190/not required 30" Driven 161' 13 3/8" 3534 c.f. Permafrost 2480' 9 5/8" 575 c.f. Class G 12112' 10. APl number 50- 029-21678 11. Field/Pool Endicott Oil Pool RECEIVED JAN 0 1995 Alaska 0il & Gas Cons. Commission AIt~l~av~l depth 161' 2477' 9774' 7" 387 c.f. Class G 11830'- 13050' 9548'- 10525' 12286'- 12304' (Squeezed), 12304'- 12326', 12360'- 12380', 12390'- 12426' (all open), 12426' -12460', 12480'- 12520', 12546'- 12564', 12570'- 12600' (all squeezed) (Subsea) 9860' - 9874' (Squeezed), 9874' - 9892', 9920' - 9936', 9945' - 9974' (All open), 9974' - 10002', 10018' - 10051', 10071'- 10086', 10091'- 10114' (all squeezed) measured true vertical Tubing (size, grade, and measured depth) 4 1/2" 12.6tt, 13CR80 to 11875' MD Packers and SSSV (type and measured depth) 9 5/8" TIW HBBP packer at 11,738'; 4 1/2" HXO SVLN at 1516' MD 13. Stimulation or cement squeeze summary Water shut off coiled tubing cement squeeze ~L3 (11/9/94) Intervals treated (measured) 12286'-12326', 12360'-12380', 12390'-12460', 12480'-12520', 12546'-12564', 12570'-12600' 1193 Bbla. ~eawater, 60 Bble acid, 10 Bble effluent water, 19 Bble methanol, Treatment description including volumes used and final pressure ,nd 26 BUa c~me.L FSIWHP = 2150 peig 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 456 502 5245 0 297 1246 1164 6542 0 320 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~ned ~~~/~ ~'", ~~ Title Senior Technical Assistant II Form10-AO~Rev 06/15/88 SUBMIT IN DU'PLIG~A'I'~_ ~( Endicatt Production Engineering Department Pg~t Squeeze Perforations DATE: 10/11/94 WELL N°: 3-01/N-29 BP EXPLORATION REP: POWERS SERVICE COMPANY: ATLASIKOENN DATE/TIME OPERATIONS SUMMAR'i) 0800 RU. Post radio silence signs at the entrance to island and next to well site. 0900 Establish radio silence and arm guns (Notify security). 0930 Install SSV fusible cap. WHP = 1900 psig. WHT = SI {leg F. IAP = 1100 psig. OAP = 200 psig[. Choke -- 0 Beans. 0935 Pressure test lubricator to wellhead pressure. 0945 RIH with Gun #1 (30 feet). SIWHP = 1900 psig[. 1040 Open wing valve and bleed WHP to 600 psig for underbalance. 1045 Tie in to CBL dated 1/25/87 then correlate back to the DLL (added 18'-CBL was three feet shallow over first interval). All of the depths listed below are from the open hole reference log (DLL). Flag line for next run 12548'. 1125 Shoot g.un #1 from 12396°12426' MDBKB..POH. SIWHP=600 psig, 1225 Fluid level was at 1300'. 1250 RIH with Gun #2 (,6' & 20' switched gun). SIWHP - 750 psig. 1330 Open wing valve. FWHP = 250 psig. 1345 Tie in to DLL logging up. Shoot gun # 2A from 12390-12396' MDBKB. FWHP = 250 psig[, log off. 1415 Tie in to DLL logging up. Shoot gun # 2B from 12360'-12380' MDBKB. FWHP = 250 psig. log[ off 1422 SI well and POH. 1530 RIH with Gun #3 (22 feet). SIWHP = 300 psig. Fluid at surface. 1625 Open wing valve . FWHP = 250 psig. Well started flowing liquid. Opened choke to 150 beans~ 1700 Tie in to DLL logging up. Gun was floating somewhat but was on depth over shooting interval. Shoot gun # 3 from 12304-12326' MDBKB. FWHP = 450 psig. Gun floating while logging, off. 1710 SI well and POH. SIWHP = 1300 PSIG. Looks like we made a oil well! 1930 Confirm all shots fired and end radio silence. 1935 RD. POP at FOC. Well was flowing hard and warming up without lift gas. FWHP=400 psig. Final SIP = 1450 psig. PERFORATION SUMMARY: GUN.. DLL DEPTH FEET $UBZONE 1 12396-12426 3 0 2B5 2A 12390-12396 6 2B5 2B 12360-12380 20 3A2 3 12304-12326 2 2 3A3 All intervals were shot using 3-3/8" guns at 4 spf, 60 degree phasing and random orientation. Atlas did not have a decentralizer to go with thier new gun bodies. RECEIVED JAN 03 1995 Alaska 011 & Gas Cons. Commission Anchora ~. LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: RE: 6 December 1994 Transmittal of Data ECC #: 5756.03 Sent by: MAIL Data: PL Dear Sir/Madam, Reference: BP 3-01/N-29 SDI ENDICOTT NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 PLS FINAL BL Run # 1 1 PLS FINAL RF Run # 1 please sign and return to: Atlas Wir~ices 5600 B~[reet ' Su~ 201 ~chorage, AK 99518 ~ ~Attn. Rodney D. Paulson ~~ ~ ~FAX t° (907) 563-7803 ~~ % Received by: /~/~~ /~/~ ~ate: ",~. ~ ~ LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE Date: 17 October 1994 Transmittal of Data ANCHORAGE ~%% AK, 99501. Sent by: U.S. MAIL Dear Sir/Madam, %%~~~.~~~x~~_x\ EnclOsed, please find the data as des~ed .~~: . WELL # DESC ~ 1 PFC/PERF RF SEPIA 1 PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA Run # 1 Run ~ 1 ECC No. 4297.07 5756.02 5600 B Street Suite 201 Anchorage, AK 99518 ttn. Rodney D. Paulson r ~~(907) 563-7803 Received by: ~Date: STATE OF ALASKA AI_/-~:~,~ OIL AND GAS CONSERVATION COMMISSluN REPORT OF SUNDRY WELL OPERATIONS 1.0perati;3ns performed: Operation shutdown Stimulate Plugging Perforate Pull tubing x Alter casing Repair well Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development ., Exploratory Stratigraphic Service 4. Location of well at surface 2535'SNL, 878'WEL, Sec. 8, T11N, R17E At top of productive interval 1742' SNL, 2434' WEL, Sec. 5, T11N, R17E At effective depth 1500' SNL, 2402' WEL, Sec. 5, T11N, R17E At total depth 1546' SNL, 2396' WEL, Sec. 5, T11N, R17E 12. Present well condition summary Total depth: measu red true vertical 13050 feet 10525 BKB feet Plugs (measured) 6. Datum elevation (DF or KB) KBE = 55.34 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 3-01/N-29 SDI 9. Permit number/approval number 86-190/C. Order #269 10. APl number 50- 029-21678 11. Field/Pool Endicott Oil Pool Effective depth: measured true vertical 12960 feet 10453 BKB feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True v~,CBal depth BKB 122' 30" Driven 161' 161' 2441' 13 3/8" 3534 c.f. Permafrost 2480' 2477' 12073' 9 5/8" 575 c.f. C/ass G 12112' 9774' 1220' 7" 38 7 c.f. Class G 11830'- 13050' 9548'- 10525' measured 12286'- 12326', 12360'- 12380', 12390'- 12460', 12480°- 12520', 12546'- 12564', 12570'- 12600' (squeezed but leaking) true vertical (Subsea) 9860'-9892', 9920'-9936; 9945'- 10002', 10018'- 10051°, 10071'- 10086', 10091'- 10114' (squeezed but leaking) Tubing (size, grade, and measured depth) 4 1/2" 12.6~, 13CR80 to 11875' MD Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary 9 5/8" TIW HBBP packer at 11,7387 4 1/2" HXO SVLN at 1516' IVIDa Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Re.oresentative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of ~/ell Operations _..xj_ Oil X Gas Suspended 17. I hereby certify~ha~th~or~going~ true and correct to the best of my knowledge. ~ R~ev~ ~/88 Title Drillin.q En.qineer Supervisor S~ned ',--' ~,---"~'~' - '- F rm 10-404 i ' Service Date SUBMIT IN DUPLICATE B?/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: SDI 3-01/N-29 BOROUGH: NORTH SLOPE UNIT: ENDICOTT FIELD: ENDICOTT LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 08/14/94 02:00 SPUD: RELEASE: 08/25/94 06:00 OPERATION: DRLG RIG: WO/C RIG: DOYON 15 08/15/94 ( 1) TD:13050 PB: 0 08/16/94 ( 2) TD:13050 PB: 0 08/17/94 ( 3) TD:13050 PB: 0 08/18/94 ( 4) TD:13050 PB:12960 NU BOPE MW: 9.2 NaBr MOVE RIG ROW T/ROW. FILL PITS W/BRINE 9.2 PPG, PRESS ON WELL = 200PSI. RU T/PUMP100 BBLS SEAWATER FOLLOWED BY BRINE DOWN TBG W/RETURNS T/FLOW LINE OF 3-03 PUMP @4 BBLS MIN. 700 PSI INTO FLOW LINE OF 500 PSI. OBSERVE WELL STABLE- ND TREE-NU BOPE CHANGING 9-5/8 PACKOFF MW: 9.0 NaBr NU BOP'S. TEST BOP. PU LANDING JT, UNLAND HGR W/95 K OVER PULL. L/D HGR, R/U & CIRC REDUCE WEIGHT TO 9 PPG BRINE. POH W/ 41 JTS 4-1/2" TBG, SSSV 7 CONTROL LINE, 20 PROT, 4 STEEL BANDS. R/D OTIS CONTROL LINE SPOOLER. POH & L/D TOTAL OF 261 JTS TBG, 3 GLM'S & CUTOFF JT, (CUT FLARED TO 5-9/16"). P/U TRI-STATE OVERSHOT & BHA, RIH TO 774' P/U HALLIBURTON 9-5/8" STROM PACKER, SET @ 50'. PULL WEAR RING, N/D BOP STACK, & SPOOL. CHANGING 9-5/8" PACKOFF. RIH TO RECOVER SLICK STICK MW: 9.0 NaBr INSTALL 9-5/8" PACKOFF & TEST TO 3000 PSI. N/U BOPE. TEST BOPE TO 5000 PSI, TEST WITNESSED BY B. FOSTER AOGCC. PULL TEST PLUG & INSTALL WEAR RING. RETRIEVE & L/D STORM PACKER. RIH W/ O/S BOWL, TAG & DRESS OFF TOP OF TBG FISH @ 10,004' LATCH ON TO TBG FISH W/ O/S, RELEASED SEAL ASSY FROM SA~ PKR W/80K OVER PULL. POH & L/D OVERSHOT BOWL W/27' CUTOFF JT. POH & L/D 43 JTS 4-1/2" TBG & BAKER SBR SEAL ASSY. P/U TRI-STATE OVERSHOT W/4-1/2" GRAPPLE. SERVICE RIG. RIH TO TOP OF SLICK STICK @ 11769'. POOH MW: 9.0 NaBr CIRC 9. BRINE. POOH RECOVER SLICK STICK & K ANCHOR/LD. MU MILL & PRT. RIH. CUT & SLIP DRLG LINE. RIH T/11782. MILL PKR. CBU. PUMP DRY JOB. POOH W/PKR & TAIL ASSY. W~LL : SDI 3-01 OPERATION: RIG : DOYON 15 PAGE: 2 08/19/94 ( 5) TD:13050 PB:12960 08/20/94 (6) TD:13050 PB:12960 08/21/94 ( 7) TD:13050 PB:12960 08/22/94 (8) TD:13050 PB:12960 MU CLEANOUT ASSY MW: 9.0 NaBr POOH NO PKR. LD MILL & JB. MU SPEAR. RIH SPEAR INTO PKR. NO INCREASE IN WT. 150 PSI INCREASE IN PP. POOH. PKR HUNG UP IN WELL HEAD. ATTEMPT T/FREE. RELEASE SPEAR F/PKR. LD SPEAR. MU PRT & SHOE. MILL PKR @38' LOST TRQ. CHANGE SHOE. SLIP & CUT DL. MILL PKR. LD PKR & TAIL ASSY. LD 6.75 DC. SERVICE RIG. MU CLEANOUT ASSY. TEST BOPE MW: 9.0 NaBr MU CLEAN OUT ASSY & RIH T/11830. CLEAN OUT F/11830 T/12600. TOOK 2 T/6K WT WHILE CLEANING OUT. CIRC. HOLE CLEAN. ATTEMPT T/REV. CIRC-BIT PLUGGED. POOH 10 STNDS. MU STORM PKR & SET @42'. ND TBG SPOOL. INSPECT & PULL PACKOFF & TBG SPOOL. INSPECT 9-5/8" CSG HNGR. SPLIT IN SECONDARY SEAL AREA OF CASG HRNG. IDRESS HGR. INSTALL NEW PACKOFF. LOCATE & INSTALL DBL STUDDED ADAPTOR FLANGE & SPOOL. NIPPLE BOPE & TEST. CIRC TOP 500' /CSG CLEAN MW: 9.0 NaBr RELEASE STORM PKR. PULL T/FLOOR & LAY DOWN. CBU MONITOR WELL. NO FLOW. POOH LD CLEAN OUT ASSY. MU 9-5/8" RBP, RIH SET @11750. SERVICE RIG. POOH. MU TOP RBP & RIH. CUT DL. RIH SET RBP @3000. POOH LD RBP RUNNING TOOL. PULL PACKOFF, PU SPEAR, PU ON CASG. DIDN'T PULL HIGH ENOUGH T/SET SLIPS. LD SPEAR. SET 7" JT IN ROTARY TABLE. PUT 2200# SAND ON TOP RTB. RIH T/5000. CIRC HOLE CLEAN. NU BOPE MW: 9.0 NaBr LD CSG CUTTER, FLUSH OUT TOP HOLE W/DIESEL. SPEAR CUT OFF CASG. LD HNGR 1 JT. & 24 CUT OFF JT. PU 10) 6.75" DC'S., BACKOFF TOOLS & 3) 8" DC'S,. BACK OUT DUTCHMAN. STAND BACK 8" DC. LD BACKOFF TOOLS. FLUSH HOLE W/20BBLS DIESEL. STND BACK 6.75" DC. PU SPEAR SET SPEAR IN DUTCHMAN. FINISH BACKING OUT. LD SPEAR & DUTCHMAN. ND BOPE. CLEAR FLOOR, RIG UP CASG TOOLS. MU TRIPLE CONNECTION, 10' PUP, 3JTS CASG. MADE UP T/12000'. TEST CASG W/3500 PSI. SET SLIPS W/215000 TENSION. MAKE INITIAL CUT ON CASG W/PNUEMATIC SAW. LD CUT OFF, LDG JT, CIRC SWEDGE & XO. MAKE FINAL CUT ON 9-5/8" CASG. INSTALL PCKOFF & TBG SPOOL. TEST W/3000. NIPPLE BOPE. W~LL : SDI 3-01 OPERATION: RIG : DOYON 15 PAGE: 3 08/23/94 (9) TD:13050 PB:12960 CIRC & FILTER BRINE MW: 9.0 NaBr NU BOPE. INSTALL TEST PLUG. TEST BOPE & MANIFOLD. LD DC. MU RBP RETRIEVING TOOL. RIH TO 2950. REVERSE CIRC SAND OFF TOP OF RBP, STING INTO & RELEASE RBP, CLEAR DP OF SAND, POOH, LD RBP. TEST CSG 2/3500 PSI. 0 LOSS. RIH W/RETRIEVING TOOL. SERVICE RIG. RIH TO 11750. STING INTO & RELEASE RBP. REVERSE CIRC. POOH. LD RBP & RUNNING TOOL. RIH 2/ 3 1/2" & 5" TO CLEAN OUT & FILTER BRINE. CIRC & FILTER BRINE. 08/24/94 (10) TD:13050 PB:12960 RUN TBG MW: 9.0 NaBr FILTER BRINE. POOH. STAND BACK 95 STANDS. LAY DOWN REMAINDER OF DP. PULL WEAR BUSHING. RU TO RUN TBG. RUN 4 1/2", 13CR-80, 12.6#, NSCT, TBG. 08/25/94 (11) TD:13050 PB:12960 SIGNATURE: RIG RELEASED MW: 9.0 Seawater RUN 4.5" 13CRR80 NSCT TBG. MU CONTROL LINES/TEST T/5000. RUN TBG. MU HNG LNDNG JT. MU CL T/HNGR & TEST. REV CIRC INHIB. BRINE. LAND TBG RILDS, DROP BALL. SET 2-WAY CHK VALVE. ND BOPE, RISER, FLOW LINES & ADPTR FLNG. NU TBG HEAD & TREE, TEST CL, SEALS, TREE & FLNGS W/5000. RU LUB. PULL 2-WAY CHK. SET PKR W/4000. TEST TBG W/4000. OK BLEED TBG T/1500. SHUT IN. TEST ANNUL. W/3700. OK. BLEED OFF TBG. SHEAR RP VALVE & BLEED TBG & ANNUL T/0. PUMP DIESEL DOWN ANNUL U-TUBE T/TBG. SECURE WELL TREE & WELL HOUSE, INSTALL BPV. RELEASE RIG @0600 HRS ON 8/25/94. (dril~i:~e~endent)~~ ~.-~- ~ DATE: MEMORANDUM TO: THRU: FROM: David John~, Chairma~ .~ Blair Wondzell, P. I. Supervisor Bobby Fostei"~ Petroleum Ins~edtor State of Alaska Alaska Oil and Gas Conservation Commission DATE: August 16, 1994 FILE NO: ALHIHPBD.doc SUBJECT: BOPE Test- Doyon 15 BPX- DIU - SDI 3-01/N-29 PTD # 86-0190 Endicott Field Tuesday, AuRust 16, !994: I traveled this date to BPX's Endicott field and witnessed the BOPE Test on Doyon rig 15. As the attached AOGCC BOPE Test Report shows there were no failures. The rig was clean and in good shape. The location was clean and there was good access to all areas of the rig. Summary: I witnessed the BOPE test on Doyon Rig 15 - test time 2.5 hours - no failures. Attachment: ALHIHPBD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Workover: X Drlg Contractor: DOYON Rig No. Operator: BPX Well Name: 3-01/N-29 Casing Size: 7" Set @ 13,050' Test: Initial X Weekly Other 15 PTD # Rep.: Rig Rep.: Location: Sec. 86-0190 DATE: 8/16/94 Rig Ph.# 659-6510/1 CLARENCE BALLARD ALLEN SINCLAIR 8 T. 11N R. 17E Meridian UM Test MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) Reserve Pit N/A Well Sign OK Drl. Rig OK BOP STACK: Quan. Annular Preventer 1 Pipe Rams Lower Pipe Rams 1 Blind Rams 1 Choke Ln. Valves 1 HCR Valves 1 Kill Line Valves 1 Check Valve N/A Test Pressure P/F 300,,'3,000 P 1 500/5, 000 P P 500/5,000 500/5,000 P 500/5,000 P 500/5, 000 P 500/5,000 P MUD SYSTEM: Visual Alarm Trip Tank YES YES Pit Level Indicators YES YES Flow Indicator YES YES Meth Gas Detector YES YES H2S Gas Detector YES YES FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan. Pressure P/F I 500/5,000 P 1 500/5,000 P f 500/5,000 P I 500/5,000 P CHOKE MANIFOLD: No. Valves 17 No. Flanges 40 Manual Chokes 1 Hydraulic Chokes I Test Pressure P/F 500/5,000 P 500/5,000 Functioned Functioned P P P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained 2 Blind Switch Covers: Master: Nitgn. Btl's: 4 ~ 2500 3,000 J P 1,400 P minutes 33 sec. minutes 55 sec. YES Remote: YES Psig. Number of Failures: 0 ,Test Time: 2.5 Hours. Number of valves tested 24 Repair or Replacement of Failed Equipment will be made within 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: GOOD TEST. 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: BOBBY D. FOSTER FI-021L (Rev. 7/19) ALHIHPBD.XLS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. TyPe of Request: Abandon __ Suspend __ Operation Shutdown __ Re-enter suspended well__ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program __ Pull tubing x Variance __ Perforate__ Other__ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development X Exploratory Stratigraphic __ Service 4. Location of well at surface 2535' SNL, 878' WEL, Sec. 8, T11N, R17E At top of productive interval 1742' SNL, 2434' WEL, Sec. 5, T11N, R17E At effective depth 1500' SNL, 2402' WEL, Sec. 5, T11N, R17E At total depth 1546'SNL, 2396' WEL, Sec. 5, T11N, R17E 12. Present well condition summary Total depth: measu red true vertical RECEIVED AUG-9 1994 Alaska 0il & Gas Cons. Commission /~ch0rag~ 13050 feet Plugs (measured) 10525 BKB feet 6. Datum elevation (DF or KB) KBE = 55.34 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 3-01/N-29 SDI 9. Permit number 86-190 10. APl number 50-029-21678 11. Field/Pool Endicott Oil Pool Effective depth: measured true vertical 12960 feet Junk (measured) 10453 BKB feet feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured cl~,~ Tru~/~rtical depth 122' 30" Driven 161' 161' 2441' 13 3/8" 3534 c.f. Permafrost 2480' 24 77' 12073' 9 5/8" 575 c.f. Class G 12112' 9774' 1220' 7" 387 c.f. Class G 11830'- 13050' 9548'- 10525' measured 12286'- 12326', 12360'- 12380', 12390'- 12460', 12480'- 12520', 12546'- 12564', 12570'- 12600' true vertical (Subsea) 9860'-9892', 9920'-9936', 9945'-10002', 10018'-10051', 10071'-10086', 10091'- 10114' Tubing (size, grade, and measured depth) 4 1/2" 12.6# L-80 TDS tubing with 3 1/2" 9.2# L-80 tailpipe to 11,899' Packers and SSSV (type and measured depth) 9 5/8" SAB packer at 11,783'; 4 1/2 SSSV at 1595' 13. Attachments Description summary of proposal X Detailed operations program ~ BOP sketch 14. Estimated date for commencing operation 8/10/94 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas__ Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge..~ ~, .~,.~~,,,~/'~,~.',~'~'~,..~~ ~,.-,.-,, ~~,, Signed /d/i~,~,~:~J~' '~ '-~' '-~ ~ Title Drilling Engineer Supervisor ~,~ Date ~d,~--~c~ ~ ¥ ~ - FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so rePr~esentative may witness Plug integrity BOP Test ~'~ Location clearance ~ Mechanical Integrity Test~ Subsequent form required 10-/-/, dB Original Signed By Approved by order of the Commission David W. Johnston J Approval No. Commissioner Form 10-403 Rev 06/15/88 Approved Copy Returned SUBMIT IN TRIPLICATE ENDICOTT SD! 3-01/N-29 WORKOVER PLAN OBJECTIVE: A rig workover is required on well 3-01/N-29 to replace collapsed 4-1/2" tubing and replace the 9-5/8" packer. The scope of the work will be to pull the 4-1/2" tubing, recover the 9-5/8" packer, change out the 9-5/8" wellhead pack off, test the 9-5/8" casing, and run a new 4-1/2" 13Cr completion assembly. ,,,TIMING: 3rd Quarter 1994 8 days plus well to well move with rig Doyon 15 PRE-RIG OPERATIONS . Circulate well with 8.6 ppg sea water. Check that the well is dead. Attempting to kill the well with sea water through the collapsed tubing with a BHP of 8.4ppg EMW may not be sufficient to kill the well. If well is not dead, circulate well with 9.0 ppg brine. , RUE line. RIH and chemical cut the 4-1/2" tubing in the middle of the first good joint of tubing above the collapsed tubing at 10,111 'MD. Circulate the IA with 8,6 ppg sea water. 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 three days after the well kill, a deeper freeze protect will need to be done. , Dig out the cellar and level the pad. Inspect the wellhead and tree. Function test the LDS's. RIG OPERATIONS . Mobilize Doyon 15. Review Endicott Simultaneous Operations Plan concerning rig moves. . Pull the BPV with DSM lubricator. Check that the well is dead. Set the TWC. 3. ND the tree and NU the BOPE. Test the BOPE. (1/2 day) , Screw in the landing joint. Pull and LD the tubing to cut point above the collapsed tubing. (1 day) . P/U overshot and latch the tubing stub. Attempt to pull EB-1 tubing seal receptacle. If this fails, attempting to rotate the KBH-22 anchor should be discussed, but remember the tubing below is collapsed. Fish the slick stick and latch. (2 days) 6. P/U mill and PRT for 9-5/8" SAB-3. Recover 9-5/8" packer. (2 days) DKC Page 1 August 5, 1994 RECEIVED AUG -9 1994 Alaska 0il & Gas Cons. Commission Anchorage ENDICOTT SDI 3-01/N-29 WORKOVER PLAN o 10. 11. 12. PU storm packer and set @ +/- 50'. Change out furminated 9-5/8" FMC pack-off. (1 day) P/U and GIH with a 9-5/8" R'I-I'S. TIH to just above 7" liner top at 11,830' MD. Test casing to 3500 psi for 30 minutes. POH. (1/2 day) RIH w/9-5/8" x 4-1/2" packer, 4-1/2" 13CR tubing to expected setting depth. (1 day) Set the 9-5/8" 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) Turn the well over to Production. RECEIVED AUG -9 1994 Alaska (~jj & Gas Cons. Commission AnChorage DKC Page 2 August 5, 1994 STATE OF ALASKA ALA,SKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate Pull tubing Alter casing Repair well Other X 2. Name of Operator 5. Type of Well: 6. BP Exploration (Alaska) Inc. Development X Exploratory 3. Address Stratigraphic 7. P. O. Box 196612, Anchorage, Alaska 99519-6612 service 4. Location of well at surface 8. 2535'SNL, 878' WEL, Sec. 8, T11N, R17E At top of productive interval 1742' SNL, 2434' WEL, Sec. 5, T11N, R17E At effective depth 1500' SNL, 2402' WEL, Sec. 5, T11N, R17E At total depth 1546' SNL, 2396' WEL, Sec. 5, T11N, R17E RECEIVED AUG - 1 1994 Aisska 0il & Gas Cons. Commission Anchor~,~e Datum elevation (DF or KB) KBE = 55.34 12. Present well condition summary Unit or Property name Duck Island Unit/Endicott Well number 3-01/N-29 SDI 9. Permit number/approval number 86-190~not required 10. APl number 50- 029-21678 11. Field/Pool Endicott Oil Pool ORi¢iN/ L feet Total depth: Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical measured true vertical Length 13050 feet Plugs (measured) 10525 BKB feet 12960 feet Junk (measured) 10453 BKB feet Size Cemented Measured depth True ve..rti.c~l depth BKB 122' 30" Driven 161' 161' 2441' 13 3/8" 3534 c.f. Permafrost 2480' 2477' 12073' 9 5/8" 575 c.f. Class G 12112' 9774' Tubing (size, grade, and measured depth) 1220' 7" 387 c.f. Class G 11830'- 13050' 9548'- 10525' measured 12286'- 12326', 12360'- 12380', 12390'- 12460', 12480'- 12520', 12546'- 12564', 12570'- 12600' (all squeezed but leaking) true vertical (Subsea) 9860'- 9892', 9920'- 9936', 9945'- 10002', 10018'- 10051', 10071'- 10086', 10091'- 10114' (all squeezed but leaking) 4 1/2" 12.6# L-80 TDS tubing with 3 1/2" 9.2# L-80 tailpipe to 11,899' Packers and SSSV (type and measured depth) 9 5/8" SAB packer at 11,783'; 4 1/2 SSSVat 1595' 13. Stimulation or cement squeeze summary Water shut off coiled tubing cement squeeze #1 and #2 (6/16-17/94) Intervals treated (measured) 12286'- 12326', 12360'- 12380', 12390'- 12460', 12480'-12520', 12546'- 12564', 12570'- 12600' See attachmente Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 1576 · 1509 12007 0 3621 j 2432 2037 0 Tubing Pressure 350 313 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed~'/,~'~,/l,~ C~, ~ TitleSenior Technical Assistant ll Form 1 ~Rev 06/15/88 SUBMIT IN DOPLI(]AYE Well: 3-01/N-29 Op~ .ion: IITIMEI DEPTH(f t) Date: 6/16-17/94 (BPM) {psi) (psi) [ VOL INOZZLE RETURN REMARKS Final Well StatusI SIWHP ](psi) I 2000 I IAP 0AP GLP FLP FLT I I N/A I ! SUMMARY Killed well down backside. Ran into 12,954 without tagging TD. Found injectivity stable but too Iow to justify using thixotropic. Squeezed well with 30 bbl class "G" instead. Looked like we put about 4 bbl cement behind pipe. Slight leak on initial pressure test. Encountered gas and crude during live reverse out. Final pressure test indicated a 0.25 bpm leak at 1800 psi. Discussed with welloperations supervisor and decided to pedorm immediate re-squeeze. Acidized prior to pumping second batch and increased injectivity to 1 bpm @ 550 psi. Displaced cement and agressively ramped pressure from 500 to 3000 psi where PT showed slight leakoff as on previous batch. LRO'd to 12900'. Jetted to 11700' and final RO'd from 12900'. PT showed 50 psi loss in 5 min @ 2000 psi. Rev'd in N2 to underbalance. LWSI. OPERATIONAL SUMMARY batch #1' - CMT TO WEIGHT: CMT ON PERFS: SQZ PRESSURE ATTAINED: START REVERSE OUT: REVERSE OUT COMPLETE:' 16:03 17:59 18:57 19:17 22:31 OPERATIONAL SUMMARY batch #2' CMT TO WEIGHT: CMT ON PERFS: SQZ PRESSURE ATTAINED: START REVERSE OUT: REVERSE OUT COMPLETE: 05:40 07:50 08:16 08:56 12:20 CEMENT BATCH #1 I I 15.8 ppg Class "G"'cement including Lab thickening time' 7 hrs, 30 rain @ 170 BHCT 0.38 % FL-33 Lab fluid loss: 89 CC 0.1 % CD-32 Field fluid loss: 94.2 CC 0.46 % R-11 Live cell loss: 225 CC 0.2 % bentonite gel Lab APl filter cake: lg HS FP-CL Field APl filter cake: 1 7/8" ,,, 0.2 % S'400 Live cell cake: 4 1/4" (broke up) 30, BBL ,pumped 17 BBL recovered ACID SUMMARY I 15 % HCI I 0.7 % S-500 1,0 % X¥1ene i 2.5 ppt F-210 0.4 % NE-41 0.4 % ACI - 274 RECEIVED tlO - ] 1994 Gas Cons. Commission Anchoraje Well- 3-01/N-29 Ope ~on: Date: 6/16-17/94 (tt) (BPM), ( psi) (psi) ] VOL.INOZZLE RETURN REMARKS CEMENT BATCH' #2' "' I ' ' I' ',' 1'5.8 ppg Class "G" Cement i~cluding Lab thickeni'~g iime: 7 hrs, 25 min ~ 170 BHCT 0.48 % FL-33 Lab'fluid loss' 46.8 CC 0.1 % CD-32 Field fluid loss: "' 53.6 CC ,. 0.53 % R-11 - _ Live cell loss: 83 CC 0.2" % bbntonite gel Lab APl filter cak~'i 7/8" lg HS FFi-E[..L Field A'PI filter cake: I 1/16" 0.2 % S-400 Live cell cake: 2 5/8" ..BBL pumped 25 21 BBL reco.,vered {Cost Code: N10301 TD Tag:-Ran in to 12954', but did not tag " " FLUIDS PUMPED : : BBLS. DESCRIPTION 434' Bullhead Sea Water' ' " 218 SW Cii:~ulate Sump,,, rtns to surface. ' ..... 10 Efflu'ent Water (Preflush) " 30 Class -G- Cement ) ....... 4 Effluent Water (Postflush) .. 30 Sea Water (Displacement) , 11 Biozan 685 Sea Water IJettin~ and R~versing) ........... .... 321 SW Circulate Sump, rtns to surface. 18 15 % HCI with 10 % Xl/.lene ...... 105 SW over[lush .... .... 15 Effluent Water (Preflush) .. ..... 25 Class "G" Cement ) .. 9 Effluent W,,ater {Postflush) .... , 28 Sea Water (DisPlacement) 0 Biozan , , 141 Sea Water (Jettin[I and Reversing) .... BOTTOM-HOLE ASSEMBLY , Tool String Descriptions I O.D. I I.D. I LengthI Comments Coiled Tubing Connector 2.2" 1 0.6' Nozzle 2.25"[ 0.3' TOTAL LEN'~TH 0.9' RECEIVED AUG - I 1994 Alaska Oil & Gas Cons. Commissio~ Anchorage BP EXPLORATION June 28, 1994 Dave Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage Alaska, 99501 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 SR r:'N~---i- ENG ASST' SR GEOL I GEOL ASST, ~ S TAT' 'T ~l~!~' FILE RE: Continued Production of Endicott Well 3-01/N-29 with IA Pressure This memo documents verbal approval received from Blair W. andz-ell yesterday to allow temporary production of well 3-01/N-29 with annulus pressure resulting from a leak in the tubing. A rig workover is planned to replace the tubing when the rig finishes drilling the current well (4-10/M-28). Continued production of 3-01/N- 29 until the rig is available is needed to evaluate recent remedial results, identify and plan additional remedial work, and maintain field production rates. The annulus pressures will be closely monitored and controlled to prevent over pressure or damage to the casing strings or well head. Well 3-01/N-29 perforations were cement squeezed With coiled tubing on June 17, 1994 to shut off excessive water production. The cement squeezed perforations proved to be leaking significantly during post squeeze pressure testing. The well was put on production without reperforating. The well tested 3621 BOPD with 36% water cut on June 22, a significant production improvement from the pre-squeeze rate of 880 BOPD with 92% water cut. Following the June 22 well test, the tubing was found to be partially collapsed and leaking at 10,111' MD. Wireline tools cannot pass the partially collapsed section of the tubing, however the tubing remains open enough to allow continued production. It is unknown if the cement squeezed perforations will continue to break down causing increasing water cut. Continued production will allow timely determination of the need for another cement squeeze. Should another squeeze be needed, it can be coordinated with the tubing replacement rig workover to enable the most efficient return of this well to productive status. Thank you for your support in matter. Please contact me at 564-4026 if you have questions or need further information. S. Burt Littlefield Lead Petroleum Engineer RECEIVED BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 August20,1993 Alaska Oil and Gas Conservation Commission 3001 Pomupine Drive Anchorage, Alaska 99501 Dear AOGCC Representative, Attached in duplicate is detailed information regarding the enclosed well logs for the Endicott Field. Please contact me at 564-5225 if you have any questions. Sincerely, ennne L. Haas ior Technical Assistant II JLH Enclosures xc: File 06.10 WELL NAME '88-' 5"7~i-01/J-19 DATE 8/2/93 INTERVALS LOG NAME RUN NO COMPANY NAME 11973'-12150' ."PFC/GR/CCL ATLAS WIRELINE "'1~O'~3-33/K-37 ~¢'¢'~8 ~"- 2-04/M- 19 "'~'~'~ 3-27/M-33 %~-'t~O-.. 3-01/N-29 %~-.- ~7.... 1-41/O-23 -'-1-3510-25 ~5(~ '"-1~15/P-25 r4-06/Q-32 ~'4-06/Q-32 'N-O6/Q-32 ,,,,2-5 2/S-14 8/2/93 7/24/93 7/28/93 7/26/93 7/29/93 7/31/93 8/5/93 7/25/93 7/25/93 8/5/93 8/11/93 12630'-13200' 10460'-10748' 10980'-11950' 11600'-12850' 11350'-11892' 12750'-13100' 12430'-12800' 11000'-11250' 10953'-11250' 8850'-11350' 11503'-12072' ....PRODUCTION LOGGING SERVICES -,' PFC/GR/CCL --- PRODUCTION LOGGING SERVICES .,--PRODUCTION LOGGING SERVICES · - PRODUCTION LOGGING SERVICES -- PFC/GR/CCL -- PFC/GR/CCL --' PRODUCTION LOGGING SERVICE S ('~,") v" PFC GAMMA RAY '-"PRODUCTION LOGGING SERVICES ,-,'PFC GAMMA RAY ATLAS WIRELINE ATLAS WIRELINE ATLAS WIRELINE ATLAS WIRELINE ATLAS WIRELINE ATLAS WlRELINE ATLAS WIRELINE ATLAS WlRELINE ATLAS WIRELINE ATLAS WIRELINE ATLAS WIRELINE STATE OF ALASKA AL-AbttA OIL AND GAS CONSERVATION COMMISSIL. .... REPORT OF SUNDRY WELL OPERATION 1. Operations performed: Operation shutdown Stimulate X Plugging Perforat~, ~'~:~ ''~ Pull tubing Alter casing Repair well Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 2535' SNL, 878' WEL, Sec. 8, T11N, R17E At top of productive interval 1742'SNL, 2434' WEL, Sec. 5, T11N, R17E At effective depth 1500'SNL, 2402' WEL, Sec. 5, T11N, R17E At total depth 1546'SNL, 2396' WEL, Sec. 5, T11N, R17E RECEIVED JAN 1 4 Alaska Oil & Gas Cons. Commissior: 6. Datum elevation (DF or KB) KBE = 55.34 feet 7. Unit or Property name Duck/s/and Unit/Endicott 8. Well number 3-01/N-29 SD/ 9. Permit number/approval number 86-190/not required 10. APl number 50- O29-21678 11. Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 13050feet 10525 BKBfeet 12960feet 10453 BKBfeet Anchorage Plugs (measured) Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True ve~j~ depth BKB 122' 30" Driven 161' 161' 2441' 133/8" 3534 c.f. Permafrost 2480' 2477' 12073' 9 5/8" 575 c.f. C/ass G 12112' 9774' measured 1220' 7" 387c. f. Class G 11830'-13050' 9548'-10525' 12286'- 12326', 12360'- 12380', 12390'- 12460', 12480'- 12520', 12546'- 12564', 12570'- 12600' true vertical (Subsea) 9860'- 9892', 9920'- 9936', 9945'- 10002', 10018'- 10051', 10071'- 10086', 10091'- 10114' Tubing (size, grade, and measured depth) 4 1/2" 12.6t/L-80 TDS tubing with 3 1/2" 9.2# L-80 tailpipe to 11,899' Packers and SSSV (type and measured depth) 9 5/8" SAB packer at 11, 783'; 4 1/2 SSS V at 1595' 13. Stimulation or cement squeeze summary Scale inhibitor treatment Intervals treated (measured) 12286'-12326', 12360'-12380', 12390'-12460', 12480'-12520', 12546'-12564', 12570'-12600' Treatment description including volumes used and final pressure 393 Bbls scale inhibitor, lOOBbls seawater spacer with surfactant, 393 Bbls Ca water spacer, 964 Bbls seawater overflush with surfactant, 170 Bbla seawater tubing displacement and 14 barrels to freeze protect. FS1WHP=IO0 psi 14. Prior to well operation Subsequent to operation Representative Daily Average Production or InJection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 5186 ~''' 4117 5186 4065 3307 5613 Tubing Pressure 745 701 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. C ) . Assistant II Signed ~~ ~..~,, '~~~ Title Senior Technical Form 10-4~ Rev 06/15/88 SUBMIT IN D~JPI.:I'CATE BLUELINE AND SEPIA INFORMATION TO THE STATE ENDICO'rT FIELD ONLY WELL NAME DATE INTERVALS LOG NAME RUN NO COMPANYNAME 1-29/M-25 11/15/92`./ 13100'-14069' (~PDK-10~3G~..~.~..~ 1-49/P-21 11/1 9/92 ,-// 2-06/J-22 1 0/25/92 --' 2-58/S-09~ .;;"z. 11/1 5/92 ~' I ATLAS WIRELINE 10600'-11200' 1240'-12260' 13900'-14328' 3-01/N-29 11/9/92 · 11900'-12850' 3-05/0-29 11/16/92- 11300'-12400' 3-21/L-34 11/16/92 / 11950'-12742' 3-23/N-32 11/9/92~ 11050'-11664' 4-02/Q-28 .~10/29/92 J 11800'-13000' [.1 0~29/92 / 11800'-13000' 4-40/P- 43¢;Z,,.Z//3,1 0/21/92 CPDK-100)GR/CCL NOISFJTEMP SURVEY PDK-100/GR/CCL PFIODUCTION LOGGING (CALIPER SURVEY) PRODUCTION L~ING (CALIPER SURVEY) PRODUCTION L~ING (CALIPER SURVEY) PFIODUCTION L~ING (CALIPER SURVEY) JEWELRY LOG INJECTION PROFILE SURVEY 12550'-13570'J INJECTION PROFILE WARM BACK I ATLAS WIREUNE I SCHLUMBERGER 1 ATLAS WIRELINE I ATLAS WIRELINE I ATLAS WIRELINE 1 ATLAS WIRELINE I ATLAS WIRELINE 1 CAMCO I CAMCO I CAMCO VED Alaska 0il & Gas Cons. COnll~joil Anchorage BLUELINE AND SEPIA INFORMATION TO THE STATE ENDICOTT FIELD ONLY WELL NAME DATE INTERVALS LOG NAME Bluelines to the State RUN NO COMPANY NAME 3-01/N-29oO~'I~~ 3-05/0-29 3-45/M-39 4-06/Q-32 4-44/M-44 1-27/P-20 ~- ~' 6/13/92 1-37/P-24 o°?'"?° 6/27/92 1-57/R-23J~""//~ 6/1 5/92 1-67/T-20 ~?'''#¢' 6/2/92 1-69/V-19~'°'~ 6/1/92 2- 04/M- 19 ~'~""~'2'- 6/18/92 2-52/S-1487-'~''~'' 6/15/92 6/1/92 3/23/92 6/9/92 6/1 0/92 f6/22/92 6/17/92 6/2/92 9950'-10690' 12050'-12430' 11600'-12389' 10550'-11800' 12000'-12630' 10000'-1 0675' 10600'-12667' 12150'-12844' 12000'-12520' 11800'-12500' 10000'-11534' 13600'-14237' 13900'-14316' 13600'-14500' Compensated Neutron Log 2.5" CNL Leak Detection Survey Temperature Gamma Ray Log Gas Lift Survey Collar Log Injection Profile Survey TDT-P Jewelry Log Production Profile Survey Perforation Log Casing Collar Log Jewelry Log PFC/Gamma Ray '"" Pump In Temperature Survey ,.,"" Temperature CCL Log One One One One One One One One One One One One One One Schlumberger Camco Camco Camco Camco Schlumberger Camco Camco Halliburton Logging Services Atlas Wireline Services Camco Atlas Wireline Services Camco Camco Page 1 Bluelines to the State BLUELINE AND SEPIA INFORMATION ENDICO'rT FIELD ONLY WELL NAME DATE INTERVALS LOG NAME RUN NO COMPANY NAME 1-27/P-20 ~ 5/1/92 10350'-10850' Production Profile Survey One Camco ~?~'-,~' 2-28/P-19 j 5/2/92 /--/'¢<~2-30/0-09 '" 5/20/92 I.--/?z-2-34/P-14-,/ 5/16/92 ~ °~-7-~2-46/Q-15~ 5/3/92 '~ ~'"'77 2-64/U-10 ~ 5/22/92 t~-'1~~ 3-01/N-29,/ 5/4/92 t~.-f~° 3-33/K-37 '/ 5/21/92 ~,-7,Z. ~4-02/Q-28 ,/ 5/11/92 t4-02/Q-28 ./ 5/24/92 ~'~.-~¢ 4-50/K-41 ./ 6/7/92 /, 4-40/P-43 .~ 5/14/92 ')4-40/P-43 ---' 5/14/92 ~,,.~3, ~ 4-40/P-43 '~ 5/14/92 , ~4-40/P-43 ~ 5/1 4/92 ~ 4-40/P-43 .,'/ 5/1 8/92 I~4-40/P-43 ~ 5/1 8/92 9900'-10300' 11100'-13250' 100'-10700' 10500'-11100' 8800'-9600' 12150'-12700' 12640'-12945' 11800'-13000' 10600'-13008' 13300'-13890' 13100'-13801' 13031.6'-13624' 13100'-13806' 9650'-13806' 12580'-13688' 12580'-13652' Production Profile Survey Production Log Leak Detection Survey Production Profile Survey TDT-P/Borax Survey/Water FLow Log Production Profile Survey Production Log Flowmeter Temperature Log Injection Profile Survey Production Logging Services Dual Laterolog Micro-SFL Repeat Formation Tester Subsea TVD Log Compensated Neutron-Litho-Density Ultrasonic Imager (USI)' ~ Cement Bond Log One One One One One One One One One One One One One One One One Camco Schlumberger Camco Camco Schlumberger Camco Schlumberger Camco Camco Atlas Wireline Services Schlumberger Schlumberger Schlumberger Schlumberger Schlumberger Schlumberger Page 1 WELL, 1-39/P-17 TDT-P 9690'-10610' SCHLUMBERGER / .~VELL __ 1-45/Q~26V PROD-F 12800'-13750' 3/5/91 RUNTHREE 12/19/90 RUNONE WELL 1-69/V-19 ~ INJ 12000'-12887' WELL 2-44/R-12 J JEWELRY LOG 10800'-11800' WELL 3-01/N-29 ~/ TDT-P 12100'-12941' SCHLUMBERGER 2/19/91 RUN ONE 2/18/91 RUN ONE RUN FOUR WELL 3-05/O-29 2/23/91 TDT-P ,j/ RUN FOUR 11550'-12380' SCHLUMBERGER WFL 7 2/23/91 11550'- 1 2380' RUN FOUR SCHLUMBERGER ,WELL 3-25/M-27 V/''~ LWD 9700'-10400' SCHLUMBERGER DLL V/ 12890'-13536' 2/5- 1 0/91 RUN ONE 2/10/91 RUNONE JOHN BOYLE July 10, 1991 Page 2 WELL 1-63/T-22 12100'-13088' STATIC TEMPERATURE SURVEY WELL 2-04/M-19 9800'-10680' TDT SCHLUMBERGER WELL 2-08/K-16 11670'-12038 TEMPERATURE SURVEY HRS WELL 3-01/N-29 11650'-12931' PRODUCTION PROFIi F WELL 3-11/M-30 12695'-13395' TDT SCHLUMBERGER WELL 3-21/L-34 12200'-12850' PRODUCTION PROFILE WELL 3-27/M-33 11550'-12070' STATIC TEMPERATURE SURVEY 11500'-12071' PRODUCTION PROFILE CAMCO WELL 3-33/K-37 12100'-13284' PRODUCTION PROFILE 6/10/91 RUNONE 6/29/91 RUN FIVE 5/24/91 RUN ONE 6/5/91 RUN ONE 6/30/91 RUN THREE 6/1 7/91 RUNONE 6/1 1/91 RUN ONE 6/9/91 RUNONE 6/6/91 RUN ONE 2063/JLH/clt June 13, 1991 Alaska Oil and Gas Conservation Commission Page 3 WELL 2-58/S-09 TEMPERATURE COLLAR 13000'-14335' WELL 2-62/Q~1 · TEMPERATURE LOG 9900'-10806' WELL 2-68/S.~1 PRODUCTION PROFILE 10500'-11100° wE,, TEMPERATURE LOG 11308'-12175' WELL 3-01/N-29 PERF~TING R~D 11650'-12750' SCHLUMBERGER WELL 3-05/0-29 X - Y CALIPER SURVEY V 11440'-12550' TEMPERATURE SURVEY 11 600'-12565' 12100'-12430' ATLAS WIREUNE 5/25/91 RUN ONE 6/4/91 RUN ONE 5/19/91 RUNONE 5/19/91 RUN ONE 5/13/91 RUN ONE 5/7/91 RUN ONE 5/24/91 RUNONE 6/6/91 RUN ONE 2013/JLH/clt STATE OF ALASKA ALASKA OIL AND {gAS CONSERVATION OOMMISSK.)N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate × Pull tubing .. AItercasing Repair well Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2535'SNL, 878' WEL, Sec. 8, T11N, R17E At top of productive interval 1742' SNL, 2434' WEL, Sec. 5, T11N, R 17E At effective depth 1500' SNL, 2402' WEL, Sec. 5, T11N, R17E At total depth 1546' SNL, 2396' WEL, Sec. 5, T11N, R17E 5. Type of Well: Development ., Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 55,34 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 3-01/N-29 SD/ 9. Permit number/approval number 86-190/91-102 10. APl number 50- 029-21678 11. Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured true vertical 13050feet 10525 BKBfeet Plugs (measured) Effective depth: measured true vertical 12960feet 10453 BKBfeet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True ve~,a~ depth BKB 122' 30" Driven 161' 161' 2441' 133/8" 3534 c.f. Permafrost 2480' 2477' 12073' 9 5/8" 575 c.f. Class G 12112' 9774' measured 1220' 7" 387c.~ Class G 11830'-13050' 9548~10525' 12286'-12326~ 12360'-12380~ 12390'-12460~ 12480'-12520~ 12546'-12564~ 12570'- 12600' true vertical (Subsea) 9860'-9892~ 9920'-9936~ 9945'-10002', 10018'-10051' 10071'-10086~ 10091'- 10114' Tubing (size, grade, and measured depth) 4 1/2" 12.6# L-80 TDS tubing with 3 1/2" 9.2# L-80 tailpipe to 11,899' Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. 9 5/8" SAB packer at 11,783'; 4 1/2 SSSV at 1595' JUN 1 ^laska 0ii & 6as 00ns. Apch0rage Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 5714 4276 9 0 1348 5881 ~'~ 4576 _.l. 24 0 1461 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. Si~ned ~ /~. ~I~'¢_-~"--.~ Title EndicottOperations&ProductionLoadEngineer Form 10-404 Rev 06/15/88 / Date SUBMIT IN DUPLICATE .~. Endicott Production Engineering Department DATE: 13 May 1991 WELL N~: 3-01/N-29 BP EXPLORATION REP: SERVICE COMPANY: Additional Luedke-Chan Schlumberger Perforations (Schwartz/McBride) I DATE/TIME ] OPERATioNS SUMMARY 0730 RU. Post radio Silence signs at tile entrance to island and next to well site. Install SSV fusible cap. . FWIIP = 1523 pslg. FWilT = 138 de# F. 1AP = 0 psi#. OAP = 100 psi#. Choke = 50 Beans. Pressure test lubricator to wellhead pressure. 0900 ESTABLISH RADIO SILENCE AND ARM GUNS (Notify security). 0930 SI Well. 0940 RIH with Gun #1 (20 feet). SIwItP = 1550 psi#. 1040 Open wing valve and set production choke to 65 beans. 1055 Tie in to CBL dated 25-Jan-87. All of the depths listed below are from the open hole reference log. Flag llne for next run. FWIIP = 1435 pslg ~ 65 /104 bean choke. Hang gun gl Top Shot at 12437' MDBKB (CBT)~ 12440' MDBKB (DLL). 1110 Shoot gun gl from 12440-12460' MDBKB and flow well for 15-20 ,minutes. FWIIP = 1385 psi# @ 65 Beans. 1125 SI well and log collars through sliding sleeve while POH. 1300 RIH with Gun #2 (20 feet). SIWllP = 1710 pslg. 1345 Open wing valve. FWHP = 1155 pslg @ 65 Beans. 1354 Tie in to CBT logging up. Shoot gun # 2 from 12420-12440' MDBKB. FWIIP = 1345 psi# ~ 65 Beans. 1415 SI well and POH. 1530 RIH with Gun #3 (20 feet). SIWHp = 1540 Psi#. 1610 Open wing valve. FWItP = 1185 psi# (~ 65 Beans. 1620 Tie in to CBT logging up. Shoot gun # 3 from 12400-12420' MDBKB. FWtIP = 1240 pslg @ 65 Beans. 1630 SI well and POH. 1715 RIH with Gun #4 (10 feet). SIWlIP = 1590 psi#. 1800 Open wing valve. FWtIP = 12i5 pslg @ 65 Beans. 1825 Tie in to CBT logging up. Shoot gun # 4 frOm 12390-12400' MDBKB. FWHP = 1260 psi# @ 65 Beans. 1838 SI well and POH. 1950 RIH with Gun #5 (20 feet). SIWItP = 1500 pslg. 2020 Open wing valve. FWIIP = 1230 psi# @ 65 Beans. 2040 Tie in to CBT logging up. Shoot gun # 5 from 12360-12380' MDBKB. FWIIP = 1270 pslg @ 65 Beans. 2050 SI well and POH. 2~3,00 RIH with Gun #6 (20 feet). SIWIIP = 1525 psig. 2320 Open wing valve. FWItP = i120 psi# @ 65 Beans ..... 2326 Tie in to CBT logging up. ShOot gun # 6 from 12306-12326' MDBKB. FWtIP = 1265 psi# @ 65 Beans. 2340 SI well and POH. 0100 RIH With Gun #7 (20 feet). SIWtIP = 1520 psi#. 0130 Open wing valve. FWlIP = 1180 psi# {~ 65 Beans. 0140 Tie in to CBT logging up. Shoot gun # 7 from 12286-12306' MDBKB:__ FWHP = .!255_ psi#. @ 65 Beans~ 0150 SI well and POH. SIWHP = 1500 psi#. Confirm all shots fired. 0315 End radio silence. DATE: 13 May 1991 WELL N~: 3-01/N-29 TYPE OF OPERATION: Additional Perforations 0300 ] RD. POP. PERFORATION SUMMARY: GUN INTERVAL(DLL} ~ FEET SUBZONE 6-7 12286-12326 12284-12324 4 0 3A3 5 12360-12380 12357-12367 20 3A2 1-4 12390-12460 12387-12457 70 2B3/2B5 All intervals were shot using 2-1/8" carrier guns at 4 spf, 0 degree phasing and 0 orientation. JUN 11 1991 Alaska Oi/& Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1 Type of Request: Abandon ~ Suspend ~ Operation Shutdown ~ Re-enter suspended well ~ Alter casing Repair well ~ Plugging ~ Time extension ~ Stimulate ~ Change approved program ~ Pull tubing ~ Variance Perforate X Other~ 2. Name of Operator 5. Type of Well: 6. BP Exploration (Alaska)/nc. Development x Exploratory ~ 3, Address Stratigraphic 7, P. O. Box 196612, Anchorage, Alaska 99519-6612 service 4. Location of well at surface 8. 2535'SNL, 878' WEL, Sec. 8, T11N, R17E At topof productive interval 9. 1742'SNL, 2434' WEL, Sec. 5, T11N, R17E At effective depth 10. 1500' SNL, 2402' WEL, Sec. 5, T11N, R17E At total depth 11. 1546'SNL, 2396' WEL, Sec. 5, T11N, R17E Datum elevation (DF or KB) KBE = 55.34 feet Unit or Property name Duck Island Unit/Endicott Well number 3-O 1/N-29 SDi Permit number 86-190 APl number 50- 029-21678 Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured true vertical 13050 feet 10525 BKB feet Effective depth: measured 12960 feet true vertical 10453 BKB feet Plugs (measured) Junk (measured) Casing Length Size Cemented Measured d~Bh True vertical depth Structural BKB Conductor 122' 30" Driven 161' 161' Surface 2441' 13 3/8" 3534 c.f. Permafrost 2480' 2477' Intermediate 12073' 9 5/8" 575 c.f. Class G 12112' 9774' Production Liner 1220' 7" 387c. f. Class G 11830'-13050' 9548'-10525' Perforation depth: measured 12480'- 12520', 12546'- 12564', 12570'- 12600' true vertical (Subsea) 10018'- 10051', 10071'- 10086; 10091'- 10114' Tubing (size, grade, and measured depth) 4 1/2~ 12.6#/_-80 TD$ tub~rig w/th $1/2' 9.2# !_-80 ta//p/pe to 11,899' °%'. Packers and SSSV (type and measured depth) 9 518" SAB packer at 11,783'; 4 112 SSSV at 1595' 13. Attachments Description summary of proposal X Detailed operations program BOP sketch X 14. Estimated date for commencing operation April, 1991 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas__ Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed .~,X~7 ~ Title EndlcottRes. Studiesa~d Dev. LeadEngr. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test~ Location clearance ~ Mechanical Integrity Test~ Subsequent form required 10- ORIGINAL SIGNE0 BY Approved by order of the Commission LONNII~ C. SMITH Form 10-403 Rev 06/15/88 [Approval No. Appruved C&P°Ymmissi°ner ,Returned SUBMIT IN TRIPLICATE ENDICOTT FIELD WELL 3-01/N-29 We plan to perforate the following 3 intervals in this well to enhance offtake and improve vertical sweep: 12302'- 12326' BKB (Ref. DLL 1/21/87) 12360' - 12384' BKB (Ref. DLL 1/21/87) 12390'- 12460' BKB (Ref. DLL 1/21/87) A lubricator will be installed and pressure tested to 3000 psi for all well work. After the perforations are added, the SSSV will be reinstalled and tested. *DGR/CNO/SFD 10557' - 11463' Sperry Sun Run No. 1 *FORMATION MULTI-TESTER 10636' - 11182' Run No. 1 Atlas *CBT 10160 - 11348 Schlumberger Run No. 1 *CET 10160' - 11370 Schlumberger Run No. 1 WELL 2-22/L-14 *TEMPERATURE LOG 11080' - 12235' Camco Run No. 2 WELL 2-36/O- 14 *COLLAR LOG 10160' - 11260' Atlas Run No. 1 WELL3-01/N-29. STATIC TEMPERATURE SURVEY 12250' - 12953' Run No. 1 Camco ,,,WELL 3-07/N-28 *TEMPERATURE LOG 13000' - 13400' Camco Run N°. 1 WELL 3-39/J-39 *TDT-P 14120' - 14636' Schlumberger Run No 1 WELL 3-49/J-40 *DUAL STATIC SURVEY 14922' - 14934' Schlumberger Run No. 1 WELL 4-04/T-26 *INJECTION PROFILE LOG 13575' - 13975' Run No. 1 Camco *TEMPERATURE LOG 13100' - 14037' Camco Run No. 1 BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 September 25, 1989 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Endicott Field - Bottom-Hole Pressure Reports Dear Sirs: Enclosed are Bottom Hole Pressure Reports for the following wells. Well Name Date 2-28/P-19 3-01/N-29 3-05/0-29 3-35/L-36 3-47/Q-35 08-16-89 08-21-89 08-19-89 08-2~.-89 08-15-89 If there are any questions regarding this data, please contact Dave MacDonald at 564-4697. Sincerely, ./~a-nne L. Haas JLH Enclosures cc: File: 76.13 SEP2 (~~ Naska Oil & Gas Cons. C0m~'tsslO. D · Anchorage *DUAL LATEROLOG MICROSHERICALLY FOCUSED LOG 13482' - 14090' Run No. 1 HALLIBURTON *CEMENT EVALUATION LOG (CET) 12500' - 13985' Run No. 1 SCHLUMBERGER *CEMENT BOND LOG (CBT) 12500' - 13965' Run No.1 SCHLUMBERGER *TCP GUN POSITIONING LOG 13454' - 13750' Run No. 1 SCHLUMBERGER WELL 1-45/Q-26 ~ *CEMENT BOND LOG (CBT) 12792' - 14181' Run No. 1 SCHLUMBERGER *CEMENT EVALUATION LOG (CET) 12792' - 14181' Run No. 1 SCHLUMBERGER *GRCCL- PACKER RECORD 12850' - 14172' Run No. 1 SCHLUMBERGER WELL 1-67/T-20 *GAMMA RAY TEMP LOG 11500' - 12041' CAMCO Run No. 1 WELL 2-52/S-14 *TEMPERATURE SURVEY 11600' - 12670' Run No. 1 CAMCO WELL 3-01/N-29 *DUAL BURST TDT LOG (TDT-P) 11845' - 12947' Run No. 3, SCHLUMBERGER WELL 2-46/Q-15 '~~PCF LOG 10500'-11110' Run ATLAS WIRELINE SERVICES WELL 2-28/P-19 MPI *DIFFERENTIAL TEMPERATURE LOG 10000'-10440' Run 1 CAMCO WELL 3-'01/N-29 *STATIC TEMPERATURE SURVEY 12150,-12940' Run 1 CAMCO ~ WELL 3-47/Q-35 ~.. *DIFFERENTIAL TEMPERATURE LOG 9725'-11254' Run 1 CAMCO WELL 4-46/N-3~) *CEMENT BOND LOG 12272'-12324' SCHLUMBERGER Run 1 WELL 4-46/N-39 *COMPLETION RECORD (POSITION TUBING) 11296'- 11758' Run 1 SCHLUMBERGER WELL 4-46/N-39 *CEMENT EVALUATION LOG 12272'-12345' Run 1 SCHLUMBERGER 1092/GND BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 July 24, 1989 John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Boyle' Enclosed please find one sepia and one blueline print for the well logs run in the following Endicott wells: '"'""-~ELL 1-63/T-22 APl No 50 029 21905 Run No. 2 *PRODUCTION PROFILE 12000'-12660' 6/7/89 5 inch log scale cased hole well _ logged by Camco WELL 3-41/K-39 *COLLAR LOG 13300'- 13638' 5 inch log scale APl No 50 029 21878 Run No.1 6/12/89 cased hole well logged by Atlas Wireline Services ~'""~WELL 3-01/N-29 APl '50 029 21678 Run No.1 *SPINNER HP PRESSURE TEMPERATURE LOG 12280'- 1'2730' 4/23/89 5 inch log scale cased hole well logged by Halliburton WELL 2-70/U-15 APl 50 029 21899 Run No.2 *PERFORATING RECORD 11190'-12050' 6/19/89 5 inch log scale cased hole well logged by Schlumberger '~~ WELL 2-68/S-17 APl 50 029 21858 Run No.1 ""---._)*PRESSURE BUILD UP SURVEY 10023'-11200' 3/24/89 no log scale cased hole well '~ PRODUCTION LOG 10600' -11000' 6/11/89 5 inch log scale cased hole well logged by Schlumberger WELL 1-27/P-20 APl 50 029 21693 Run No.1 ~*PRODUCTION PROFILE LOG 990o'- 10850' 6/27/89 5 inch log scale cased hole well logged by Camco WELL 2-22/L-14 .APl 50 029 21931 "'"-"*INJECTION PROFILE LOG 11748'-12100' 6/14/89 5 inch log scale cased hole well logged by Camco Run No. 1 ,. W~ 2-04/M-19 APl 50 029 21586 Run No.1 TEMPERATURE LOG 10100'-10660' 6/13/89 5 inch log scale cased hole well logged by Camco WELL2-08/K-16 APl 50 029 21676 Run No.1 '"'""~PRODUCTION PROFILE LOG 11700'- 12200' 6/9/89 5 inch log scale cased hole well logged by Camco WELL 3-17/J-30 APl 50 029 21946 "'"--'*CEMENT EVALUATION LOG 13040'- 14004' 7/3/89 5 inch log scale cased hole well ~ CEMENT BOND LOG 103040' - 14004' 7/3/89 5 inch log scale cased hole well "'"'-J GAMMA RAY - CCL 13100' - 13700' 7/5/89 5 inch log scale cased hole well logged by Schlumberger Run No. 1 WELL 4-50/K-41 AP! 50 029 21940 "'"J'PERFORATING RECORD 13553'-13564' 6/22/89 Run 1 ~,,~.5 inch log scale cased hole well PERFORATING RECORD 13260' - 13820' 7/8/89 Run 2 5 inch log scale cased hole well logged by Schlumberger Run No.1 & 2 WELL 2-46/Q-15 APl 50 029 21921 Run No.1 '-,,w-PRODUCTiON PROFILE 10600'-11000' 6/21/89 2 & 5 inch log scale cased hole well '""'*TEMPERATURE SURVEY 10600' - 11100' 6/24 & 25/89 2 inch log scale logged by Otis WELL 3-17/J-30 APl 50 029 21946 Run No.1 '"'--' *DUAL LATEROLOG MICROSPHERICALLY FOCUSED LOG 13382'- 14102' 3/8/89 ~2 & 5 inch log scale open hole well *COMPENSATED SONIC LOG 13382' - 14080' 6/29/89 2 & 5 inch log scale open h01e well ~*DUAL INDUCTION LATEROLOG 13382' - 14105' -6/29/89 2 & 5 inch log scale open hole well ~ *SPECTRAL DENSITY DUAL SPACED NEUTRON LOG 13382' - 14103' 6/29/89 2 & 5 inch log scale open hole well *FORMATION TEST LOG no depths 6/29/89 no log scale open hole well logged by Halliburton Sincerely, GD/Ims cc: File 06.10 Gas Cons. Commiss~[~ BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 May 23, 1989 Mr. J. Boyle AOGCC 3001 Porcupine Dr. Anchorage, Alaska 99501 Dear Mr. Boyle: Accompanying this letter are reprocessed TDT-P data, including bluelines, sepias, and tapes, for the following wells: Sag Delta 7 ~ N-29 Sag Delta 10 ~ O-23 J-18 ~ ~O-25 ~J-19 ~O-29 K-33 ~ "'* P-17 ~., M-19 "P-20 M-25 ~ "~ ~' P-24 M-30 ~, Q-32 N-22 In January of this year, Schlumberger modified their TDT-P software. Previously processed logs then became unsuitable as baselines for fluid monitoring with newly processed logs. Consequently, Schlumberger agreed to reprocess previous TDT-P data with the new so,ffware, and we now have a full set of standard format, consistently processed logs for monitoring fluid movements. If any further questions arise over the reprocessing of TDT-P logs in Endicott please contact J.H. Dupree (907) 564-4797 G.W. Geehan Manager Endicott Geoscience GWG/GD/Ims STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAI S 1. Type of Request: Abandon ~ Suspend ~ Operation Shutdown __ Re-enter suspended well~ Alter casing__ Repair well ~ Plugging ~ Time extension ~ Stimulate X Change approved program ~ Pull tubing ~ Vanance __ Perforate ~ Other 2. Name of Operator BP Exploration (Alaska)/nc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development X Exploratory ~ Stratigraphic__ Service 6. Datum elevation (DF or KB) KBE = 55.4 feet 7. Unit or Property name Duck/s/and Unit/Endicott 4. Location of well at surface 8. 2531' SNL, 848' WEL, Sec. 8, T11N, R17E At top of productive interval 9. 1984' SNL, 3336' WEL, Sec5, T11N, R17E At effective depth 10. 1287'SNL, 3392' WEL, Sec. 5, T11N, R17E At total depth 11. 1230' SNL, 3398' WEL, Sec. 5, T11N, R17E Well number 3-07/N-28 SDI Permit number 89-12 APl number 50- 029-21911 Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 13550 feet Plugs (measured) 10545 feet BKB 13468 feet Junk (measured) 10487 feet BKB Casing Length Size Cemented Measured d~ ,p,t ~ Structural Conductor 92' 30" Driven 131' Surface 2463' 13 3/8' 2690' c.f. Permafrost 2502' Intermediate 12465' 9 5/8' 575'c.f. C/ass G 12504' 12504' Production Liner 1343' 7" 410 c.f. C/ass G 12207'- 13550' Perforation depth: measured 13130'-13270' true vertical (subsea) 10194'-10292' Tubing (size, grade, and measured depth) 4 1/2" 12.6# L80 TDS with 3 1/2" tailpipe to 12270'. Packers and SSSV (type and measured depth) 9 5~8"packer at 12157'; 4 1/2" SSSV at 1555'. True vertical deCh BKB 131' 2500' 9811' 9604~10545 13. Attachments Description summary of proposal X Detailed operations program BOP sketch X 14. Estimated date for commencing operation April20, 1989 16. If proposal was verbally approved Name of approver Lonnie Smith 4/14/89 Date approved 15. Status of well classification as: Oil Gas Service Water Injection Suspended 17. I hereby...certif, y that the_/f'~egpincj ~'s true and correct to the best of my knowledge. Signed ~//~~~~' Title Manager, Reservoir & Production Engineering Date '/TZ'/(~.~'~ ,/'/ ' ' - f FOR COMMISSION USE ONLY Condit~ns//of approval: Notify Commission so representative may witness I Approval No. / / Plug integrity BOP Test Location clearance -- ~,/ Mechanical Integrity Test '~-ubsequent form required 10- ORIGINAL SIGNED BY Approved by order of the Commission LONNIE C. SMITH 'C~)ate Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE WELL 3-07/N-28 REMEDIAL WORK JUSTIFICATION AND HISTORY Well 3-07/N-28 was drilled as a zone 2A water injector. It was perforated using drill pipe conveyed guns. The perforated interval was 13130-13270 MDBRT referenced to the DLL-GR 3/2/89. This is in the aquifer. After perforating, the well inflowed formation water to surface at an average flow rate of 5700 bpd. FWHP went to zero psig as formation water reached surface. At this point, an unsuccessful attempt was made to kill the well with 9.0 PPG brine. A sized salt kill pill was successfully pumped and the well was killed. The completion proceeded and the well was left with a column of diesel to the sliding sleeve. The well was then tied in as a water injector and not preproduced. The initial attempt to inject water 3-5-89 showed a 300-500 bwpd rate at maximum header injection pressure of 2800 psig. After 7 days of minimal injection and no improvement, the well was then shut-in and freeze protected. 35 bbls diesel was pumped at 0.5-1.0 bpm at 4000 psig surface pressure. This applied up to a maximum of 8500 psi of B HIP. Recommended maximum overbalnces for sized salt pills are approxamately 500 psig. Sustained excessive overbalances applied to salt pills cause the polymer carrying agent to dehydrate and form an impermeable filter cake. This appears to be the explanation for the poor injectivity into well 3-07/N-28. Data'base information from M-I Drilling Fluids indicate that the best way to correct this situation is to create an underbalanced situation and suck the material from the perf tunnels. Also, this polymer filter cake material is soluable in 15% HCL and would be easier to clean up if acid was spotted also. OPTIMIZE ~lttE NITROGEN INJECTION VOL..,ME TO MAXIMIZE LIQUID RATE RECOVERY AND MINIMIZE NITROGEN CONSUMED, WITH THE EMPHASIS ON MAXIMIZING LIQUID RATE.. THIS SHOULD OCCUR AT AN APPROXIMATE TOTAL GAS TO LIQUID RATIO OF 1200-1500 SCF/BBL. 12) ASSUMING THE WELL WILL INFLOW, CONTI:NIJE TO NITROGEN LIFT. 13) CATCH 1 QUART SURFACE SAMPLES TO ATTAIN BOTTOMS UP LIQUIDS. ONCE BOTTOMS UP OCCURS, SAMPLE EVERY HOUR FOR THE REMAINDER OF THE FLOWPERIOD. HAVE SAMPLF. S ANALYTF~D AT ENDICOTT LAB FOR BS&W AND Ph. 14) MONITOR THE LIQUID RECOVERED THROUGH THE TEST SEPARATOR UNTIL-EITHER 5 TUBING VOLUMES, 1600 BBLS, IS RECOVERED OR UNTIL THERE IS NO NITROGEN LEFT IN THE TRANSPORT. 15) POH WITH CTU. 16) RIG DOWN CTU AND NITROGEN UNITS. 17) ATTEMPT TO INJECT USING THE MAXIMUM AVAILABLE PRESSURE SUPPLIED FROM THE PLANT, (APROX 2800 PSIG). MONITOR FOR INJECTION. RAMP UP INJECTION RATE IN INCREMENTS. OBJECTIVE INJECTION RATE IS 12 MBWPD. NOTIFY ANCHORAGE ENGINEERING IF AT THIS POINT, 10 MBWPD CAN NOT BE ACI--IIF. VED. 18) IF THE WELL WILL NOT INJECT AT THIS POINT, MAKE ARRANGEMENTS TO FREEZE PROTECT THE WELL USING A HOT OIL TRUCK. PRESSURE TEST LINES TO 5000 PSIG. PUMP DIESEL AT A MAXIMUM WHP OF 4500 PSIG IN AN ATTEMPT TO BREAK DOWN FORMATION AND ESTABLISH INJECTIVITY. IF THE INJECTIVITY INDEX INCREASES AND THE FORMATION BREAKS DOWN, RESUME WATER INJECTION. IF NO BREAKDOWN IS SEEN WlqlLE PUMPING DIESEL AS SOME. RESTRICTED RATE, CONTINUE TO FINISH PUMPING DIESEL AND LEAVE WELL SHUT-IN. 19) IF AFTER ATTEMPTING TO CLEAN UP THE PERFS BY NITROGEN LIFTING, THE WELL DOES STILL NOT TAKE ACCEPTABLE INJECTION VOLUMES, A PROBABLE MUD ACID STIMULATION WILL BE FORWARDED. WELL ~-@7/N-28 HCL PERF WASH AND CLEANUP 1) RU SLICKLINE AND PULL SSSV. MAKE DRIFT RUN. 2) RU COILED TUBING UNIT, ACID TRANSPORT, NITROGEN PUMPER, AND FULL NITROGEN TRANSPORT. RIG UP A PUMP-iN SUB (SEE STEP 8). 3) RIG UP UTILIZING A TUBING END LOCATOR TO ASSUR_E DEPTH CONTROL. PRESSURE TEST TO 5000 PSIG. ASSURE STRIP CHART RECORDER IS OPERATIONAL. 4) RIH WITH CTU. CORRELATE THE E-LINE REFERENCED TUBING TAIL DEPTH TO THE iNDICATED TUBING TAIL DEPTH AND TIE-IN NOZZLE. RECIPRICATE THE ACID SOLUTION VOLUME OF 47 BBLS ACROSS THE PERFORATED INTERVAL FROM 13130-13270 MDBRT AT 10-20 FPM. PUMP AT'THE MAXIMUM RATE WITHIN THE SURFACE WELLHEAD INJECTION PRESSURE LIMITATION OF 4500 PSIG. RECOMMENDED ACID ADDITIVES AND VOLUMES ARE AS LISTED FOR A 2000 GAI J.ON ACID VOLUME: 15% HCL, 0.2% SURFACTANT, 0.4% INHIBITOR, AND IRON SECQUESTRENT AS RECOMMENDED BY VENDOR. NOTE- NO EMULSION/SLUDGE TESTING NECESSARY DUE TO THE WELL BEING COMPLETED IN THE AQUIFER. 5) DISPLACE ALL ACID OUT OF CTU WITH DIESEL. POH. 6) LEAVE THE WELL SHUT-IN FOR A FOUR HOUR SOAK PERIOD. 7) RIG UP CHICKSAN FROM A PUMP IN SUB ON WELL 3-07/N-28 TO AN ADJACENT WELL. TIE-IN AT THE OTIS QUICK CONNECT ABOVE THE SWAB VALVE. SHUT-IN THE TIE-IN WELL AT THE MASTER SO AS TO UTILIZE IT FOR FLOWBACK OF WELL 3-07/N-28. 8) OPEN THE PRODUCTION CHOKE FULL OPEN ON THE ADJACENT TIE-IN WELL AND LINE UP THROUGH THE HIGH FLOW TEST SEPERATOR. ZERO THE CTU COUNTER REFERENCED TO THE ROTARY TABLE. RIH WITH COILED TUBING AND BEGiN PUMPING NITROGEN IMMEDIATELY TO DISPLACE THE DIESEL OUT OF THE CTU. DO NOT GO DEEPER THAN 2000 FT UNTIL NITROGEN IS DISCHARGING OUT OF NOZZLE. RIH PUMPING NITROGEN TO LIGHTEN THE TUBING DIESEL AND WATER AND ESTABLISH INFLOW. 9) CONTINUE TO INCREASE NITROGEN RATE AS NECESSARY. SAMPLF. RETURNS TO CONFIRM LIQUID MOVEMENT. 10) CONTINI.JE TO RIH WITH CTU. INCREASE THE NITROGEN RATE IN INCREiMENTAL STEPS WHILE RIH TO DRAW THE BHP AS LOW AS POSSIBLE TO ESTABLISH INFLOW AT THE PERFORATIONS. 11) STOP CTU NOZZLE AT APPROXIMATELY 12100 FT. BASED ON THE LIQUID RETURNS AS MEASURED IN THE SEPERATOR, BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 March 29, 1989 John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Boyle: Enclosed please find one sepia and one blueline print for the cased hole well logs run in the following Endicott well: WELL 3,01/N-29 *DUAL,.,,.,.P-~ ,~T,,_,, TDT LOG 11850'- 12952' Run No. 2 WELL 2-04/M-19 *DUAL BURST TDT LOG 9800'-10690' Run No. 2 Logged By Schlumberger Sincerely, Gregory ~. ~lard / %~/' - ~_~)~ '~ Standard Alaska Production Company 900 East Benson Boulevard PO. Box 196612 Anchorage, Alaska 99519-6612 (907) ,561-5111 November 17, 1988 STANDARD ALASKA PRODUCTION Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Endicott Field - Bottom-Hole Pressure Reports Dear Sirs' Enclosed are Bottom Hole pressure Reports for the following wells in the Endicott Reservoir: Well Name Date 1 -29/M-25 1-35/O-25 3-01/N-29 3-1 l/M-30 3-1 l/M-30 3-27/M-33 (Upper) (Lower) 10-23-88 10-24-88 10-23-88 10-02-88 10-02-88 10-02-88 If there are any questions regarding this data, please contact Loren Twyford at 564-4401. Sincerely, JLH A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 11:170. Standard Alaska ~ Production Company 900 East Benson Boulevu,d P.O. I~x 196612 Anchorage, Alaska 99519-6612 (907! ,561-5111 STANDARD ALASKA PRODUCTION -, · August 11, 1988 John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re' Endicott well log information Dear Mr. Boyle: Enclosed please find one sepia and one blueline print for the cased hole well logs run in the following Endicott Well: · ..... 7 *Temperature/CCL Run date' 7-21-88 Logging Company: Otis Run 1-7 date: 7/26-27/ Run 8-13 date' 7/28-29/88 ~ Logging Company' Otis Run 1-8 date: 7/26/88 Run 9 date: 7/28/88 Logging Company: Otis A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. Sincerely, · Jeanne L. Haas Date Standard Alaska Production Company 900 East Benson Boule P.O. Bo x 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 APR 15, 1988 STANDARD ALASKA PRODUCTION John Boyle Alaska Oil and 3001 Porcupine Anchorage, Gas Conserva t ion Drive Alaska 99501 Commission Dear Mr. Boyle The following log information for~~'~ '~ '~ 1 sepia and blueline print for; · Run~ Mar. 28, 1988 wells is enclosed: * Dual Burst TDT-P APR 1 '8 1988 Re.ce 0il & Gu 00ns. ~:~'l~l~i:~;'~ ~ Anol'lomge Sincerely, Bruce S t. Date A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. I I ~1 m I II I ~":~' , I I I II1! II I I ~ I I I I X" 25114&.41 E" 464036.43 &~ Y' ~98219~.68 N' 7g0~236.26 70~21'07.28~2' 147c~7'26.0&10' 2221.4~ 2218.1& I~ 258980.00 [' 464077.&4 ~ 66 ~Y' 5~822~3.1B' N' 7B052~5.17 70-21'0B.0¢~7" 147'57'30~2206'" 2128.45 23b0.45 X- 258840.75 E' 4640~4.7~ ..... ~---Y'--5~'B21B-7.'4*--' N=- ~B0525~: 64 .... 70-2-i';-07. I02," - 1-47 -~-7";~6. 2208' X- 258974.26 E- 464075.9~~' -- . 68 Y- 5982284,99 N- 7805262.64 ~ 70:21'08.0173" 147'57'30.3805" 2136.82 . 2365.92 :: x, 2~ea~5.0t E- 4640~3.02 J : : ' X- 2513968 5~ ,. E-":464074.2~ 70 Y- 5982276.10 N- 780~260.12 70c21'07.9350· ' 147c~7'30.5403· 2145.19 2371.39 I- 258829.28 E- ~$4031.31 , i , . ,~ . .. . -. . . M PI PRO.SE O WE~ L~ATION LIST .,~ ~ ~aS CoBo. Ou~,l~a.~.~.. P R E PARE D FOR SOHIO ALASKA PETROLEUMCO. '*~.~.,*' ~. 69194//_]~_/~.' ORW. NO. I,6-a5 PREPARED BY ~TE: NOV. '3, ~IZo~--. ,~ F.R BELL ~ ASSOC. ...~ ~~ ~ SHEET G of I0 ' SC~E : N/A qk~'~ss~~~ PRUDHOE BAY OFFICE Standard Alaska Production Compa~ 900 [~ost ~enson Bou ,J PO Box 196612 Anchorage Alaska 99519 6612 /907~ 561-5111 JAN 11, 1988 STANDARD A[ A,qKA P~(/)i)~J( I ION John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Boyle: The follouing log information for gndicott wells is enclosed: 1 Sepia and blueline print for: 3-01/N-29 Run ] December 5, 1987 * P~-oduction Profile Sincerely, ~Bru~e ~t~.~ierre Date Standard Ala~. Production Co, 900 East Benson P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DEC 28, 1987 STANDARD ALASKA PRODUCTION John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Boyle: The following log information for Endicott wells is enclosed: 1 Sepia and blueline print for: 3-1/N-29 Run 1 December 5, 1987 * Production Profile (field print) !~ 0il & ~a~ Co~-~. Co~nrr]issio~ t.~/ A~chorag~ ' Date Sincerely, Bruce St. Pierre A unit of the or,g'nat Standard Oil Company Founded m Cleveland Ohio in 1870. Standard Alaska Production Com~ 900 East Benson B~ ,yard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907t 561-5111 OCT 1, 1987 STANDARD ALASKA PRODUCTION William Van Alen Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Van Alen: The following log information for Endicott wells is enclosed: 1 sepia print and 1 blueline print for: N-29 Run 1 August 27, 1987 * GR Positioning Log Da t e~/~aska Gas 00as. 00m~BB~ll A unit of the onginaJ Standard OiJ Company Founded in Cleveland Ohio in 1870 ~ STAT.E OF ALASKA ALASKJlIII~ AN D GAS CONSERVATION ~N WELL COMrPLETIO,N OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2, ·Name of Operator 7. Permit Number Standard Alaska Production Company 86-190 3. Address 8. APl Number P. O. Box 196612 Anchorage, Alaska 99519-6612 50-029-21678 4. Location of well at surface 9. Unit or Lease Name 2535' SNL, 878' WEL, Sec. 8, TilN, R17E Duck Island U~t/ Endicott At Top Producing' Interval 10. Well Number 1742'SNL, 2434' wEL, Sec. 5, TllN, R17E .3.-_1/~r29 SDI At Total Depth 11. Field and Pool 1546' SNL, 2396' WEL, Sec.5~ TllN, R17E . Endicott Field 5. Elevation in feat (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Endicott Pool 55.34' = KBE ADL 47502 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Cornpletions 12-28-86 1-22-87 8-29-87 ~/A feet MSL one 17. TotaIDepth,MD+TVD) .!8. PIugBackDepth(MD+'I'VD, 19. DirectionalSurvey [ 20. Depth where SSSV set I 21. Thickness of Permafrost 13050'MD 10525'TVI~12960'MD 10453'TV)YES~ NO[] 1595. feetMD 1536' 22. Type Electric or Other Logs Run Submitted with 10-404 Feb.. 1987 NGT, LDT/CNL, FMS~ DLL/MSFL; S'DT MWD Resistivity Gamma, CBT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 30" Structural Drive Pi~ Ru~.~ 1Rq ~ 13,3/8" 689 L-80 Surface 2480" 17%'" 3534 cu.ft. Permafro: t .. 9-5/8" 47# NT80S Surface 103~ ,. 12%- 9-5/8" 47# NT95HS 103~' 12111' 12%" 575 cu.ft. Class G ' 5%CFR2+.12% HR7 7" 29# SM 110 11830' 13050' 8~" 387 cu.ft. Class G 0 5% Halad 344 .3%I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size a~d aumber~ SIZE DEPTH SET (MD) PACKER SET (MD) ::. 4~" L-SO 12 6# 11769' 11783' MD / TVDSS 3¼" L-80 9.~ # 11898' 12480 ' -12520 ' 10018 ' -10051 ' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 12546 ' -12564 ' 10071" -10086 ' DEPTH I~NTERVAL (.MD) AMOUNT & KiND O'F MATERIAL ~jSErD 12570' -12600' 10091'-10114' 9-5/8" x 13-3/8't Downscueeze 9-5/8" w 1 ~-~/R" 27, PRODUCTION TEST Date First Production October 1987I Method Of Operation {Flowing, gas .lift,etc.) Flowing Date of Test Hours Tested PRODUCTION F'OR OIL-BBL GAS-MCF WATER-'BBL CHOKE SIZE I GAS~OIL RATIO TEST ~ERtOID '~ Flow Tubi'ng C~aei~g Pressure' CALCULATED ~! O'IL-B!BL GAS~MCF WAT.ER-BBL O'lL GRAVITY-APl ~Corr~ Press. 24~HO~IR R ATE 28. CDR E DATA Brief description of l ithology, porosity, fracturas, apparent dips and presence of oil, gas or wats r. Submit core Chips. Submit in duplicate Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. G EO LOG lC. MAR KE RS NAME Top HRZ Put River Top Kekiktuk MEAS. DEPTH 11812' 12126' 12150 ' TRUE VERT. DEPTH 9479' 9730' 9750' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Division f~.~- ~ ~~__. ~ Drilling Signed ' ' Title Engineer Date ._ . INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none" Form 10-407 Rig: PAA #7 Well: YlIN-29 (SDI) Daily Drilling Report -- ENDICOTT August 26, 1987 at 0600 hrs STANDARD ALASKA PRODUCTION Ckavent Opcradon: Mud Type: Brine SURVEY MD 0600 Depth: 12 960' Day: 31 24-Hour Ftg: -' N/U BOPE. Accept rig at 2300 hrs on 8-25-87. Install 2-way check valve in hanger. NID tree and N/U BOPE WT: 9.6 VIS: PV: YP: FL: SOLIDS: TEMP: °F ANGLE DIRE(THON TVD SECTION COORDINATES DLS Rig: PAA #7 Well: 3-1/N-29 (SDI) Daily Drilling Report .- ENDICOTT August 27, 1987 at 0600 hrs STANDARD ALASKA PRODUCTION Ch~ent Operation: Mud Type: Brine 0600 Depth: 12 960' Day:. 32 24-Hour Ftg: -' Running in hole to perforate. NU BOPE. RIH. Displace hole with filtered brine water. POH. Pickup perf. guns and RIH. WT: 9.6 VIS: PV: YP: FL: SOLIDS: TEMP: °F AN(~LE DIRE(?FIQN TVD SECTION COORDINATES DLS Rig: PAA #7 Well: 3-1/N-29 (SDI) Daily Drilling Report -- ENDICOTT August 28, 1987 at 0600 hrs STANDARD ALASKA PRODUCTION Chh'rent ~tion: Mud Type: Brine SURVEY MD 0600 Depth: 12960' Day: 33 24-Hour Ftg: -' Run 4-1/2" robing. RIH with perf. guns. Perforate and flow well to surface. Reverse circulate well fluids to tank. POH with guns. Rig up and run 4-1/2"tubing. WT: 9.6 VIS: PV: YP: FL: Solids: Temp: OF ANGLE DIRECTION TVD SECTION COORDINATES DLS STANDARD ALASKA PRODUCTION Rig: PAA #7 Well: 3-1/N-29 (SDI) Daily Drilling Report -- ENDICOTT August 29, 1987 at 0600 hrs 0600 Depth: 12960' Day: 34 72-Hour Ftg: -' Current Operation: Releasing rig. Run and land 4-1/2" completion string. Nipple down BOP. Nipple up tree and test. Set plug in tailpipe. Set packer and test tubing annulus to 2500 psi. Open sliding sleeve. Displace robing to diesel. Close sliding sleeve. Install back pressure valve in tree. Released rig at 0600 hrs on 8/29/87. Mud Type: Brine WT: 9.6 VIS: PV: YP: FL: Solids: Temp: OF SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS SOHIO ALASKA PETROLEUM CO. Controlled Drilling Consultants, Inc. LES HENDERSON 333-1552 CONTROLLED DRILLING CONSUL, ,ANTS, INC. 4234 }~INGSTON' DR. Anchorage, Alaska' 99504 (907) 333-1552 . January 27, 1987 Mr.. Brian Rose Standard Alaska Production Co. Pouch 6-612 Anchorage, AK 99502 RE: Magnetic Single Shot Survey Job No. 1286-027 Well N-29 (32-5-11-17) Endicott North Slope, Alaska Date of Survey 12~27-86 to 01-17-87 Dear Mr. Rose: Please find enclosed the "Original" and six (6) Copies of our Magnetic Single Shot Survey on the above well. The method used in calculatin§ this survey was Radius of Curvature. The depth. of the survey was 0 to 12,133. Thank you for giving us this opportunity to be of service. Yours very truly, Controlled Drilling Consultants, Inc. C.W' Harrington Directional Supervisor STANDARD ALASKA PRODUCTION ¢OHPANY · MAGNETIC SINGLE SHOT SURVEY RADIUS OF CURVATURE ME~HOD OF COMPUTATION ENGINEER C,W HARRINGTON?TERRY HENDERsoN WELL N-29 KB ELEV 55,34 FT, SURVEY DATE 1.-,','.' o~ i .35 1772 10,87 W i0.92 N 84 38 80.27 B 139,77 N 35 2 53 W 2.170 COHPUTER,~ 21 KB ELEV 55. S4 'ET, DEPTH ~HGLE DEPTH SE~ DIREC DISTANCE ANGLE DE'G/~ OOFT DISTANCE 5 15 W 2.450 599,60 N ~9 10 58 W 0 W 1 ,093 :3084,69 DISTANCE ANGLE DEG?i00FT ~I~T~NuE 5871,77 ,C. OMP~ TER- 2 ~ KB ELE~ 55,34 .00 $ . oo 955 9~, 900 0 0 2. ?'3 N ,89 E ,9~ N ~,95 W 2500 2 1 28.30 N 51,14 W DEPTH AHD OTHER DATA FOR EVERY EVEN 1 O0 FEET OF SUB SEA DEPTH. 3655, 3~00 40 44'00 220 38 808.94 N :307,8:9 W 5813 5255, 5280 557 42 544.99 N 786.35 ~ SOHIO WELL 29 SINGLE SHOT SURVEY JO'B~'NO MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN I O0 FEET OF .,OB SEA DEPTH, CONPUTER- 21 KB ELEV 55,34 9?55 7955-, 7900 1799 42 4349. i300,77 W 8700 2.095 29 5080,56 N 1451 .47' N 1526.05 W SOHIO ~ELL R-I 286-027 ~OMPUTER- 21 KB ELEV 55.34 9~80~0 ~429. 7374, 3~320,08 N 1 t 8.3.79 W HORIZONTAL VI EW RADIWELL~r'A N D'~,RDusN_291,,=OF ALASKAcuRVATURE(:52_5_i 1-17)PRODUCTION CO. _ . - - ! ...... i '' ,, . ........ ~ · · . . [ " . . ~ - . _ . , - . . f SUB-SURFACE DIRECTIONAL SURVEY ~UIDANCE r~'l ONTINUOUS [-~"1 CO L Company STANDARD ALASKA PRODUCTION COMPANY W~ll Nafll~ 3-1/N-29 SDI ('2535' FNL~ 878' FF].~SEC 8~TllN,R17g) F~ld/LOcatlOl3 ENDICOTT~ NORTH SLOPE, 6LASKA Job Reference No. Date. 72176 25-JAN-87 ~ Computed By; RUBENSTEIN KRUWELL GCT DIRECTIgNAL S~RV~Y CUSTOMER LISTING FO~ STANDARD ALASKA PRODUCTION CC 3-1/N-29 SOI ENDICOTT NORTH SLCPE,ALASKA SURVEY DATE: 25-JAN-ST ENGINeeR: RUBENSTEIN METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPCLATION: LINEAR VERTICAL SECTION: HORIZ. ~IST. PROJECTEC ONTO A TARGET AZIMUTH ~F NORTH 14 ~EG 50 MIN ~EST COMPUTATION DATE: 1-FEB-87 PAGE STANDARD ALASKA PRODUCTION CO DATE OF SURVEY: 25-JAN-87 3-1/N-29 SDI ENDICOTT NORTH SLOPE,ALASKA KELLY BUSHING ELEVATION: ENGINEER: RUBENSTEIN INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0.00 0.00 -55.34 0 0 N 0 0 E 100.00 100.00 44.66 0 13 N 4 3 E 200.00 200.00 144.66 0 12 N 14 18 W 300.00 300.00 244.66 0 12 N 1i 15 E 400.00 400.00 344.66 0 6 S 1 7 E 500.00 500.00 444.66 0 14 N 67 10 ~ 600.00 600.00 544.66 0 13 N 30 16 E 700.00 700.00 644.66 0 4 S 81 47 W 800.00 800.00 744.66 0 15 S 10 21 W 900.00 899.99 844.65 0 15 S $0 51 E 1000.00 999.99 94..65 1100.00 1099.99 1044.65 1200.00 1199.99 1144.65 1300.00 1299.99 1244.65 1400.00 1399.99 1344.65 1500.00 1499.98 1444.64 1600.00 1599.77 1544.43 1700.00 1699,56 1644.22 1800.00 1799.42 1744.08 1900.00 1899.29 1843.95 0 3 S 21 19 W 0 13 S 37 2 W 0 17 S 32 43 E 0 19 S 73 14 E 0 14 S 88 19 E 2 19 S 85 20 W 3 53 N 89 9 W 3 21 N 86 33 W 2 48 N 75 43 W 3 0 N 70 14 W 2000.00 1999.15 1943.81 2100.00 2098.96 2043.62 2200.00 2198.74 2143.40 2300.00 2298.52 2243.18 2400.00 2398.31 2342.97 2500.00 2498.12 2442.78 2600.00 2597.93 2542.59 2700.00 2697.64 2642.30 2800.00 2797.02 2741.68 2900.00 2895.99 2840.65 3 17 N 64. 47 W 3 44 N 60 36 W 3 48 N 55 27 W 3 45 N 51 8 W 3 37 N 43 16 W 3 25 N 41 16 w 3 41 N 42 39 W 5 24 N 25 37 ~1 7 21 N 16 44 W 9 6 N 17 13 W 3000.00 2994.27 2938.93 11 53 3100.00 3091.65 3036.31 14 12 3200.00 3188.20 3132.8& 15 47 3300.00 3284.12 3228.78 17 8 3400.00 3379.28 3323.94 18 37 3500.00 3473.63 3418.29 20 5 3600.00 3566.94 '3511.60 22 9 3700.00 3659.05 3603.71 23 28 3800.00 3750.33 3694.9'9 24 57 3900.00 3839.97 3784.63 27 45 55.34 FT VERTICAL gOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/S~UTH EAST/WEST gIST. AZIMUTH FEET CEG/iO0 FEET ~EET FEET OEG MIN 0.00 0.00 0.00 N 0.00 0.21 0.34 0.20 N 0.08 0.51 0.25 0.53 N 0.01 0.84 0.18 0.90 N 0.11 0.97 0.31 1.01 N 0.05 0.74 0.48 0.84 N 0,27 0.96 0.09 1.13 N 0.55 1,15 0.52 1.35 N 0.61 0.85 0.01 1.01 N 0.53 0.48 0.00 0.69 N 0.75 0.37 0.71 0.66 N 1.08 0.26 0.22 0.50 N 0.89 -0.16 0.18 0.06 N 0.89 -0.52 0.00 0.18 S 1.36 -0.78 0.21 0.31 S 1.88 -0.64 5.71 0.38 S 1.10 0.75 0.36 0.60 S 5.32 2.57 0.91 0.37 S 11.69 4.61 0.57 0.39 N 16.89 7.31 0.80 1.92 N 21.75 0.00 N 0 0 E 0.21 N 22 24 0.53 N 0 44 0.90 N 6 52 1. O1 N 2 47 0.88 N 17 47 1.26 N 25 46 1.48 N 24 26 1.14 N 27 40 1.03 N 47 42 E 10.62 0.90 4.07 N 26.68 14.75 0.31 6.92 N 32.1~ 19.54 0.33 I0.41 N 37.78 24.70 0.60 14.35 N 43.17 30.10 0.58 18.70 ,,N 47.93 35.61 0.48 23.33 N 52.00 41.04 0.93 27.87 N 56.15 48.10 1.18 34.08 N 50.32 58.99 1.08 44.32 N 64.25 73.29 1.68 58.03 N 68.31 1.27 N 58 26 E 1 02 N 60 35 = 0.89 N ~5 7 ~ 1.37 S 82 21 ~ 1.91 S 80 32 E 1.16 $ 70 58 E 5.36 S 83 34 W 11.70 S 8d 10 'w 16.90 N 88 41 N 21.8~ N 84 56 ~ N 16 52 W 91.67 2.61 N 18 41 W 114.35 2.23 N 17 19 W 140.33 1.16 N 15 6 W 168.57 1.85 N 13 33 W 199.31 1.51 N 13 25 W 232.42 1.~9 N 15 56 W 268.35 N 17 8 W 307.26 1.44 N 19 3 W 348.02 2.11 N 20 38 W 392.12 2.79 26.59 N 81 20 W 32.90 N 77 51 ~ 3~.19 N 74 35 ~ 45.4~ N 71 37 W 51.45 N 63 41 W 57.00 N ~5 50 W 62.69 N 63 36 W 69.29 N 60 32 W 78.05 N 55 24 W ~.63 N 49 38 ~ 75.67 N 73.54 W 105.52 N 44 10 W 97.27 N 80.59 W 126.31 N 39 38 W 122.03 N 88.61 W 150.51 N 35 59 W 149.13 N 96.53 W 177.66 N 32 5~ W 178.95 N 104.07 m 207.01 ~ 30 10 ~ 211.17 N 111.71 ~ 238.90 N 27 52 W 245.94 N 120.30 W 27~.01 N 26 9 W 283.26 N 131.87 W 312.45 N 24 57 N 322.08 N 144.56 W 353.04 N Z~ 10 w 363.75 N 159.59 W 397.22 N 23 41 W COMPUTATION CATE: STANOARO ALASKA PRODUCTION CO 3-1/N-29 SDI ENDICOTT NORTH SLOPE,ALASKA 1-FEB-ST INTERPOLATED VALUES FOR EVEN 100 FEET OF COURSE VERTICAL DOGL DEVIATION AZIMUTH SECTION SEVE OEG MIN DEG MIN FEET CEG/ TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 3872.16' 3957.38 4040.05 4119.90 4197.13 4271.68 4343.76 4414.84 4485.18 4555.37 30 10 N 22 47 W 440.07 2 32 47 N 22 44 W 491.83 2 35 40 N 22 5 W 547.52 2 38 13 N 20 45 W 607.27 2 40 39 N 19 31 W 670.48 2 42 58 N 18 49 W 736.89 Z 44 34 N 18 27 W $06.02 0 44 56 N 18 22 W 876.20 t 45 24 N 15 25 W 947.11 0 45 31 N 16 7 W, 1018.18 0 4000.00 3927.50 41.00.00 4012.72 4200.00 4095.39 4300.00 4175.24 4400.00 4252.47 4500.00 4327.02 4600.00 4399.10 4700.00 4470.18 4800.0'0 4540.52 4900'.00 4610.71 4625.44 4695.60~ 4765.98 4836.59 4907.31 4977.89 5048.28 5118.68 5189.06 5259.58 45 28 N 18 6 W 1089.38 0 45 24 N 18 2 W 1160.50 0 45 8 N 17 56 W 1231.41 0 45 1 N 17 32 W 1302.11 0 44 59 N 17 11 W 1372.72 0 45 12 N 17 7 W 1443.48 0 45 17 N 16 56 W 1514.45 0 ~5 12 N 16 28 W 1585.41 0 45 19 N 16 14 W 1656.41 0 45 0 N 16 19 W 1727.28 0 500.0.00 4680.78 5100.00'4750.94 5200.00 4821.32 5300.00 4891.93 5400.00 4962.65 5500.00 5033.23 5600.00 5103.62 5700.,00 5174.02 5800.00 5244.40 5900.00 5314.92 5330.30 5400.96 5471.59 5542.61 5613.37 5683.51 5753.47 5823.63 5894.04 5964.37 44 57 N 16 30 W 1797.94 45 10 N 16 32 W 1868.66 44 53 N 16 23 W 1939.41 44 45 N 16 32 W 2909.77 45 9 N 17 14 W 2080.36 45 38 N 18 2 W 2151.54 45 32 N 1~ 40 W 2222.83 45 15 N 18 48 W 2293.89 45 12 N 18 33 W 2364.70 45 27 N 18 3 W 2435.64 6000.00 5385.64 '6100.00 5456.30 6200.00 5526.93 6300.00 5597.95 6400.00 5668.71 6500.00 5738.85 6600.00 5808.81 6700.00 5878.97 6800.00 5949.38 6900.00 6019.71 6034.20 6103.63 617Z.73 6241.73 6310.62 6379.36 5447.96 6516.13 6582.29 6647.25 45 53 N 15 9 N 2507.07 0 46 B N 18 10 W 2578.90 0 46 21 N 15 19 W 2651.03 0 46 28 N 17 58 W 2723.26 0 46 26 N 17 49 W Z795.62 0 46 37 N 17 21 W 2868.14 0 46 46 N 16 43 W 2940.82 0 47 33 N 16 27 W 3013.94 1 49 27 N 16 9 W 3088.88 0 49 25 N 15 54 W 3164.88 1 7000.00 6089.54 7100.00 6158.97 7200.00 6228.07 7300.00 6297.07 7400.00 0365.96 7500.00 6434.70 7600.00 6503.30 7700.00 6571.47 7800.00 6637.63 7900.00 6702.59 PAGE DATE OF SURVEY: Z5-JAN-87 KELLY BUSHING ELEVATION: ENGINEER: RUBeNSTEiN MEASURED DEPTH EG RECTANGULAR COORDINATES MORIZ. RITY NORTH/SOUTH EAST/WEST DIST. 100 FEET FEET F~T 2 55.34 FT DEPARTURE AZIMUTH OEG MIN .65 408.66 N 177.47 W 445.53 N 23 28 W · 28 456.87 N 197.75 W 497.83 N 23 24 N · 72 508.84 N 219.25 W 554.06 N 23 18 W · 38 564.86 N 241.23 W 614.21 N 23 7 W · 60 524.50 N 263.07 W 677.65 N 22 50 W .48 587.45 N 284.92 W 744.15 N 22 30 W .82 753.13 N 307.04 W ~13.31 N 22 10 W · 17 819.88 N 329.24 W 863.52 N 21 52 W · 53 887.32 N 351.68 W ~54.~7 N 21 37 W · 23 954.95 N 374.02 M 1025.58 N 21 23 W .21 1022.76 N 396.20 W 1096.82 · 36 1090.50 N 418.30 ~ 1167.98 .19 115~.07 N 440.25 ~ 1238.93 · 40 1225.50 N' 46!.~5 W 1309.64 · 16 1292.99 N 482.93 W 1380.23 · OZ 1360.67 N 503.82 W 1450.95 .42 1428.59 N 524.66 ~ 1521.~ .30 1496.61 N 545.05 w 1592%77 .44 1564.77 N 565.05 W 166'3.67 .28 1632.83 N 584.92 W 1734.44 .16 1700.66 N 604.90 ~ 1805.03 · 22 1768.49 N 525.05 W 1875.70 .54 1836.38 N 645.11 W 1946.40 .43 1903.90 N 6~5.03 W 2016.71 .94 1971.52 N 665.51 W 2087.30 · 62 2039.45 N 707.11 W 215~.56 ,44 2107.26 N 729.65 W 2230.01 .44 2174.73 N 752.59 W 2301.27 .57 2241.9~ N 775.35 W 2372.27 · 51 2309.48 N 797.67 W 2443.35 · 55 2377.51 N 819.90 W 251~.92 · 58 2445.90 N 842.33 W 2586.85 · 22 2514.55 N 86~,98 W 2659.16 · 43 2583.32 N 887.56 W 2731.54 · 7~ 2652.30 lq 90~.83 W 2804.01 .57 2721.50 N 931.85 ~ 2876.62 .7i 2791.07 N 953.15 W 2949.33 .77 2861.21 N 974.01 W 3022.45 .81 2933.16 N 995.09 W 3057.36 .51 3006.23 N 1016.07 ~ 3173.30 N 21 10 W N 20 59 W N 20 38 w N ZO 28 W N 20 19 W N ZO 9 W N 20 0 W N 19 51 W N 19 42 W N 19 34 W N 19 27 W N 19 21W N 19 15 W N 1:~ 10 W N 19 7 W N 19 5 W N 19 5 ~ N 19 4 W N 19 3 W N 1~ 1 w N 19 N 18 5d W N 18 57 W N lb 56 W N 13 54 ~' N 18 51 W N 1~ 47 W N 1~ 44 ~ N 1 $ 40 W C3MPUTATION DATE: 1-FEB-87 PAG~ 3 STANDARO ALASKA PRODUCTION CO DATE OF SURVEY: ZE-JAN-87 3-1/N-29 SDI KELLY BUSMZNG ELEVATION: ENDICOTT NORTH SLOPE,ALASKA ~NGINEER: RUBENSTEIN INTERPOLATED VALUES FO2 EVEN 100 FEET OF MEASURED JEPTH TRUE SU6-SEA COURSE VERTICAL OGGLEG RECTANGULAR COOROINATES HORIZ. DEPARTURE MEASUREO VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST GIST. AZIMUTH OEPTH OEPTH DEPTH · DEG MIN 8000.00 6767.94 6712.60 49 23 8100.00 6832.61 6177.27 49 46 6200.00 6897.67 6842.33 49 8 8300.00 6963.38 6908.04 48 35 8400.00 7029.69 6974.35 48 10 8500.00 7096.63 7041.29 47 49 8600.00 7163.66 7108.32 47 57 8700.00 7230.63 7175.29 47 56 8800.00 7297.77 7242.43 47 38 8900'00 7365.35 7310.01 47 38 9000.00 7433.28 7377.94 46 44 9100.00 7502.09 7446.75 46 22 9200.00 7571.40 7516.06 45 57 9300.00 7641.06 '7585.72 45 41 9400.00 7711.06 7655.72 45 26 9500.00 7781.70 7726.35 44 48 9600.00 7852.84 7797.50 44 33 9700.00 7923.86 7868.52 45 3 9800.00 7993.94 7938.60 45 47 9900.00 8063.62 8008.28 45 47 55.34 ,~T OEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN o N 15 6 W 3240.56 1.43 3079.14 N 1036.~0 W 3248.89 N 18 36 W N 14 19 W 3316.83 0.72 3152.93 N 1055.72 W 3324.98 N 18 30 W N 13 57 W 3392.77 0.15 3226.58 N 1074.23 W 3400.71 N 18 24 W N 13 52 N 3468.15 0.24 3299.74 N 1092.40 ~ 3475.86 N 18 19 W N 13 43 W 3543~.01 0.60 3372.44 N 1110.25 W 3550.50 N 18 13 W N 13 52 W 3617.28 0.63 34~4.~6 N 1128.02 W 3624.56 N 18 7 W N 13 53 W 3691.48 0.43 3516.60 N 1145.84 W 3698.57 N 18 2 ~ } N 13 48 W 3765.74 0.51 3586.70 N 1163.61 W 3772.64 N 17 57 N N 13 22 W 3839.84 1.46 3660.72 N 1181.11 W 3846.~4 N 17 52 N N 12 43 W 3913.52 1.29 3732.53 N 1197.71 W 3919.99 N 17 47 W N 12 27 W 3986.86 0.70 3804.14 N 1213.72 W 3993.07 N 17 41 W N 12 22 W 4059.39 0.60 3875.02 N 1229.32 W 406'5.34 N 17 36 ~ N 12 20 W 4131.42 0.37 3945.42 N 1244.82 ~ 4137.14 N I7 30 N N 12' 28 W 4203.12 0.50 4015.50 N 1260.18 W 4208.50 N 17 25 W N 12 48 W 4274.48 0.88 4085.19 N 1275.74 ~ 4279.75 N 17 20 W N 13 3 W 4345.25 0.45 4154.18 N 1291.58 W 4350.34 N 17 16 W N 13 15 W 4415.51 0.33 4222.61 N 1307.60 W 4420.4~ N 17 1Z ~ N 13 2 W 4485.89 1.38 4291.14 N 1323.71 W 4490.57 N 17 8 W N 12 30 W 4557.19 0.78 4360.71 N 1339.49 ~ ~561.80 N 17 4 W N 12 18 W 4628.~7 0.86 4430.75 N 1354.92 ~ 4633.29 N 17 0 W 10000.00 8133.66 8078.32 45 11 10100.00 8204.41 8149.07 44 ~1 10 200.00 8275.94 ~220.60 43 54 10300.00 8348.36 8293.04 ~3 6 ,o,oo.oo ,o oo.oo 11000.00 8883.16 8827.82 37 2 11100.00 8963.08 8907.74 36 52 11200.00 9043.01 8987.67 36 57 11300.00 9123.09 9067.75 36 37 11400.00 9203.45 9148.11 36 20 11500.00 9284.13 9226.79 36 17 11600.00 9364.32 9'308.98 36 58 11700.00 944~.27 9358.93 36 53 11800.00 9524.28 9~68.94 36 52 11900.00 9604.26 95~8.92 36 56 N I1 58 W 4700.18 N 11 49 W 4770.78 N 11 40 W 4840.58 N 11 36 W 4909.44 N 11 15 W 4977.21 N 11 12 W 5043.89 N 11 0 W 5109.48 N 10 55 W 5173.~1 N 10 50 W 5236.99 N 10 30 W 5299.09 N 10 7 W 5359.74 N 9 24 W 5419.62 N 8 46 W 3479.45 N 8 19 W 5539.02 N 7 43 W 5598.16 N 7 11 ~ 5656.81 N 6 4 W 5715.98 N 4 35 ~ 5773.32 N 3 34 ~ 5834.33 N 1 53 W 5893.11 0.37 0.52 0.72 0.85 1.12 0.99 1.21 0.79 0.85 0.95 0.84 0.40 0.59 0.24 0.71 0.97 0.53 0.75 1.00 1.22 4500.53 N 1369.93 W 4704.41 N 16 35 W 4569.67 N 1364.56 w 477~.82 N 16 51 4638.08 N 1398.83 ~ 4~44.43 N 16 46 4,705.61 N 1412.72 ~ 4913.10 N 16 42 W 4772.13 N 1426.16 W 4980.68 N lo 38 W 4837.66 N 1439.11 w 50~7.1~ N 16 34 w 4902.11 N 1451.~4 w ~112.59 N 16 29 W 4965.39 N 1464.11 W 5176.75 N 16 25 W 5027.55 N 1476.10 W 5239.76 N 16 21 W 5088.70 N 1487.57 W 5301.70 N 16 17 5148.51 N 1498.61 . 5362.1~ N 16 13 W 5207.73 N 1508.79 W 5421.89 N 16 9 W 5267.06 N 15.18.30 W 5481.53 N 16 4 W 5326.30 N 1527.19 W 5540.92 N 15 59 W 5385.24 N 1535.49 W 5599.87 N 15 54 W 5443.83 N 1543.17 ~ 5658.33 N 15 49 N 5503.16 N 1550.07 W 5717.30 N 15 43 W 5362.~6 N 1555.85 ~ 5776.43 N 15 37 W 5622.76 N 1560.32 W 5835.2~ N 15 30 N 5682.73 N 1563.19 W 5893.81 N 15 22 W COMPUTATION DATE: 1-FEB-8? 4 STANDARD ALASKA PRODUCTION CO 3-1/N-29 SDI ENDICOTT NORTH SLOPE,ALASKA PAgE DATE DF SURVEY: ZE-JAN-87 KELLY BUSHING ELEVATION: ENGINEER: RUBENSTEIN INTERPOLATED VALUES FDR EVEN 100 FEET DF MEASURED DEP'TH TRUE SOB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 55.36. FT 12000.00 9684.22 9628.88 36 44 12100.00 9764.57 9709.23 36 21 12200.00 9845.03 9789.69 36 20 12300.00 9926.16 9870.82 35 20 12400.00 10008.0.0 9952.66 34 50 12500,00 10089,57 10034,23 36 5 12600,00 10169,57 10114,23 37 27 12700,00 10248,72 10193,38 37 59 12800,00 10327,01 10271.67 38 47 12900,00 10'405,43 10350,09 37 27 N 0 3 E 5951.48 N 1 41 E 6008.88 N 2 47 E 6065.72 N 3 31 E 6121.44' N 4 2 E 6175,99 N 4 1 E 6230.82 N ~ 25 E 6287,65 N 5 4 E 6345,33 N 5 39 E 6403.85 N 5 13 E 6462.00 1,35 0,98 1,26 0,75 0,60 2,01 1,07 1,24 0,77 3.56 5742.77 N 1564.17 ~' 5951.98 N 15 16. w 5802.29 N 1563.22 W 6009.i8 N 15 4 W 5861,63 N 1560,80 W 6065,88 N 14 54 W 5920,01 N 1557,65 W 6121,50 N 14 44 W 5977,34 N 1553.80 W 6176,00 N 14 34 ~i 6035,03 N 1549,72 W 6230,83 N 14 24 W 6094,87 N 1545,3i W 628'7,72 N 14 13 w 6155,77 N 154.0,20 ~ 6345,53 N 14 2 W 6217,71 N 1534,42 W 6404,25 N 13 51 W 6279.42 N 1528.04 W 6462.67 N 13 40 W 13000,00 10485,13 10429,79 37 6 13050,00 10525.00 10469.66 37 6 N 6 26 E 6518.43 N 6 26 E 6546.60 0,00 0,00 6339,45 N 1521,30 W 5519,43 N 13 29 W 6369,43 N 1517.92 W 6547.80 N 13 24 W VERTICAL CDGLEG RECTANGULAR COORDINATES HERIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/wEST DIST. AZIMUTH FEET DEG/IO0 FEET FEaT FEET OEG MIN COMPUTATION DATE: 1-FEB-87 PAGE 5 STANDARD ALASKA PRODUCTION CO DATE OF SURVEY: ZG-JAN-$7 3-1/N-29 SDI KEL'LY BUSHING ELEVATION: ENDICOTT NORTH SLOPE,ALASKA ENGINEER: RUBENSTEIN INTERPCLATED VALUES FOR EVEN 1000 FEET OF MEASUREO DEPT TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0.00 0,00 -55.34 0 0 1000.00 999.99 944.65 0 3 2000.00 1999.15 1943,81 3 17 3000.00 2994.27 2938,93 11 53 4000.00 3927.50 3872,16 30 10 5000,00 4680,78 4625,44 45 28 6000.00 5385.64 5330.30 44 57 7000.00 6089.54 6034.20 45 53 8000,00 6767,94 6712.60 49 23 9000.00 7433.28 7377.94 46 44 55.34 ET 10000.00 8133.66 5078.32 45 11 11000.00 8883.16 8827.82 37 2 12000.00 9684.22 9628.88 36 ~4 13000,00 10485.13 10429.79 37 6 13050,00 10525.00 10469.66 37 6 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SEC'TICN SEVERITY NORTH/SOUTH EAST/WEST GIST. AZIMUTH FEET CED/lO0 FEET FEET FEET DEG MIN N 0 0 E 0.00 S 21 19 W 0.37 N 64 47 W 10.62 N 16 52 W 91.67 N 22 47 W 440.07 N 18 6 W 1089.38 N 16 30 ~ 1797,94 N 18 9 W 2507.07 N 15 6 w 3240,56 N 12 27 W 3986,86 N 11 58 W w700.18 N 10 7 W 5359,74 N 0 3 E 5951,48 N 6 26 E 6518.43 N 6 26 E 6546,60 0.00 0.71 0.90 2.61 2.65 0.21 0.16 ,0.55 1.43 0.70 0.00 N 0.00 E 0.00 N 0 0 E 0.66 N 1.08 E 1.27 N 58 26 E 4.07 N 26.68 W 26.9,9 N 81 20 W 75.67 N 73.54 W 105.52 N 44 10 W 408.66 N 177.47 W 445.53 N 23 28 W 1022.76 N 396.20 W 1096.82 N 21 10 W 1700.66 N 604,90 W 1205,03 N 19 34 W 2377.51 N 819.90 W 2514,92 N 19 1 N 3079.14 N 1036,40 W 3248,89 N 18 36 W 3804,14 N 1213.72 N 3993,07 N 17 41 W 0.37 0.84 1.35 0.00 0.00 4500.53 N 1369,93 W 4704.~1 N 15 55 W 5148.51 N 1495.61 W 536,2.18 N 16 13 W 5742.77 N 1564.17 W 5951,98 N 15 14 ~ 6339.45 N 1521,30 W 6519.43 N 13 29 W 6369,43 N 1517,92 W 6547,80 N 13 ~4 W COMPUTATION DATE: 1-FEB-87 PAGE STANDARD ALASKA PRODUCTION CD 3-1/N-29 SOl ENOICOTT NORTH SLOPE,ALASKA INTERPOLATED VALUES FOR TRUE MEASURED VERTICAL DEPTH DEPTH SUB-SEA COURSE VERTICAL'DEVIATION AZIMUTH DEPTH DEG MIN DEG MIN 0.00 0.00 55.34 55.34 155.34 155.34 255.34 255.34 355.34 355.34 455.34 455.34 555.34 555.34 655.34 655.34 755.34 755.34 855.35 855.34 -55.34 0 0 N 0 0 0.00 0 18 N 41 26 100.00 0 11 N 29 29 200.00 0 13 N 27 38 300.00 0 5 N 58 2 400.00 0 12 S 43 55 500.00 0 14 N 40 27 800.00 0 8 N 16 0 700.0.0 0 14 S 8 46 800.00 0 16 S 43 41 9 10 11 12 13 14 15 16 17 18 55.35 955.34 55.35 1055.34 55.35 1155.34 55.35 1255.34 55.35 1355.34 55.35 1455.34 55.47 1555.34 55.69 1655.34 55.86 1755.34 55.99 1855.34 900.00 0 12 N 87 57 E 1000.00 0 9 S 53 9 W 1100.00 0 16 S 1 48 E 1200.00 0 18 S 71 15 E 1300.00 0 19 S 74 31 E 1400.00 0 16 N 55 23 W 1500.00 3 59 S 87 55 W 1600.00 3 38 N 67 48 W 1700.00 2 57 N 80 42 W 1800.00 2 56 N 71 39 W 19 20 21 22 23 24 25 26 27 28 56.12 1955.34 56.29 2055.34 56.51 2155.34 56.73 2255.34 56.95 2355.34 57.14 2455.34 57.33 2555.34 57.54 2655.34 58.00 2755.34 58.86 2855.34 1900.00 3 4 N 65 54 W 2000.00 3 35 N 61 13 W 2100.00 3 49 N 57 5~ ~ 2200.00 3 51 N 54 2 W 2300.00 3 42 N 47 28 W 2400.00 3 32 N 40 3& W 2500.00 3 31 N 42 33 W 2600.00 ~ 21 N 32 53 ~ 2700.00 b 29 N 20 28 W 2800.00 ~ 30 N 16 11 W 29 30 31 32 33 34 35 36 38 39 60.28 2953.34 62.61 3055.34 65.89 3155.34 59.91 3255.34 74.76 3355.34 80.54 3455.3. 87.48 3555.34 93.95 3653.34 05.55 3755.34 17.43 3855.34 2900.00 10 58 N 16 10 W 3000.00 13 2b N 18 24 W 3100.00 15 22 N 17 44 W 3200.00 16 39 N 15 51 W 3300.00 18 16 N 13 30 W 3400.00 19 46 N 13 14 W 3500.00 21 53 N 15 42 W 3600.00 23 25 N 17 3 W 3700.00 25 5 N 19 8 W 3800.00 28 7 N 20 57 ~ DATE OF SURVEY: 25-JAN-S7 KELLY BUSHING ELEVATION: ENGINEER: RUBENSTEIN EVEN 100 FEET OF SUB-SEA DEPTH VERTICAL SECTION FEET 0.00 0.02 0.38 0.70 0.98 0.81 0.84 1.10 1.03 0.60 DOGLEG RECTANGULAR CO SEVERITY NORTH/SOUTH EA CEG/100 FE~T F 0.00 0.00 N 0.62 0.01 N 0.10 0.39 N 0.01 0.73 N O. 39 1.04 N 0.43 0.87 N 0.00 0.99 N O. 20 1.30 N 0.14 1.21 N 0.82 0.77 N ORDINATES HORIZ. ST/WEST DIST. EET FE'ET 0.00 E 0.00 0.01 w 0.02 0.01 w 0.39 0.05 E 0.73 0.08 E 1.04 0.12 E 0.88 0.44 E 1.08 0.62 ~ 1.44 0.56 ~ 1.33 0.58 E 0.96 0.40 0.33 0.O6 -0.38 -0.69 -0.77 -0.02 1 3.63 5.05 0.00 0.67 N 0.00 0.60 N 0.43 0.27 N 0.00 0.11 S 0.12 0.28 S 2.29 0.29 S 0.33 0.57 S 0.31 0.50 S 0.96 0.06 S 0.42 1.1~ N 9.08 0.38 3.05 N 12.82 0.68 5.56 N 17.40 0.39 8.83 N 22.45 0.05 12.61 N 27.74 0.56 16.76 N 33.28 0.21 21.37 N 38.66 0.50 25.88 N 44.55 3.89 30.87 N 53.89 3.70 39.46 N 56.97 2.83 51.98 N 83.80 2.53 68.11 N 105.4~ 2.06 88.80 N 131.15 1.31 113.29 N 159.82 1.62 140.72 N 191.32 1.51 171.18 N 225.78 1.48 204.71 N 263.65 2.52 2~1.41 N 305.64 1.49 281.71 N 350.38 2.24 324.32 N 400.28 2.34 371.42 N 0.99 E 1.ZO 1.00 E 1.16 0.82 E 0.85 1.12 E 1.i2 1.66 E 1.59 1.96 E 1.98 2.25 w 2.32 8.98 W 8.99 4.73 w 14.73 9.57 w 1~.60 55.34 FT DEPARTURE AZIMUTH DEG MIN N 0 0 E N 39 11 W N 2 8 W N 3 38 E N 4 32 E N 7 42 5 N 24 I0 E N 25 41E N 24 51 E N 36 48.~= N 53 49 E N 58 51 E N 71 36 E S 84 37 E S 80 30 E S 81 42 E $ 75 53 w S 85 48 W S 59 45 W N '~6 32 ~ 24.48 W 24.67 N 52 54 W 29.70 W 30.22 N 79 24 W 35.37 W 36.45 N 75 59 W 40.58 W 42.78 N 72 51 ~ 45.97 W 48.93 N 69 58 W 50.31 W 54.66 N 66 59 N 54.35 W 60.20 N 64 32 W 5~.56 W 66.22 DJ ~2 12 N 02.65 W 7~.04 N 57 47 W 66.48 W 84.39 N 51 58 W 7 7 8 10 11 11 13 14 16 1.31 W 93.61 7.75 ~ 118.03 5.85 w 142.14 4.20 g 169.34 2.18 w 199.36 0.17 ~ 232.4~ 9.51 ~ 269.3~ 1,39 ~ 310.85 5.35 ~ 355.40 2.32 ~ ~05.~2 N ~6 1~ W N 41 12 W N 37 9 W N 33 ~7 W N 30 50 W N 28 i7 w N 26 20 W N 25 Ow N 24 3 N 23 37 W COMPUTATION DATE: 1-FEB-87 PAGE 7 STANDARD ALASKA PRODUCTION CO DATE OF SURVEY: 25-JAN-87 3-1/N-29 SDI ENDICOTT NORTH SLOPE,ALASKA KELLY BUSHING ELEVATION: ENGINEER: RUBENSTEIN 55.34 PT INTERPOLATED VALUES FOR EVEN 100 FEET DF SUB-SEA DEPTH TRUE SUB-SEA CDURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH OEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DZST. AZIMUTH FEET DEG/IO0 FEET FEET FEET OEG MIN 4032.36 3955.34 3900.00 31 ~ 4 4151.14 4055.34 ~000.00 34 14 4274,74 4155.34 4100,00 37 39 4403,78 4255,34 4200,00 40 44 4538,95 4355,34 4300,00 43 45 4679,05 4455,34 4400,00 44 42 4821,10 4555,34 4500,00 45 21 4963.70 4655,34 4600,00 45 31 5106,26 4755,34 4700,00 45 23 5248,20 4855,34 4800'00 45 4 N 22 53 W 456.39 N 22 31 W 519.80 N 21 4 W 591.81 N 19 29 W 672.92 N la 38 w 763.55 N 18 21 w 861.44 N 18 22 W 962.09 N 18 6 W 1083,55 N 18 1 W 1164.95 N 17 47 W 1265.50 3.03 3.20 2.34 2.62 1.5~ 1 .£0 0.40 0.16 0.3~, 0.36 423.85 N 183.87 W 462.02 N 23 27 W 482.95 N 208.62 m 526.08 N 23 21 ~ 550,32 N 235.69 W 59~.67 N 23 11 W 626.81 N 263.89 W 8~0.10 N 22 49 W 712.77 N 293.51 W 770.83 N 22 22 W 805,85 N 324,57 W 868.75 N 21 55 W 901.57 N 356.42 W 969.46 N 21 34 W } 998,16 N 388,15 W 1070.97 N 21 14 W 1094,74 N 419.66 W 1172.43 N 20 58 W 1190,57 N 450,73 W 1273.03 N 20 44 ~ 5389,66 4955,34 4900,00 44 58 5531,39 5055,33 5000,00 45 15 5673,48 5155,34 5100,00 45 12 5.815,54 5255,34 5200,00 45 17 5957,16 5355,34 5300,00 45 0 6098,64 5455,34 5400,00 45 10 6240,04 5555,34 5500,00 44 41 6381,04 5655,34 5600.00 45 3 6523,59 5755.34 5700,00 45 38 6666.39 5855.34 5800.00 45 24 N 17 12 W 1365,41 N 17 6 W 1465,74 N 16 33 W 1566,60 N 16 14 W 1667,45 N 16 25 W 1767.68 N 16 32 W 1B67,70 N 16 24 W 1967,61 N 17 4 W 2066,93 N 18 13 W 2168,37 N 18 48 W 2270,05 0.11 0.24 0.35 0.61 0.20 0.22 0.46 0.72 0.5~, 0.58 1286.00 N 460.77 W 1372.93 N 20 29 N 1381.97 N 510.37 W 1473.21 N 20 16 W 1478,56 N 539,70 W 1573,98 N 20 3 W 1575,38 N 568,14 ~ 1674,69 N 19 4'9 W 1671,62 N 596,32 W 1774,~0 N 19 37 W 1767,57 N 624.79 W 1874,74 N 19 28 W 1863,45 N 653,07 W 1974,58 N 19 18 N 1958.68 N 681.53 ~ 2073.86 N 19 I1 W 2055.48 N 712.37 ~ 2175.42 N~ 19 6 W 2152,10 N 744,88 W 2277,36 N 19 5 N 8808.45 5955,34 5900,00 45 13 6950,93 6055,34 6000,00 45 43 7094.76 6155.33 6100,00 46 7 7239,50 6255.34 6200,00 46 ~0 7384.60 6355,34 6300,00 ~6 25 7530,05 6455.34 6400.00 46 38 7676,19 6555.34 6500.00 47 10 7827.26 6655.34 6600.00 49 28 7980,68 6755,34 6700.00 49 11 8135,10 6~55,34 6800.00 49 30 N 15 30 W 2370,69 N 18 5 W 2471.96 N 18 10 W 2575,12 N 18 14 W 2679.54 N 17 50 W 2784.48 N 17 9 W 2889.96 N 16 29 W 2996.43 N 16 3 W 3109,59 N 15 gO W 3225.91 N 14 9 W 3343,58 0,59 0,45 0,47 0,41 0,66 0,53 1,27 0,66 1,40 1,08 2247.67 N 777.26 ~ 2378.27 N 19 4 W 2344.08 N 808.96 W 2479.7~ N 19 2 W 2442,31 N 841,15 ~ 2583,10 N 19 0 W 2541,69 N 873.94 W 26~7,'74 N 1~ 58 W 2641.68 N 906.41 W 2792.86 N 18 56 W 2742.37 N 938.33 W 2898.46 N 18 53 W 2844.40 N 969.04 W 3004.94 N 18 48 W } 2953.06 N 1000.83 W 31!B.05 N 16 ~3 W 3065.01 N 1032.36 m 3234.26 N 18 37 H 3178,85 N 1062.29 ~ 3351.56 N 18 Za W 8287,83 6955,34 6900,00 48 37 8438.41 7055.34 7000.00 48 1 8587.57 7155.34 7100.00 47 57 8736.86 7255.34 7200.00 47 50 8885.15 7355.34 7300.00 47 38 9032.13 7455,34 7400.00 46 32 9176.88 7555.34 7500.00 46 0 9320,43 7655.34 7600.00 45 37 9462,81 7755,34 7700.00 44 56 9603,51 7855.34 7800,00 44 33 N 13 54 W 3459.01 N 13 49 ~ 3571.58 N 13 54 W 3582.25 N 13 45 W 3793.08 N 12 46 W 3902.57 N 12 25 W 4010.21 N 12 25 W 4114.81 N 12 30 W 4217.72 N 12 56 W 431~.02 N 13 16 W 4417.98 0,44 0,51 0.42 0.43 1,10 0,48 0,32 0,35 0,57 0,36 3290.87 N 1090.21 W 3~66.75 N 13 19 W 3400.20 N 11i7.06 W 3578.99 N 18 11 W 3507.64 N 1143.62 ~ 3689.37 N la 3 W 3615.26 N 1170.12 ~ 3799.91 N 17 56 W 3721,84 N 1195.29 W 3909.07 N 17 48 W 3826,96 N 1218.75 W 4016,34 N 17 39 N 3929.18 N 1241.25 W ~120.5~ r4 17 31 ~ 4029.76 N 1263.33 m 4223.15 N 17 24 W 4128,62 N 1285,6~ W 4324,17 N 17 17 W 4225.01 N 1308.16 W 4422.90 N 17 12 ~ STANDARD ALASKA PRODUCTION CO 3-1/N-29 SDI ENDICOTT NORTH SLOPE,ALASKA COMPUTATION DATE: 1-FEB-87 PAGE DATE OF SURVEY: 25-JAN-87 KELLY bUSHING ELEVA'TION: ENGINEER: RUBENSTEIN 55.34 F'T ZNTERPCLATED VALUES FOR EVEN 100 FEET OF SUb-SEA DEPTh ~ TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASUREO VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEG MIN FEET gED/lO0 FEET FEET FEET DEG MIN , N 12 49 ~ 4517.69 0,99 4322.15 N 1330,83 W 4522,40 N 17 6 N 12 20 W 4620,36 0,93 4422,43 N 1353,11 W 4624,80 N 17 0 N 11 59 W 4721,9~ 0,39 4521,83 N 1374,45 W 4726,11 N 16 54 W N 11 47 W 4820,68 1,02 ~618,57 N 1394,78 W 4824,58 N 16 48 W N 11 33 W 4915~93 0,84 4711.97 N 1414,02 W 4919.56 N 16 42 W N 11 8 W 3007,45 0,72 4801,85 N 1432.03 W 5010,83 N 16 36 N 11 7 W 5095.48 1.19 4~88,35 N 1449.14 W 5098.62 N 16 30 W N 10 55 W 5179.79 0.76 4971.26 N 1463.25 W 5182.70 N 16 25 W N 10 46 W 5260,91 0.68 5051.08 N 1480.59 W 5263.61 N 16 20 N 10 19 W 5338,71 0,79 5127,75 .N 1494,86 W 5341.21 N 16 15 W N 9 27 W 5413,83 0,40 5202,00 N 1507,63 W 5416,12 N 16 9 W N 8 41 W 5488,66 0,47 5276,22 N 1519,70 ~ 5490,71 N 16 4 W N 8 5 W 5562,82 0,51 5350,00 N 1530,60 W 5564,64 N 15 57 W N 7 24 W 5635,89 0,23 5422,92 N 1540,49 W 5637.48 N 15 51 W N 6 11 W 5709.31 0,64 5496,46 N 1549,35 W 5710,65 N 15 44 W N 4 44 ~ 5783,50 0,78 5571.23 N 1556,54 W~ 5784.58 N 15 36 W N 2 55 W 5857,19 1,01 5646,02 N 1561,63 ~ 5858.01 N 15 27 N 0 41 ~ 5930,52 1,27 5721,14 N 1564,06 ~ 5931.08 N 15 17 W N 1 31 E 6002,35 0,99 5'795,50 N 1563.42 W 6002,68 N 15 5 N 2 51 E 6072,97 1,42 5869,22 N 1560,44 W 6073,11 N 14 53 W N 3 49 E 6141,05 0,79 5940,60 N 1556,33 W 6141.08 N 14 40 W N 4 2 E 6207,50 1,46 6010,50 N 1551,45 W 6207.50 N 14 28 W. N 4 20 E 6277.39 1.02 6084.06 N 1546.1~ ~ 6277.45 N 14 15 N 5 5 E 6350,22 1,16 6160.94 N 1539.74 W 6350.44 N 14 1 W N 5 49 E 6425,15 0,94 6240.30 N 1532.15 ~ 6425,64 N 13 47 W N 6 26 E 6497,38 0,00 6317,06 N 1523.83 W $4~8.25 N 13 33 W N 6 26 E 6546.60 O.O0 6369.43 N 1517.92 W 6547.80 N 13 24 DEPTH DEPTH DEPTH 9744.76 7955.347900.00 9888.13 8055.348000.00 ~oo~o.~s~,.~ ~oo.oo ~o~.~ ~.~ ~oo.oo ~o~o,.~ ~,,.~ ~oo.oo ~o~o,.~o ~.~ ~oo.oo ~o,~.o~ ~,~.~ ~oo.oo ~,~.~ ~oo~.~ ~oooo.oo ~~.~~o~,.~ ~o~oo.oo ~o~.~ ~o~,,.~ ~o~oo.oo ~~.~o ~o~,.~ ~o~oo.oo ~,~.~ ~o~.~ ~o~oo.oo ~o,o.oo ~o,~.oo ~o~,.~ COMPUTATION DATE: 1-FE8-87 9 STANDARD ALASKA PRODUCTION CO 3-1/N-29 SDI ENDICOTT NORTH SLOPE,ALASKA INTERPOLATED VALUES FOR CHOSEN HORIZONS MARKER DRILLERS DEPTH MEASURED DEPTH BELOW KB 13050.00 FROM KB 10525.00 PAGE DATE OF SURVEY: 25-J&N-87 KELLY BUSHING ELEVATION: ENGINEER: RUBENSTEIN 55.34 SURFACE LOCATION AT ORIGIN: 2535 FNL, 878 FEL, SEC 8, TllN, R17E TVD RECTANGULAR COORDINATES SUB-SEA NORTH/SOUTH EAST/WEST 10469.66 6359.43 N 1517.92 W COMPUTATION OATE: 1-FEB-8'7 PAGE 10 STANDARD ALASKA PRODUCTION CD DATE OF SURVEY: Z5-JAN-87 3-1/N-29 SDI ENDICOTT NORTH SLOPE,ALASKA KELLY BUSHING ELEVATION: ENGINEER: RUBENSTEIN 55.34 FT MARKER MEASURED DEPTH BELOW KB SUREACE LgCATIO'N AT ORIGIN: 2535 FNL, 678 EEL, SEC 3, TllN, R17E TVO RECTANGULA. R COORDINATES FROM KB SUB'SEA NORTH/SOUTH EAST/WEST DRILLERS DEPTH 13050.00 10525.00 10469.66 63~9.~3 N 1517.92 W FINAL WELL LOCATION AT TO: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 13050.00 10525.00 10469.66 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG, MIN 6547.80 N 13 24 W SCHLUr"IBEROER D I RE C T ]; ONAL SUR V E Y COMPANY STANDARD ALASKA PRODUCTION NELL 3-i N-29 SDI FIELD ENDICOTT COUNTRY USA RUN 1 DATE LOOOED 2S - JAN - 8? REFERENCE FS1A. t ECEIVED ,,,,ap .- 2 1987 Oil & Gas Cons. Comm,:.,,~ Anchorage WELL' 3-1/N-29 SDI ~' 2535' FNL & 878' FEL, S,.,; 8, TllN, R17E ..... HORIZONTAL PROJECTION NORTH 12000 REF FS]A. SCALE = 1/2000 IN/FT .~ ...... :'"'!'"':'"~ ........ i': ':'F"! -';""! ~.":"T"T ....... ~'"'~'"?'"F"; t""F";'"'?; ........... : ......... ;"!'"'!'": ........ ; ....... : ............. : ................. ; ................ : .......... '~ : . ~, : . . . , + r.-:-=-;.-.,.-.-+-:..+-:-..~'?.~. ................. ~ ........ - ........................................................ ; .......................................................... .~ ............... .J SO00 6000 ~ ; ~ : i ; : ...... · . . .... ~"'T'"!'"'~'"T"'~'"T'"F'"~ .... ::; ~::.. ~:~::: .... ::::~.::: :-~:. . ::::::::: ~ t ~? .... ....... --~;: .... ~'"'~""~"'~""~""~'"'~'"T""~ ......... · ..;...;...$...;...L..$....~...;....~ .... ........ ........ .... ; . . · "?"i'"'!'"'i'"t'"t'"t" , ,:: ,~ ~ . :.. "':'""'"'"':'"T"'T'"T'"T"'T'" ....... . ..... ..4...~.4...;...4...~...~...~.. ::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::: T...,--.? ....... ~.-.:.. . . .--;..-;.--~-..~...~,.-.~-..;.-.~, .... . ....... :::?...:...i.-+...i-...~..-~ .......... ;....i ...... ~...!...~...:..,i...+ ::::::::::::::::::::::::::::::::::::::::: NEST -8000 -6000 -4000 -2000 0 2000 4OOO 6000 800O EAST WELL' 3-1/N-29 SDI 2535' FNL & 878' FEL, SEC 8, TllN, R17E ~ERTICAL PROJECTION -4000 -2000 0 0 2000 4000 6000 8000 !0000 !2000 S. '"m~":""i'''~''~m'''~'?', ............... i'"'i"':'"~'"': ........ /-+---!'"~"~--',-"i ............ ~ ....... ~" ;'"';-.-.i-.-.;.--!----i ......... !..-.i ......... : .............. i: ............ ' ....... ; .............. ......... { .................... ~....;...i...L4....~-..~ ......... L. L.~L._L...'~ j [.]~.: ............. L...L..~ ........ : ............ L..[ ......... '.2 ....' ........ ' ..................... : ................. L..~ ......................... ..... ;..~.~ ........ ;....~4....~....~....:..~ .............. L..~...~-..~.-L..~.-.~I...~ ..; ......... L-~....:_..~ ......... :.4 .............. : .................. ~....:, ~...~ .................. ~ ................... ~ ........ ~ ......... : ...... l .............. :...: .................. ~ . ~ 77~- PROJECTION ON VERTICAL PLANE 94S. - 165. SCALED IN VERTICAL OEPTHS HORIZ SCALE = 1/2000 IN/FT irt ii TELECO Teleco Oilfield Ser~. ~s of Alaska Inc. 6116 Nielson Way Anchorage, AK 99502 (907) 562-2646 January 20, 1987 JOB #556 STANDARD ALASKA PRODUCTION CO. WELL: 3-1/N-29 ENDICOTT SDI RIG: POOL ARCTIC ALASKA #7 Please find attached a copy of the computer calculated MWD directional surveys for the above mentioned well. We at Teleco appreciate this opportunity to provide service to Standard Alaska Production Company. Teleco is committed to providing the highest quality of service and we would welcome any comments or questions concerning these surveys or any of our other services. Sincerely, Pat Havard Field Service Supervisor PH/el Enclosures A ~'P..,~I~'I' COMPANY TELECO OILFIELD SERVICES JOB 556 SURVEY CALCULATIONS Date Page 01/19/87 ~ompany: ~ell: ~cation: ~ig: STANDARD ALASKA PRODUCTION CO. 3-1/N-29 ENDICOTT SDI POOL ARCTIC ALASKA #7 ?ELECO Job # 556 TAK ;rid Correction: [agnetic Declination: ~otal Correction: ~roposed Direction: 0.00 degrees 31.50 degrees 31.50 degrees 345.50 degrees MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100' *************************************************************************************************** TIE INTO GYRO SURVEY @ 2511.00 4.0 320.0 N 40 00 W 2509.06 37.12 25.51N 48.98W 55.22 N 62.488W 0.000 TELECO MWD SURVEYS 2511' 2860.00 8.3 344.4 N 15 36 W 2856.26 70.61 56.73N 62.65W 84.52 N 47.840W 1.625 2954.00 10.6 344.4 N 15 36 W 2948.98 86.04 71.59N 66.79W 97.91 N 43.015W 2.447 3046.00 13.0 342.3 N 17 42 W 3039.03 104.83 89.61N 72.18W 115.07 N 38.852W 2.650 2767.00 6.8 343.0 N 17 00 W 2764.07 58.40 45.00N 59.22W 74.38 N 52.770W 2.193 2672.00 4.9 334.5 N 25 30 W 2669.57 48.79 35.98N 55.72W 66.33 N 57.142W 0.891 TELECO Job # 556 TAK 01/19/87 Page 2 MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100' 3152.00 15.3 341.9 N 18 06 W 3141.81 130.70 114.27N 80.15W 139.58 N 35.046W 2.172 3248.00 16.3 344.7 N 15 18 W 3234.18 156.82 139.30N 87.66W 164.59 N 32.181W 1.310 3342.00 17.8 345.4 N 14 36 W 3324.04 184.38 165.93N 94.77W 191.09 N 29.732W 1.611 3436.00 19.1 346.5 N 13 30 W 3413.21 214.12 194.79N 101.99W 219.88 N 27.637W 1.432 3608.00 22.1 343.3 N 16 42 W 3574.19 274.62 253.20N 117.75W 279.25 N 24.941W 1.862 3703.00 23.5 343.0 N 17 00 W 3661.77 311.40 288.44N 128.42W 315.73 N 24.001W 1.479 3794.00 24.4 343.0 N 17 00 W 3744.93 348.31 323.76N 139.21W 352.42 N 23.266W 0.990 3888.00 27.3 341.6 N 18 24 W 3829.52 389.22 362.80N 151.67W 393.23 N 22.687W 3.152 3984.00 29.4 338.4 N 21 36 W 3914.00 434.59 405.63N 167.25W 438.76 N 22.408W 2.700 4093.00 32.6 338.8 N 21 12 W 4007.42 490.32 457.89N 187.74W 494.89 N 22.294W 2.942 4189.00 35.4 338.8 N 21 12 W 4087.00 543.63 507.95N 207.12W 548.55 N 22.184W 2.917 4283.00 37.7 339.1 N 20 54 W 4162.51 599.24 560.18N 227.23W 604.52 N 22.079W 2.454 4374.00 40.2 341.9 N 18 06 W 4233.27 656.21 614.10N 246.32W 661.66 N 21.856W 3.359 4467.00 42.1 342.6 N 17 24 W 4303.30 717.31 672.38N 264.98W 722.71 N 21.509W 2.102 4753.00 45.2 342.6 N 17 24 W 4510.21 914.47 860.78N 323.93W 919.71 N 20.622W 1.084 4943.00 45.6 343.3 N 16 42 W 4643.62 1049.62 990.12N 363.60W 1054.77 N 20.165W 0.336 5132.00 45.4 343.3 N 16 42 W 4776.10 1184.32 1119.25N 402.26W 1189.34 N 19.769W 0.109 TELECO Job # 556 TAK 01/19/87 Page 3 MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100' **************************************************************************************************** 5321.00 45.1 341.6 N 18 24 W 4909.15 1318.35 1247.22N 442.73W 1323.47 N 19.544W 0.658 5510.00 45.2 342.3 N 17 42 W 5042.45 1452.08 1374.62N 484.25W 1457.42 N 19.406W 0.268 5699.00 45.4 344.4 N 15 36 W 5175.39 1586.32 1503.32N 522.74W 1591.61 N 19.174W 0.797 5984.00 45.1 343.7 N 16 18 W 5376.03 1788.65 1697.93N 578.36W 1793.73 N 18.810W 0.204 6174.00 45.2 343.7 N 16 18 W 5510.03 1923.27 1827.21N 616.09W 1928.28 N 18.633W 0.059 6452.00 45.5 341.9 N 18 06 W 5705.40 2120.81 2016.13N 6646.00 45.4 341.9 N 18 06 W~ 5841.50 2258.81 2147.57N 674.57W 2125.99 717.46W 2264.25 N 18.500W 0.473 N 18.473W 0.058 7973.00 49.0 345.1 N 14 54 W 6746.78 3227.42 3074.42N 1002.18W 3233.64 N 18.055W 0.812 8169.00 49.4 346.1 N 13 54 W 6874.84 3375.79 3218.13N 1039.08W 3381.72 N 17.894W 0.437 8358.00 48.7 345.4 N 14 36 W 6998.71 3518.53 3356.48N 1074.22W 3524.19 N 17.747W 0.464 8534.00 48.2 346.1 N 13 54 W 7115.45 3650.25 3484.14N 1106.64W 3655.67 N 17.621W 0.411 8821.00 47.6 347.6 N 12 24 W 7307.86 3863.13 3691.50N 1155.08W 3868.00 N 17.375W 0.440 9042.00 46.9 347.6 N 12 24 W 7457.87 4025.31 3850.03N 1189.87W 4029.70 N 17.174W 0.317 7784.00 49.7 343.3 N 16 42 W 6623.66 3084.07 2936.45N 963.14W 3090.37 N 18.159W 1.099 7507.00 46.7 344.0 N 16 00 W 6439.05 2877.71 2738.33N 905.02W 2884.01 N 18.289W 0.383 7222.00 46.3 342.6 N 17 24 W 6242.86 2671.13 2540.32N 845.61W 2677.37 N 18.412W 0.300 6930.00 45.8 341.6 N 18 24 W 6040.21 2461.28 2340.28N 781.00W 2467.16 N 18.455W 0.160 TELECO Job # 556 TAK 01/19/87 Page 4 MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100' **************************************************************************************************** 9191.00 46.4 347.2 N 12 48 W 7560.16 4133.60 3955.76N 1213.50W 4137.71 N 17.054W 0.388 9387.00 45.8 348.6 N 11 24 W 7696.06 4274.70 4093.85N 1243.10W 4278.43 N 16.891W 0.599 9568.00 44.8 346.9 N 13 06 W 7823.38 4403.25 4219.57N 1270.40W 4406.67 N 16.756W 0.867 9796.00 45.9 347.2 N 12 48 W 7983.61 4565.39 4377.64N 1306.75W 4568.52 N 16.621W 0.491 9956.00 45.9 347.2 N 12 48 W 8094.95 4680.25 4489.71N 1332.15W 4683.17 N 16.526W 0.025 .0144.00 44.6 348.6 N 11 24 W 8227.30 4813.64 4620.25N 1360.14W 4816.29 N 16.404W 0.870 .0295.00 43.2 348.6 N 11 24 W 8336.10 4918.17 4722.88N 1380.78W 4920.59 N 16.297W 0.927 .0523.00 41.8 348.6 N 11 24 W 8504.20 5071.95 4873.87N 1411.15W 5074.05 N 16.148W 0.614 ,0718.00 39.8 349.3 N 10 42 W 8651.81 5199.13 4998.92N 1435.57W 5200.97 N 16.023W 1.052 ,0904.00 38.1 349.7 N 10 18 W 8796.45 5315.77 5113.89N 1456.87W 5317.36 N 15.902W 0.924 1085.00 37.1 351.4 N 08 36 W 8939.85 5425.77 5222.82N 1475.01W 5427.11 N 15.771W 0.796 1275.00 37.0 352.8 N 07 12 W 9091.50 5539.48 5336.19N 1490.74W 5540.51 N 15.608W 0.447 1460.00 36.5 352.8 N 07 12 W 9239.73 5649.25 5446.01N 1504.55W 5650.01 N 15.444W 0.271 1650.00 37.1 355.3 N 04 42 W 9391.87 5761.79 5559.20N 1516.34W 5762.29 N 15.257W 0.849 1836.00 37.2 357.8 N 02 12 W 9540.12 5872.03 5671.32N 1523.10W 5872.28 N 15.033W 0.814 2040.00 36.8 0.6 N 00 36 E 9703.04 5991.29 5794.06N 1524.82W 5991.35 N 14.744W 0.849 Oii F i el d Senvi ces PLAN ViEW STA A A 3- ' .POOL AR TIC ALASKA .... #~ ..... WEST (~t) 16400 PROOUCT~_~C N ! cO ' _ ......... · _..SCAL _E~ - 4 .... i7~::~2 , , I 2400 .0452 ~ 1600 & ;Gas..6ons:.. 4800 4000 3200 2400 1600 t ............. ~.~ ae 'i ~ . -. 800 ;\ · ~4~. ".~_l 8~ IEI F ~ __~00iifi~ld Sarvic~s ~,'~:xT I C?,~. PRSiE£T I 8i,i 6O00 8ooo 0 2000 4000 6000 8000 ! 0000 i 2000 2000 i ' " ' ~ ~ : ; i , ' ~ ' ' ' ' ' , ' f' ' ' ~~N : , ~ t I ': i, ' ~ i ~ ', ' iaooo =.) : ............ I-, : 14000 160OD F-~ 20000 ........ '"- ~- .... ..... i Standard Alaska Production Company 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 564-51 I ! APR 8, 1987 STANDARD ALASKA PRODUCTION William Van Alen Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Van Alen: The following log information for Endicott wells: As requested 1 sepia print for: P-20, P-27, M-25 * CBT * CET 0-25, N-29 * CET Oil &AnchorageG':~s Cons. Commission Sincerely, Bruce St. Pierre Received by Date A u,,i! of Ihe or,ginol Standard O,I Compo,~¥ Standard Alaska Production Company 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Mr. Lonnie Smith Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Duck Island Unit/Endicott Wells Dear Mr. Smith, STANDARD ALASKA PRODUCTI~,J April 3, 1987 We are requesting that the AOGCC adopt dual designation for all future ~ .... ~ ,~1/ well names in the Duck Island/Endicott Unit for operational and safety /;~l~.,-~ ~-~ reasons. Dual designation lists the numeric surface location followed by an alpha-numeric bottom hole location. This will be indicated in future wells on Form 10-401 in Item Number 8. We also ask that wells drilled to date be referenced by this dual designation. For your use is a list of wells drilled to date. WELL NAME PERMIT NUMBER API NUMBER 1-5/0-20 (MPi) 1-27/P-20 (MPI) 1-29/M-25 (MPI) 1-35/0-25 (MPI) 1-41/0-23 (MPI) 1-47/Q-21 (MPI) 2-2/P-18 (MPI) 2-4/M-19 (MPI) 2-6/J-22 (MPI) 2-14/0-16 (MPI) 2-34/P-14 (MPI) 2-62/Q-17 (MPI) 3-1/N-29 (SDI) 3-5/0-29 (SDI) 3-21/5-34 (SDI) 3-23/N-32 (SDI) 3-27/M-33 (SDI) 3-33/K-37 (SDI) 3-35/5-36 ($DI) 3-47/Q-35 (SDI) 4-8/P-27 (SDI) 4-20/M-35 (SDI) (T-34 Redrill) 4-20/T-34 (SDI) (Abandoned) ~ ~ ~ ~l~nitoftheoriginalStandordOitC .... pony 86-106 50-029-21605 87-9 50-029-21693 86-181 50-029-21669 86-184 50-029-21672 87-32 50-029-21713 86-131 50-029-21625 86-63 50-029-21568 86-82 50-029-21585 87-18 50-029-21699 86-149 50-029-21639 86-172 50-029-21662 86-158 50-029-21648 86-190 50-029-21678 86-130 50-029-21624 87-33 50-029-21714 86-155 50-029-21645 86-83 50-029-21586 86-180 50-029-21668 87-20 50-029-21701 86-64 50-029-21569 87-8 50-029-21692 86-173 50-029-21640-01 86-150 50-029-21640 we thank you for your assistance and should you have any guestlons, give me a call at 564-5007. Yours very truly, RSA/MAW/pm/1664D cc: R. H. Reiley_ B. L Rose~ J. G. Vidrine I. R. Robertson D. Huxley B. Ross File 16.4 Endicott Development R. S. Allan Division Drilling Engineer Standa~rd Alad~a P~oducfion C~mpan¥ 900 East 8enson 8oulevafd P.O. Box 196612 Ancho~'age, Alaska 99519-6,612 (907) 561-511 I STANDARU ALASKA PRODUCTION MAR 12, 1987 William Van Alen A].a~ka Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Van Alen: The following log information for Endicott wells is enclosed: 1 sepia and 1 blueline print for: P-20 Run 1 February 21, 1987 DLL/MSFL * LDT/CNL * ARRAY SONIC * SHDT NGT/SP 1 blueline print for: P-20, P-27, M-25 Run 1 * CBT * CET · . -- Rece ~ .~ska 1 blueline print for-: 0-25, H-29 Run 1 Sincerely, Bruce St. Pierre Standa~l Akz s~a Production C~mF>a n" 900 East Benson Bou~ d P.O. Bo~ 196612 AnCho~oge, Ak~sko 99~19-6612 (907) 561-511 i STANDARD ALASKA PRODUCTION March 3, 1987 William van Alen Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. van Alen: The following log information for Endicott wells is enclosed: I sepia and 1 blueline print for: P-27 Run 1 February 24, 1987 * LDT/CNL * NGT * DLL/MSFL * ARRAY SONIC * SHDT 1 magnetic tape and listing for: N-29 MWD Resistivity ~ o3g77--o Intermediate Run January 25, 1987 P-20 OH LIS February 21, 1987 Sincerely, // Received by ~/~ g ~;:¢'7: ~ Founded in Cle~elond ~,o ,n 1870 SCHLUIdBE:RGER OFFSHORE SERVICES A C)iyl$iofl of SchlbrnberOer Limited 7 ~ ~967 ~ ENDICOTT DEVELOPMENT. Staml&rd Ala81La I~roducttoa Co 000 B. Benson Bird HB 12-2 Ancborale, Ak g9519-6612 Atteflth3ll: . Bruce S~_. Peirre ?ouch 3&006t Frudhoe 147, Ak gg73&-O06! ATTB: BeFute/If. ar te Geflt~mefl: I aYlolded Sepia Eflck~d ore 3BL. orin~ of ~e. . Comp~ly Standard Ak ~rod Co Field Bndicott CET Well 3-1/N-29 SDI Coa~ty Iorth Slope State Additior~l prints ore being sent to: _J__~L_prints a 1-IYo~ded S~pia ..~a. sh Or! & Sas ~ ConseFvattou CouttSslon 3001 Porcupine DFSv~ Anchora_~e. Ak 005Oi L-%ATT.: % ~ri~ts & I Rl~hted Anchora_fe_. Ak ggJlg-O2&7 ATTll: Bob DAVis _J.J. L4>rints & I l~olsted ._~9i. ~ AICO Alq0-8791 P 0 Box 10036~ , Ancbora_fe ? Ak gg510-0360 ATTH: Lu¢llle Johnston ~n~'ints .fwiflts The film i~ returned to SAnG lecetved bv; ~_~ll~skaaska OilOil && GasGas Cons. Commiosio~ Charles U. aerrtuAum, u~ =~ud~'" .~tanclard Ata~g~'~'' production Cen' 900 East Benson . ~vard P.O. Box 196612 Anchoroge, Aloska 99519-6612 (907) 561-51 ! I STANDARD ALASKA PRODUCTION February 10, 1987 William van Alen Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. van Alen: The following log information for Endicott wells is enclosed: 1 sepia and 1 blueline print for: N-29 Run 1 January 25, * CBT 1987 RECEIVED ,~, .r, 2 1987 Alaska Oil & Gas Cons. Sincerely, Laura Fuj ika~a Received by A unit ot lhe otiginol Seondord O~1 Coml~Ony Da t e Founded in Clevelond. Oh,o. ,n ll~IU. Standard Ajadr~ Production 900 Eost Benson r~ulevord P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-511 January 27, 1987 STANDARD ALASI<A PRODUCTION William van Alen Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. van Alen: The following log information for Endicott wells is enclosed: 1 sepia and 1 blueline print for: N-29 Run 1 January 21, 1987 * NGT * LDT/CNL * FMS * DLL/MSFL * SDT * MWD Resistivity Gamma 2" & 5" Sincerely, Laura Fuj ikawa Received by Date A unit of the or,ginol Standard C~l Company Founded in Cleveland. C~,o ,n 1870 Standard Alad Productien 900 Easl Bent, on Boulevard P.O. Box 196612 Anchorage, Ala dca 99519-6612 (907) 561-5111 January 19, 1987 STANDARD ALASKA PRODUCTION William van Alen Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. van Alen: The following log information for Endicott wells is enclosed: 1 sepia and 1 blueline print for: N-29 Run 1 January 21, 1987 * 1 magnetic tape + listing OH logs Sincerely, Laura Fuj ika~a Received by Date RECEIVED ~'dAR '- 2 1987 .,a. la~ka Oil & Gas Cons. Gommissior~ Anchorage A unit of the original Standard C~l Company Founded ;n Cleveland Ohio. in 1870. .... STATE OF ALASKA ALASK. OIL AND GAS CONSERVATION COMfy 51ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [~ Stimulate [] Plugging [] Perforate [] Pull tubing Alter Casing [] Other [] 2. Name of Operator Standard Alaska Production Company 3. Address P. O. Box 196612 Anchorage, Alaska 99519-6612 4. Location of well at surface 2535' SNL, 878' WEL, Sec 8, TllN, R17E At top of productive interval 1742' SNL, 2434' WEA~, Sec. 5, TllN, R17E At effective depth At total depth 1546'.SNL, 2396' WEL, Sec, 5, TllN, R17E 11. Present well condition summary Total depth: measured 13050 ' feet true vertical 10525" feet Plugs (measured) 5. Datum elevation (DF or KB) K_BE = 55.34 Feet 6. Unit or Property name Duck Island Unit/Endicott 7. Well number N-29 SDI _A8¥ rova I number 9. APl number 50-- 029- 21678 10. Pool Endicott Effective depth: measured feet true vertical feet Junk (measured) Casing Length Size Structural Conductor 161' 30,' Surface 2425 ' 13-3/8" Intermediate 12056 ' 9-5/8"' Production Liner 1220 ' 7" Perforation depth: measured Cemented Measured depth Structural Drive Pipe 161' 3534 cu.ft. Permafrost 2480' 575 cu. ft. Glass G 12112.' 387 cu. ft. Class G 13050' True Vertical depth 161' 2480' 9854' 10523' true vertical Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary RECEIVED IViAR - 2 ]987 Alaska 0il & Gas Cons. Commission Anchomg. Intervals treated (measured) Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14. Attachments Daily Report of Well Operations MWD & SS Copies of Logs and Surveys Run L~ GCT Directi 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ¢' Signed ¢, %. ~ Title Form 10-404 Rev. 12-1-85 >nal in Duplicate Rig: PAA #7 Well' N-29 (SDI) SAPC Daily Drilling Report -- ENDICOTT December 28, 1986 at 0600 hours AFE # 717522 API 50-029-21 678 0600 Depth' 240' Day: -1 24-Hour Ftg' 134' Current Operation' Drill surface hole. Accept rig at 1600 hrs. on 12-27-86. Spud well at O001 hrs. on 12-28-86. Drill 17-1/2" hole to 240 ft. MUD TYPE-Gel WT:8.8 VIS'243 PV-28 YP-36 FL'12.8 SOLIDS: TEMP'48°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES 1416h' DLS ,, Rig: PAA #7 Well: N-29 (SDI) SAPC Daily Drilling Report -- ENDICOTT December 29, 1986 at 0600 hours AFE # 717522 API .~0-029-21678 0600 Depth: 1299' Day: 1 24-Hour Ftg: 1059' Current Operation: Tripping. Drill and survey 17-1/2" hole to 1299 ft. Trip bit. MUD TYPE-Gel WT:9.0 VIS:164 PV:13 YP:54 FL:20 SOLIDS:5 TEMP:64°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1416h: SAPC Daily Drilling Report -- ENDICOTT December 30, 1986 at 0600 hours Rig' PAA #7 Well- N-29 (SDI) AFE # 717522 API 50-029-21678 0600 Depth- 2511' Day' 2 24-Hour Ftg' 1212' Current Operation- R/U to run 13-3/8" casing. Drill and survey 17-1/2" hole to 2511 ft. mud. POH. R/U to run 13-3/8" casing. Circ. and condition MUD TYPE-Gel WT'9.4 VIS'I 53 PV'16 YP:39 FL'20 SOLIDS'8 TEMP'68°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1416h' SAPC Daily Drill lng Report -- ENDICOTT December 31, 1986 at 0600 hours Rig' PAA #7 Well' N-29 (SDI) AFE # 717522 API 50-029-21678 0600 Depth' 2511 ' Day' 3 24-Hour Ftg' ' Current Operation' NU BOPE. Rig up and run 13-3/8" casing to 2480' and cement with 3800 sacks Permafrost cement. Remove landing joint and riser. Install starting head and NU BOPE MUD TYPE- WT'9.3 VIS:41 PV:9 YP:6 FL:20 SOLIDS-6 TEMP'°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1416h. ~ Rig: PAA #7 Well: N-29 ISDI) SAPC Daily Drilling Report -- ENDICOTT January l, 1987 at 0600 hours AFE # 717522 API 50-029-21 678 0600 Depth: 2600' Day: 4 24-Hour Ftg: 89' Current Operation: Change BHA. N/U BOP's. Test BOP's. Test casing to 3000 psi - OK. Drill FC, cement and l0 ft. new hole. Perform FIT to ll.2 ppg EMW. Drill 12-1/4" hole to 2600 ft. POH. MUD TYPE-Ligno WT:9.3 VIS:41 PV:9 YP:6 FL:20 SOLIDS:6 TEMP:°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1 416h: Rig: PAA #7 Well: N-29 (SDI) SAPC Daily Drilling Report -- ENDICOTT January 2, 1987 at 0600 hours AFE # 717522 API 50-029-21678 0600 Depth: 3532' Day: 5 24-Hour Ftg: 932' Current OperatiOn' RIH. RIH w/dynadrill. Dynadrill to 3168 ft. POH. RIH. Drill and survey 12-l/4" hole to 3532 ft. dynadrill and RIH. L/D dynadrill. POH. P/U MUD TYPE- WT:9 VIS:62 PV:16 YP:12 FL:ll.5 SOLIDS:5 TEMP :6§°F SURVEY MD ANGLE DIRECTION TVD SECTION 9 2511 4 N40W 2509 37 12 2860 8.3 N15.6W 2856 70 1 5 31 52 1 5.3 N18W 3141 130 18 3436 1 9.1 N13.5W 3413 214 COORDINATES N25 aJ 56 Nl14 ~/194 ~d49 ~Y 62 vd 80 ~Yl02 141 6h: DLS 1.62 2.17 1.43 SAPC Daily Drilling Report -- ENDICOTT January 3, 1987 at 0600 hours Rig: PAA #7 Well: N-29 {SDI) AFE # 717522 API 50-029-21678 0600 Depth: 4570' Day: 6 24-Hour Ftg: 1038' Current Operation- RIN. RIH w/dynadrill. Dynadrill 12-1/4" hole to 4115 ft. POH. L/D dynadrill. P/U BHA and RIH. Drill and survey 12-1/4" hole to 4570 ft. Trip bit. MUD TYPE- WT:9.3 VIS:44 PV:13 YP:6 FL:8.5 SOLIDS:6 TEMP:°F SURVEY MI)' ANGLE · DIRECTION I'VD SECTION COORDINATES 19 3608 22 N16j 7W 3574 294 Id253 I~/117 23 3984 29.4 N21.6W 3914 434 I~ 405 ~ 167 28 4467 42.1 N17.4W 4303 71 7 N 672 I~d 265 DLS 1.86 2.07 2.10 141 6h: SAPC Daily Drilling Report -- ENDICOTT Januar.¥ 4, 1987 at 0600 hours Rig: PAA #7 Well' N-29 (SDI) AFE # 717522 API 50-029-21 678 0600 Depth: 5305' Day: 7 24-Hour Ftg: 600' Current Operation: Drill lng. RIH. Drill 12-1/4" hole to 4705 ft. survey 12-1/4" hole to 5305 ft. Trip bit. Drill and MUD TYPE- WT:9.5 VIS:44 PV:15 YP:8 FL:7.3 SOLIDS:8 TEMP:62'F -SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS '~:~ 29 4753 45' 2 N17.4W 4510 , 286 30 4943 45.6 N16.7W 4643 190 31 5132 45,4 N16.7W 4776 189 ~860 N 990 Nll19 1~/324 363 402 1.08 .34 .11 1416h' SAPC Daily Drilling Report -- ENDICOTT January 5, 1987 at 0600 hours Rig: PAA #7 Well: N-29 (SDI) AFE # 71 7522 API 50-029-21 678 0600 Depth: 6725' Day: 8 24-Hour Ftg: 1420' Current Operation .... Drilling. Drill and survey 12-1/4" hole to 6335 ft. Trip bit. Drill and survey to 6725 ft. MUD TYPE-Ligno WT:9.6 VIS'40 PV:12 YP':7 FL:6.6 SOLIDS:8 TEMP' °F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES 34 5699 45 N15.6W 5175 1585 fl1503 bV523 37 6452 45.5 N18.1W 5705 2120 I~ 2016 v~Y675 DLS .800 .47 1416h: Rig: PAA #7 Well' N-29 (SDI) SAPC Daily rjrilling Report -- ENDICOTT January 6, 1987 at 0600 hours AFE # 717522 API 50-029-21 678 0600 Depth' 7850' Day: 9 24-Hour Ftg: 1125' Current Operation-:-~ Dri 11 i rig. Drill and survey 12-1/4" hole to 7670 ft. 7850 ft. Trip bit. Drill to MUD TYPE-Ligno WT:9.7 VIS:42 PV-14 YP:8 FL-7.1 SOLIDS:8 TEMP:°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES 39 6930 45.8 N18.4W 6040 2460 rd2340 ~d 781 41 7507 46.7 N16W 6439 2877 N 2738 ~/905 141 6h' DLS .16 .38 SAPC Daily Drilling Report -- ENDICOTT January 7, 1987 at 0600 hours Rig' PAA #7 Well' N-29 ISDI) AFE # 717522 API 50-029-21 678 0600 Depth' 8348' Day' l0 24-Hour Ftg' 498' Current Operation' Repair top drive. Drill & survey 12-1/4" hole to 7860 ft. Trip bit. Drill to 8348 ft. Repair top drive. MUD TYPE-CLS WT'9'7 VIS'40 PV'14 YP:8 FL:5.9 SOLIDS'8 TEMP'°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 42 7784 49'7 N16.7W 6623 3084 43 7974 49'0 N14. gw 6747 3227 44 8169 49.4 N13.gw 6875 3376 1~2936 3074 ~U3218 1~963 ~1003 1039 1.10 O. 81 0.44 1416h' Rig' PAA #7 Well' N-29 (SDI) SAPC Daily Drilling Report -- ENDICF)TT January 8, 1987 at 0600 hours AFE # 71 7522 API 50-029-21 678 0600 Depth- 8810' Day- ll 24-Hour Ftg- 462' Current Operation' Drilling. Drill and survey 12-1/4" hole to 8440 ft. Trip bit. Drill to 8810 ft. MUD TYPE-CLS-Gel WT:9.9 VIS:43 PV:17 YP-7 FL-5.8 SOLIDS:Il TEMP'°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES 45 8358 48.7 N14.6W 6999 351 9 N3356 IN1075 46 8534 48.2 NI3.9W 7115 3650 INI3484 ~ll07 1416h' DLS 0.46 O. 41 SAPC Daily Drilling Report -- ENDICOTT January 9, 1987 at 0600 hours Rig: PAA #7 Well: N-29 ~SDI.) AFE # 717522 API 50-029-21678 0600 Depth: 9118' Day: 12 24-Hour Ftg: 308' Current Operation: POH. Drill to 9118. Trip for bit. Test BOP's. RIH to 3512. Check Teleco, insufficient pressure. POH checking for washout. MUD TYPE-CLS-Gel WT:9.8 VIS:38 PV:IO YP:7 FL:6.2 SOLIDS:lO TEMP:93°F SURVEY MD ANGLE DIRECTION I~D SECTION COORDINATES DLS 47 8821 47.6 N12.4W 7308 3863 369l 11 55 48 9042 46.9 N12.4W 7458 4025 3860 ] 1 90 0.44 0.32 SAPC Daily Drilling Report -- ENDICOTT January 10, 1987 at 0600 hours Rig' PAA #7 Well. N-29 (SDI) AFE # 717522 API 50-029-21 678 Current Operation. POH. 0600 Depth' 9643' Day' 1 3 24-Hour Ftg' 525' POH for wash out. RIH. Drill and survey 12-1/4" hole to 9643 ft. Lost pump pressure. POH for wash out. MUD TYPE-CLS-Gel WT:9.8 VIS'40 PV'lO YP'6 FL'5.8 SOLIDS-11 TEMP'91 °F SURVEY MD 49 9191 50 9387 ?NGLE DIRECTION TVD SECTION COORDINATES 46.4 N12.8W 7560 41 34 ~d 3956 b~121 4 45.8 N11.9W 7696 4275 ~d 4094 ~/1 244 DLS 0.39 0.60 1416h' Rig: PAA #7 Well: N-29 ISDI) SAP[i, Daily Drill ing Report -- ENDICOTT January ll, 1987 at 0600 hours AFE # 717522 API 50-029-21 678 Current Operation: Drilling. POH for washout. hole to 9800 ft. MUD TYPE-CLS-Gel WT:9.8 VIS:39 0600 Depth: 9800' Day: 14 24-Hour Ftg: 157' Found washout. RIH. PV:9 YP:7 FL:6.0 Drill and survey 12-1/4" SOLIDS:lO TEMP:82°F SURVEY MD ANGLE DIRECTION 51 9568 44.8 N13.1W TVD 7823 SECTION COORDINATES 4403 AY4219 b~/1271 1 41 6h: DLS 0.87 Rig: PAA #7 Well: N-29 (SDI) SAPC Daily Drilling Report -- ENDICOTT January 12, 1987 at 0600 hours AFE # 71 7522 API 50-029-21 678 0600 Depth: 10,065' Day: 1 5 24-Hour Ftg: 265' Current Operation: Drilling.~ .- Drill and survey 12-1/4" hole to 9879 ft. 1 0,065 ft. MUD TYPE-CLS-Gel WT:9.8 VIS:41 PV:12 YP:9 FL:6.0 Trip bi t. SOL I DS: 1 0 Drill to TEMP:83°F SURVEY MD ANGLE DIRECTION TVD SECTION 52 9796 45.8 N12.8W 7984 4565 53 9956 45.9 N1 2.4W 8095 4681 COORDINATES ~ 4377 NYl 307 rd 4489 t~Y 1332 141 6h: DLS 0.45 0.19 Rig: PAA #7 Well: N-29 (SDI) SAPC Daily Drilling Report -- ENDICOTT January 13, 1987 at 0600 hours AFE # 71 7522 API 50-029-21678 0600 Depth: 10,395' Day: 16 24-Hour Ftg: 330' Current Operation: Drilling. Drill and survey 12-1/4" hole to 10,375 ft. Trip bit. Drill to 10,395. MUD TYPE-CLS-Gel WT:9.8 VIS:42 PV:12 YP:IO FL:6.0 SOLIDS:lO TEMP :94°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES 54 10245 43.2 N11.4W 8337 491 8 bj4722 ball 381 1 41 6h: DLS 0.82 SAPC Daily Drilling Report -- ENDICOTT January 14, 1987 at 0600 hours Rig: PAA #7 Well' N-29 ISDI) AFE # 717522 API 50-029-21 678 0600 Depth' 10,900' Day' 1 7 24-Hour Ftg' 505' Current Operation' Drilling 12-1/4" hole. Drilling to 10,900'. MUD TYPE-CLS-Gel WT'9.9 VIS'39 PV'll YP-IO FL'6.2 SOLIDS:lO TEMP'104°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 55 10,523 41.3 Nll.4W 8505 5071 4873 1412 0.61 56 10,712 39.8 NIO. 7W 8652 5198 4998 1436 1.05 141 6h: Rig' PAA #7 Well' N-29 (SDI) SAp,r, ~aily nrilling .Deport -- E,~,~ICnTT January 1E, 1987 at OGO0 hours AFE # 71 752? API 5F~-029-21 678 0600 Depth' 11,120' Day' 18 24-Hour Ftg' 220' Current Operation' Drilling. Drill and survey 12-1/4" hole to 10,989 ft. ll,120 ft. MUD TYPE- WT:IO VIS'38 PV'12 YP-7 FL'6.2 SOLIDS'lO Trip bi t. Drill to TEMP.96°F SURVEY ~ID ANGLE DIRECTION TVD SECTION 57 10,904 38.1 NIO.3W 8797 5315 COORDINATES 511 3 1 457 .92 1 41 6h- DLS Rig: PAA #7 Well: N-29 /SDI) SAPC Daily Drilling Report -- ~I.IDICF)TT January 16, 1987 at 0600 hours AFE # 71 7522 API 50-029-21678 0600 Depth: 11,458' Day: 19 24-Hour Ftg: 338' Current. Operation: Tripping. Drill and survey 12-1/4" hole to 11,458 ft. Trip bi t. MUD TYP£-Ligno WT:IO VIS:42 PV:14 YP:12 FL:6 SOLIDS:lO TEMP: °F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES 58 11,085 37.1 N9.6W 8940 5425 /N/5221 1~1476 59 11,275 37 N7.2W 9092 5539 INI5335 ~N/1493 1 41 6h: DLS · 60 .76 Rig: PAA #7 Well: N-29 (SDI) SAPC Daily Drilling Report -- CNPICP, TT January 17, 1987 at 0600 hours AFF. # 717522 API S0-029-21678 0600 Depth: 11,950' Day: 20 24-Hour Ftg: 492' Current Operation: Drilling. RIH. Drill and survey 12-1/4" hole to 11,950 ft. MUD TYPE-Ligno WT:IO.2 VIS:42 PV:15 YP:12 FL:5.5 SOLIDS:Il TEHP: 1 06 °F SURVEY MD ANGLE DIRECTION TVD SECTION 60 11,460 36.5 N7.2W 9240 5648 61 ll ,650 37.1 N4.7W 9392 5761 62 11,836 37.2 N2.2W 9540 5871 COORDINATES N5445 N5558 ~5670 vN/1 507 ~1518 vvq 525 1416h: DLS .27 .85 .81 - J---; C Gas Cons. Rig: PAA #7 Well- N-29 ISDI) SAPC Daily Drilling Report -- ENDICOTT January 18, 1987 at 0600 hours AFE # 71 7522 API 50-029-21678 0600 Depth' 12,133' Day' 21 24-Hour Ftg' 183' Current Operation' Run casing. Drill 12-1/4" hole to 12,133 ft. Short trip CBU. POH. Rig up and run 9-5/8" casing. MUD TYPE-Ligno WT:IO.2 VIS'40 PV'15 YP'll FL'5.1 SOLIDS'Il TEMP'°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1416h- Rig' PAA #7 Well' N-29 (SDI) SAPC Daily Drilling Report -- EHDICOTT January 19, 1987 at 0600 hours AFE # 717522 API 50-029-21678 0600 Depth' 12,133' Day: 22 24-Hour Ftg' ' Current Operation' Drilling cement. Run 9-5/8" casing. Shoe at 12,111 ft. Mix and pump cement. Install tubing spool. Run and test pack ~ff. Test BOPE. P/U 8-1/2" BHA and RIH. Drill cement. MUD TYPE-Ligno WT'9.7 VIS'39 PV'll YP'8 FL'6.2 SOLIDS'8 TEMP:°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS l~,16h- Rig: PAA #7 Well: N-29 (SDI) SAPC Daily Drilling Report -- ENDICOTT January 20, 1987 at 0600 hours AFE # 71 7522 API 50-029-21678 0600 Depth: 12,709' Day: 23 24-Hour Ftg: 575' Current Operation: Tripping. Drill cement. Test casing to 3000 psi - OK. Drill out shoe. Perform FIT to 13.5 ppg EMW. Drill 8-1/2" hole to 12,709 ft. Trip bit. MUD TYPE-Ligno WT:9.9 VIS:39 PV:12 YP:7 FL:6.6 SOLIDS:lO TEMP:°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1416h: Rig' PAA #7 Well' N-29 (SDI) SAPC Daily Drilling Report -- ENDICOTT January 21, 1987 at 0600 hours AFE # 717522 API 50-029-21678 Current Operation: Dri~ll ing. Trip bit. MUD TYPE-CLS-Gel WT:IO.O 0600 Depth- 13,030' Day- 24 24-Hour Ftg' 322' Drill 8-1/2" hole to 13,030 ft. VIS'38 PV'12 YP:7 FL'6.6 SOL IDS :l 1 TEMP' 106°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1416h- EECEIVED Oil & Gas Cons. An.ho, Rig: PAA #7 Well: N-29 (SDI) SAPC Daily Drilling Report -- ENDICOTT January 22, 1987 at 0600 hours AFE # 717522 API 50-029-21678 0600 Depth: 13,050' Day: 25 24-Hour Ftg: 20' Current Operation:~ Open hole logging. Drill 8-1/2" hole to 13050 ft. (TD). POH. Run open hole logs. MUD TYPE-CLS-Gel WT:IO.O VIS:40 PV:12 YP:7 FL:6.8 SOLIDS:Il TEMP: °F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1416h: Rig- PAA #7 Well- N-29 (SDI) SAPC Daily Drilling Report -- ENDICOTT January 23, 1987 at 0600 hours AFE # 71 7522 API 50-029-21678 0600 Depth' 13,050' Day- 26 24-Hour Ftg' ' Current Operation' Running liner, Run open hole logs. RIH. MUD TYPE-CLS-Gel WT:IO.O VIS'42 PV'14 Circ. POH. Run 7" liner. YP'9 FL'6.8 SOLIDS'Il TEMP'°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1416h. RECEIVED 2 1987 Alas,.ka 0il & Gas Cons. Commiss;e:': Anchorage Rig: PAA #7 Well: N-29 (SDI) SAPC Daily Drilling Report -- ENDICOTT January 24, 1987 at 0600 hours AFE # 717522 API 50-029-21678 0600 Depth: 13,050' Day: 27 24-Hour Ftg: ' Current Operation: RIH w/cleanout assy.. Mix and pump cement. Bump plug - OK. POH tools. RIH 8-1/2" cleanout assy. Tag cement at 11,490 ft. Drill cement to liner top at 11,834 ft. Circ. POH. RIH with 6" cleanout assy. MUD TYPE-CLS-Gel WT:IO.O VIS:44 PV:15 YP:ll FL: SOLIDS: TEMP: °F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 141 6h: SAPC Daily Drilling Report -- ENDICOTT January 25, 1987 at 0600 hours Rig' PAA #7 Well' N-29 (SDI) AFE # 717522 API 50-029-21678 0600 Depth' 12,960' Day: 28 24-Hour Ftg: ' Current Operation- Lay down 5" DP. RIH w/6" cleanout assy. Test liner lap to 3000 psi. - OK. RIH and tag cement at 12,709 ft. Drill to 12,960 ft. {Shoe at 13,048 ft.). Circ. Displace well to 9.6 ppg brine. Test casing to 3000 psi - OK. POH. MUD TYPE-Brine WT'9.6 VIS- PV- YP- FL' SOLIDS' TEMP'°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1416h. Rig: PAA #7 Well: N-29 ISDI) SAPC Daily Drilling Report -- ENDICOTT January 26, 1987 at 0600 hours AFE # 717522 API 50-029-21678 0600 Depth: 12,960' Day: 29 24-Hour Ftg: ' Current Operation: Move rig. POH. Run open hole logs. Run #1: CBT/VDL/GR/CCL Run #2: GCT to surface Fill top 250 ft. of hole with diesel. Run hanger and 1 joint 4-1/2" tubing. N/D BOPE. N/U master valve and test. Release rig at 0200 hrs. 1-26-87. Move to P-27. MUD TYPE-Brine WT:9.6 VIS: PV: YP: FL: SOLIDS: TEMP:°F SURVEY HD ANGLE DIRECTION TVD SECTION COORDINATES DLS _ 1416h: RECEIVED IAR '- 2 1907 Gas Cons. Commission Anchorage STATE OF ALASKA ALASK. ~ OIL AND GAS CONSERVATION COMN, _,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon E~ Suspend [] Operation Shutdown [] Re-enter suspended well :] Alter casing f.i) Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [3 Perforate I~ Other 2. Name of Operator 5. Datum elevation (DF or KB) Standard Alaska Production Company KBE = 55.34 feet 3. Address 6. Unit or Property name P. O. Box 196612, Anchorage, Alaska 99519-6612 Duck Island Unit/Endicott 4. Location of well at surface 2535' SNL, 878' WEL, Sec. 8, TllN, R17E At top of productive interval Proposed 1640' SNL, 2425' WEL, Sec. 5 TllN, R17E At effective depth At total depth Proposed 1518' SNL, 2471' WEL, Sec. 5, TllN, R17E 7. Well number N-29 SDI 8. Permitnumber 86-190 9. APInumber 50-- 029-21678 10. Pool ~ndicott 11. Present well condition summary Total depth: measured true vertical Effective depth: Casing Structural Conductor Surface Intermediate measured true vertical Proposed Length 161' 2444' 12072' Production Liner 1369' Perforation depth: measured true vertical Size 30" 13-3/8" 9-5/8" ,! Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) feet feet Plugs (measured) feet feet Junk (measured) Proposed Cemented Measured depth Structural Drive Pipe 3700 cu. ft. Permafrost 575 cu. ft. Class G 161' 2500' 12128' 440 cu. ft. Class G 13247' Proposed ~ue Verticaldepth 161' 2500' 9746' 10546' RECEIVED FEB- ]987 Alaska 011 & Gas Cons. Commls?,: Anchorage 12.Attachments Description summary of proposal [] Detailed operations program E~ BOP sketch 13. Estimated date for commencing operation [Hid 1987 14. If proposal Was verbally approved Name of approver Date approved 15 h reby certify that the foregoing is true and correct to the best of my knowledge Signe~: ~,~. ~ Title Division Drillinq Enqineer Date Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearance "~ "" ~"~ ~," by order of ~~¢ Commissioner the commission Date ~ Form 10-403 Rev 124-85 Submit in triplicate WELL N-2g (SDI) Permit Number 86-190 Approval Date 12-11-86 OPERATIONS Well operations will be shutdown after clean out to 7" float collar. Test 7" liner and lap to 3000 psi. Change over to NaC1 packer fluid. Nipple down BOPE. Install master valve with blind flange on wellhead and release rig. Run CBT/VDL/GR/CCL in 7" liner and gyroscopic survey from PBTD to surface and downsqueeze the 13-3/8" x 9-5/8" annul us wi th a non-freezing fluid once rig is off location. The well will be completed by moving a rig on location in mid-1987 and perforate well under balanced utilizing drill pipe conveyed guns. Flow well for simple clean-up. Kill well and complete with straddle-pack/packer tailpipe configuration using 9-5/8" and 7" packers with 3-1/2" tailpipe run on 4-1/2" 12.6#/ft., L-80 TDS tubing with GLM's. A sub surface safety valve will be installed below base of permafrost. Install and test tree. Release rig. i ECEIVED FEB 4 1987 Aias~ Oil & 8as ~na. Anchorage JGV/pm/1489D STATE OF ALASKA ALASKA OIL AKD GAS CONSERVATION CO~tMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: P~E: Receipt of the fol lowing material which was transmitted via is hereby acknowledged: DESCRIPTION Copy sent YES to se~r NO~=,N SCHLUMBERGER OFFSHORE SERVICES A Division of Schlumberger Limited HOUSTON, TEXAS 77001 January 27, 1987 'Standard Alaska Production Co 900 E. Benson Blvd. lib 12-2 Anchorase,.Ak 99519-6612 AHention' Lavra Fu~lkawa PL.r~,AB[ REPLY TO ICHLUMBERGER oFIr~HoRE eERVICEe Pouch 340069 Prudhoe Bay, AK 99?34-0069 Attn: Bernie/Harie Gentlemen: Enclosed ore 3BLprints of the CBT, R1 ~ /~/~? Company Rtandard AK Prod Co ,Well 3-1/N-29 SDI Field Endicott ,Coun~ North Slope State .IBL nrints & 1RF°lded~~_ Alaska Oil & Gas 3001 Porcupine Drive I BL prints 909 ~. 9Ih Ave A~c~oTe[e, AK 99519-0247 Attn: Bob Davis I RRolled Sepia I BL prints ARCO AN0-879E &nchora._Re, · AK 99510-0360 Attn: Lucille Johnston prints I RRolled Sepia _LBl~prints AHOCO Production Go AMCKI_.0 R,t ldt nE 167/i Brnnd~nv 1 RRolled Sepia A_BL_prints EX~ON Co-_party, US_a_ 800 Bell St (too-_ 2917-2) ltouston.. TX 77002-7126 Attn: Steve Idi 1 son prints prints The film is returned to SAPC [eceived by: Date: We appreciate th/e4~rivil~f serving ]~ou. ,/~. !~.: ~: i~' .: 'f? ;::. i; SCHLU R FFSHORE SERVICES ~ / i ~. k./'--' - ~CLhar~les R. Herri~an MEMORAI "')UM TO: THRU: FROM: Stat of Alaska ALASKA OIL ,,~qD GAS CONSERVATION COM~MISo~ON C. V rton ~ DATE' January 9, 1987 Chai~'~~~~'~- ~ FILE NO.: D.BDF. 94 · Lonnie C Smith ~.,:~,!'~ o TELEPHONE NO.: Commissioner Bobby D. FosteriO Petroleum Inspector SUBJECT: BOP Test SAPC DIU - ~ Well N-29 SDI Permit #86-190 Endicott Oil Pool W_ednesda_yDecember 3!, 1986: The BOP test began at 10:30 a.m. and was concluded at 6:30 p.m-~ 'As the attached BOP test report shows, there were 3 failures, two of which were repaired/replaced and I will be notified. In summary, I witnessed the BOP test on Standard Alaska Production Company's Endicott well N-29 SDI. Attachment STATE Or ALASKA 'ALASKA OIL & C~.~ COKSERVATION C .O~-~SSION ~.0.P.E. Inspect/on Report ~ocation, 6eneral~Uell. Si~~ Mud Svst~s Visual Audio Trip Tank Pi: Gauge Flow Monitor Gas Detectors BOPE Stack Annular Preventer '/ Pipe Rams ~ Blind P.~--~ / ACCUMU~TOR SYSTEM Full Charge Pressure ~ Pressure After Closure / Pump incr. clos. pres. 200 pslg. Full Charge Pressure Attained:- · Controls: Master ~ psig psig Test Pressure Choke Line Valves R.C.R. Valve F,:L!! Line Valves Check V -,.ire Test Rest~:s: Faiiu:es ~ Ke!!v and Floor Safety Valves . Upper Kelly / Test Pressure ~,,-o Lower Kelly ./ Test Pressure ~o~U Ball T)~e / Test Pressure ~z~ inside BOP / Test Pressure ~ Choke .W. anifoid~~- Test Pressure No. flanges ~ ~ Adjus:abie Chokes J Mvdrauical!v o~erazed choke ~ Test Time ~ hrs. Repair or Replacement of failed equipmen: :o be made ~iuhin Eay~ and Inspector/ o Co~.issiom office notified. '- _- . . / / ~ , - ~//~ ~:;¢~ ~ 4-~ A~', ~ /~~~- ¢ ~' ~~.~-~ J ~ .-. --' Dis:~ibu:~om - orig. - A0&GCC . .~~ cc - Supervisor '.ns . December 11, 1986 Mr. R. S, Allan Division Drilling Engineer Standard Alaska Production Company P.O. Box 196612 Anchorage, Alaska 99519-6612 Telecopy: (907) 276-7542 Re: Duck Island Unit N-29 SDI Standard Alaska. Production Company Permit No. 86-190 Sur. Loc. 2535'S~,~, 878'WEL, Sec. 8, TllN, R17E, bM. Btmhole Loc. ]518'S~IL, 2471'WEL, Sec. 5, TllN, R17E, 1~.~. Dear Mr. A1 lan: Enclosed is. the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled, l~ere a diverter system is required, please also notify this office 24 hours prior to Commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. V~z'V~,t r u I Y/Ydhr-s ?, "'" ' Chairman o f Alaska Oil and Gas Conservation Co~ission BY ORDER OF THE CO~.~ISSION dlf Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~.r. Doug L. Lowery STATE OF ALASKA ALASKA (.,,- AND GAS CONSERVATION CO,,,MISSION PERMIT ---TO DRILL 20 AAC 25.005 Slot ,, la, TyPe of work Drill [] Redrill OI lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] Deepen[]J Service [] Developement Gas [] Single Zone [] Multiple Zone [] 2. Na'me of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Standard Alaska Production Company 56' feet Endicott Field ~'.' Address 6. Property Designation Endicott Oil Pool P. O. Box 196612 Anchorage, AK 99519-6612 ADL 47502 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 2535' SNL, 878' WEL, Sec. 8, TllN, R17E Duck Island Unit/Endicoi:t At top of productive interval 8. Well nu ,tuber Number 1640' SNL, 2425' WEL, Sec. 5, TllN, R17E N-29 SD~I K00683449-G-14 At total depth 9". Approximate spud date Amount 1518' SNL, 2471' WEL, Sec. 5, TllN, R17E December 15, 1986 $200,000.00 12. Distance to nearest 13. Distance t~) nearest well 14. Number of acres in property 15. Proposed depth(MD and TVD property line Surface 13,247' ND ADL:_;3,12828 1640feet 20 feet 2560 l0; 546 ' ?VD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 2600feet Maximum hole angle44_~ Maximum surface 3900 psig At total depth (TVD) 9855 ' 4840 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" Str]~ctural Drivi; Pipe 105' surfac( ~ 161' 161' Drive L7-1/2' 13-3/8" 68~ L-80 Butt. 2444' Surface 2500' 2500' 3700 cu. ft. Permafros' L2-1/4" 9-5/8" 47# NT80S NSCC .10329'Surface 10385 8500' 320 cu. ft. t2-1/4" 9-5/8" 47# NT95H~ NSCC 12072' 10385 8500'12128 9746' 575 cu. ft. Class G 8-1/2" 7" 29# SM-lID Butt, 1369'1 11878' 9567'i13247 10546' 440 cu. ft. Class G 19. To be complete(:J"for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor S u rface Intermediate Liner Perforation depth: measured ~,!a~','.g 0JJ ~';~ ;..!;~,. ';, {.'..;;~ .,. ~ ...... true vertical 20. Attachments Filing fee [] Pro'~erty plat ~ BOP Sketch [] Diverter Sketch [] Drilling program ~ Drilling fluid program ~ Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge ~,/C.,. Date I~. "~hed ~---._¢. ~ Title Division Drilling Engineer Commission Use Only ,, Permit Numb_6_190e,~ 50- 029-21678 12/11/86 for other requirements Goneition~ et approval Samples required ~ Yes ~ No Mud log required L-] Yes [~ No Hydrogen sulfide measures [] Yes [] No Directional survey required I~Yes [] No Required wor~~,~r~"/~~M; [~ 1OM; [] 15M Other:. -- ~( /'/~~./~'~1,} /~/,,~ by order of Approved by ~ .__~' Commissioner the commission Date Form 10-401 Rev. 12-1-85 PROPOSED DRILLING AND COMPLETION PROGRAM WELL 3-1/N-29 0 bj ecti v ~ Well N-29 will be drilled as an oil production well. Zone 2B is the primary objective; zones 2A and 3A are secondary objectives. Total depth will be 10490 ft TVD ss to allow total penetration of potential tar mat. The completion will be run in mid-1987. !'~i..ii . O!)eration Execute a rig move from slot 3-33 to slot 3-1~'~h~'~i'i~'?''~':-:-'': ...... ~'~'::~!'~:" 17-1/2" hole to 2500 ft. and cement 13-3/8" 68#/ft., L-80 Buttress casing to surface. Pressure test casing. Install BOPE. Maximum BHP is 4840 psi at 9855 ft. TVDss. Maximum possible surface pressure is 3900 psi based on a full gas column. Drill out casing and 5 ft. of new hole and conduct a formation leak-off test. Vertically drill 12-1/4" hole to 2600 ft. then directionally drill to the intermediate casing point above the Kekiktuk formation. Run and cement 9-5/8" 47#/ft., NT80S and NT95HS, NSCC casing. No abnormal pressures are expected in the 12-1/4" hole section. Pressure test casing. Drill out casing shoe and 5 ft. new hole and conduct a formation leak-off test. Drill 8-1/2" hole to TD. Run logs. Run and cement 7" 29#/ft, SM-Il0 buttress liner to TD with approximately 250 ft. of lap in the 9-5/8" casing. Clean out to float collar. Test casing and lap to 3000 psi. Change over to NaC1 packer fluid. Install tubing hanger with one joint of 4-1/2" tubing. Nipple down BOPE. Install master valve with blind flange on wellhead and release rig. Run CBT/VDL/GR/CCL in 7" liner and gyroscopic survey from PBTD to surface and downsqueeze the 13-3/8" x 9-5/8" annulus with Permafrost cement followed by a non-freezing fluid once rig is off location. Move rig on location in mid-1987 and perforate well under balanced using guns run on drill pipe. Flow well for simple clean-up. Kill well and complete with a wireline run and set 7" packer with 3-1/2" tailpipe, and a 9-5/8" packer with 3-1/2" tailpipe and 7" packer run on 4-1/2" 12.6#/ft., L-80 TDS tubing with GLM's. A sub surface safety valve will be installed below base of permafrost. Install and test tree. Release rig. B.O.P. STACK CONFIGURATION 13-S/8 IN. TRIPLE RAM STACK SO00 PSI WP DRILLING ANNULAR PREVENTER 2 IN. KILL LINE CHECK HAND HAN GATE GATE I I I I PIPE RAMS 1 BLIND RAMS I I DRILLING SPOOL 4IN. CHOKE LINE GATE GATE ] I PIPE RAMS [ l, ~ · .Gl: ;~':~;"ii-:-~.!i~'i'~,-, .... Closest Approach Analgsis .... ..,,~.j >. ?,-,.x - '" -.` ., .. - . Search Rmdius= 5000 ' COURSE LINE" ` For proposed mell~. SI-N2~[32-0-11-17] Note' All depths in ~eet Belo~ Kellg Bushing (BKB) P a g e 1 '~ .......... , . ........ ii/:.;C..1.6 se~g{:-./~pp r oa C.h ..... WE~L I-DENT -. ~.' ":.'-ii:7~? .... ':'" '.'"": ....~,'-'-'i/NEARBY\ CLOSEST TVD-..".; " TVD DEPART DISTANCE TVD .:,.-~:. ': t, '.. 0.: 0'-'.:', ~ "..:, ,:,e.'::,~..t ~O:. 0 :. z.~:' ::,. ,,~:. :?~::7-~: :i"' ? "0'{:':..0 " !: :[::¥ --- . , ;.0'. 'O"ii .}:2: !:?:{.~;": 170~:0.'~'7ri.::'.[' :;:: .... :'i-, ::,. . .,.?:..¥ r.;.,.,.:~.,.!' ::~'.,F'?''"'' ,..:: '.' ?...?. :?::....{:D~.:' .... . }. : O. O O;:"O 0. O O. O z' 1 ~.'7 AO00-O000002 ?? .... ~.::,., .-:{ ,~2 ,]7~,,~~ '?.v- ,, :,..~...: ..St .. ..... . .,...,.. ~:.,, .: ..: - ,,,,ao0:,0000o2 .... . , SI -25 A000~0000026 SI -26 A000-0000028 ^00o-o:oo06 , .... SI-49 AO00-O000050 ~I-50 A029-2028000 SI-DI I A029-202800 i Si-DI2 A029-215~900 Si --~35 A029-2 I. 58600 Sl ---M33 A O'.,:.} 9-- ~'2162400 SI -O~9 ,40,7!5~- 2 ! 64000 ~ -r _.'rNa /, 029- 2 .t 54001 S i -i"I°~, 5 A,:5;29-21 64500 5 ! - i'q32 Vertical /PROPOSED\ DEPART O. 0 O. 0 O. 0 O. 0 207. 6 0.0 0.0 0.0 0 0 31.8. 4 3914. 5 414. 5 5003. 779 9 2016. 5 3658. 2 258. 9 4450. 7 1042 7 t 840. 6 300. 6 O. 0 300 0 0 I 259. 80!. 0 0.0 158. 0 i 000. ~ o 0 1000 0 Intersect'ion /NEARBY\ TVD DEPART 30 1 ? <';. (} ~ ;'"', ?"] z% ].OZ. 9 o. 0 iOC, 0 300 5 O. 0 VERTICAL DISTANCE 109. The ~set! mhich comes closest to p'ropo-sed well is' Closest approach '~iCE OFF ~or this distance 2600. N--- SDI Endicott Row 3 Slot 1 \ ,~ T. 12 N. 4 T. IIN. Satellite Drilling Islond(SDI) ~ ~~Howe Ish nd 18 17 16 Duck liland" '1~~ ...... ~..,: ~ ,~-. ~ ~%~. pR!Oi'~'~':~'ED WELL LOCATIONS MPI Wells Located In Sec.36, T. IZN.,R.16E.,Umiat M. SDI Wells Located In Sec. 8,T. IIN.,R.17E.~Um'~of M. PREPARED FOR SOHIO ALASKA PETROLEUM CO. DRW NO. I1(;;' 85 SHEET I of I0 REV. 0 PREPAR ED BY F.R. BELL 6 kSSO.C. PRUDHOE BAY OFFICE PRUOHOE BAY, ALASKA DATE: NOV. 13, 1985 SCALE: I"=1 MILE DRAWN BY: R.G.T. i C:NECKED'SY ' 8.E. ii i ~7~000 O0 ~ ~6:58 ~o~4z 44 46 _48 ~O0o ~ ~0~)'o o u~o 000 0 Indicates well CERTIFICATE O_.F SURVEYOR 4~ Indicates C41c,leted SsctiaaClraer Poeitia. Indicates hr~dlcder ~f~t Distance I ~rby ce~ify ~atlam properly registered end lad~etee Perpe~dicullr Offlet licenled~ practice landsu~eying inthe State ~ (per~ndicul~ disleKe ~eHmfm each wall) AIQIKQ a~ that this ~let reprelen~ Iff ~Nlld I~et~n ~r the Well numbers shown above. All PLAT lurveylnl vel ~ne byre or ,nder my lUpeviliol, SDI PROPOSED WELL LOCATIONS end that ell dimensions and details are correct. LOCAT[D IN SEC. I, T. IIN., 1.17 E. UMIAT M. DRW. NO. 116-85 PRIrpAREO BY SHEET ? of IO F.R. BELL & ASSOC. RUDHOE BAY OFFICE REV. O /PRUDHOE BAY~ ALASKA / PREPARED FOR SOHIO ALASKA PETROLEUM CO. )AT[: NOV. I$, Ills SCALE: I"" DRAWN BY: CHECKED BY: I.E. I Y- S970ti,5.47 N- 710il70.15 70oi9'20.240t· 147- $1' 49. 27tt· 2'535.21 i71.0~ X' Z70i63.10 E' 46754i.06 _. 2 Y-~970796.40 N-7801819.45 70o19'18.5842, 147~{'"'4B"~610~' 270~3,73 8~5.60 X- 270181.57 E- 467547.32 - 5 Y- 597096'6 51 ~ N- 7801871 22 70 1c~°20."2542"''* 147~51'48 9908" 2'5~ 9~ · X= 270173.75 E= 467544.08 ................................. ~ ...... · t ' X 270191.51 E- 467550 34 j X- 270183.69 i E- 467547.1! { { - 4, & Y- 5970798,49 N- 7801820,17 [70019'1EI.61'08'' 147051'48'.0-321" X- 270201,46 E- 467551,17]... 7 Y- 5970968.60 N,' 7801871,95 J70c19'20."2808" 147°~i"48'.412'2i-" 2531.23' {i4'B~31 X- 270195.64 E' 467550.13 .f. 8 Y' 5970799.54 N' "780182~). 54 70c19'18.6240' 147c'*~1" 47. 7429' 2699.67 825.86 x- 2702~1.41 E- 4675S~.39 ' '9 V-5970969'.4, S N-?SOLS72.32 70olv'20.'2940' ~7o=~'~S.~232' 2~iV.a7 X- 270~0~.~e E- 447SS3.~ 10 Y- 5970800.58"* N- 7801~20.90 70~19'1B.6373' 147051'47.4537.. " 2698.32 B15.95 I- 270221.35 E- 467559.42 11 Y- 5970970.69 N- 7801872.*9 70c19'20.3073' 147c51'47'.B340' ..... 2528.52 8'~8.49 X- 270213.53 E- 447556.18 ...... 12 Y- 5970801.43 N- 7801821.27 70o19'18.6506" 147°51'47.1645" 2696.97 806.04 x- 27023~.30 E- 4~7~42.~4 X- ,~,70223.47 E- 447SSS.2t X- 2702~.2~ E- e47S4S.~7 15 Y- 5970972.79 N' '7B01873.43 70'~19'20.5338' 147°5'1"'47.2554' 2525.82 l- 270233.42 E- 467562.23 16 Y- ~970803.72 N-'TBOIB22.0[ 70°19'tB.6771' i47°51'46.5862" 2494.27 786.2i X- 270251.19 E- 447568.49 17 Y" ~970973.B3 N- 7801873.80 70°19'20.1471" 14~°5~'46.9664" 2524.47 798.75 1- 270243.~6 E- 4~75~5.2~ is v. svToe04.74 w-"TSO'id22.3s 70olv'is.4v04· i~osi'44.mvTO' 24v~.~i 774.30 X" ~70261..13 E- 467~7l 19 Y" ~970974,B8 N" 7801874.16 70019'20.3604" 147°51'46.6'77'2" 2~23.'12 788.83 X" 2702~3.31 E" 467568.28 20 Y- ~970B05.81 N- 7B01822.7~ 70e~9'18,7037' S47°~I'46.007B' 2691,56 766,39 X~ 270271,08 E- 467~74.54 21 Y- ~970975.9~' N- 7B01B74.~3 70°19 ' 20. 3736' ~47°5~'46.3880' " 2521.76 77~.92 X- 270263.2~ E- 467~71.30 , . i i i i ii I i u i i i iii i i i i SDI PRO~SEDWELL L~ATI~ ~ST ~ ~ LOCkTED IN SEC. I , T. II N., ~.I7E. U~IkT ~..~~~ ~ SOHIO ALASKA PETROLEUM CO. · .... --'~~~~~.~ DRW. NO. ,,6-85 PREPA,ED BY DATE:NOV. · t .~.~~_ SHEEr , of I0 ER. BELL & ASSOC. SCALE: N/A ~ ~SSl~~ ~ PRU DHOE BAY OFFICE ...... ORA WN B .y REV. O PRUDHOE BAY, ALASKA CHECKED * X- ~70211.02 E- 4&7~77.~6 23 Y- ~970976.97 N- 7801874.90 70~19'20.~869' 247°~1 46'-0-~9' 2~20.41 769.01 X~ 270273.20 E- 467~74.33 ~4 '~. ~e~oeo~.eo ~-~-Y"e6"i-'~-~-~T4e-'r~-6'~':~e.~:o~-'T~'4~-'~:.~s.4~4, ': ~eee.~e X- 270290.97 ~ E' 467~0.~9 ~ - ~- ;-~'--~*~'6~-74--~-N'-~8'01'82-5--.'85~-,70cl-9;'1'8.7455" i 147~ 51' 45.1405" ; 2&87.51 756.65 2z ~. ~gzoee2.~9 ~. ~eo~eze.~4 ~0= ~9'20.4~3~-"~-j4~"4~"6~29' 251~.6~ 7i9--,'44 X~ 270322.92 E~ 467~89.4~ ~e ~- ~9~oe:3.~ N- ~80~.~ 70~9'~e.~6~· :4zo~x'4s.ges~· Xm 270340.69 E- 467~9~. 71 . 29 Y- 5970983.24 N- 7e01877.11 70019'20.466~' 147°51'44.3637' 25~2.30 j 709.~3 X- 270332.87 E- 467~92.48 30 Y- ~970814,17 N- 780182~.69 70°19'IB.B098' 14~5~'43.6943' 26B0.75 ~ 617.0B X- 2703~0.64 E- 467~98.74 31 Y- ~970984,28 N- 780~B77,4g 7~9'20,479B' ~47°~1'44,0745' 25~0,9~ ~99.62 X~ 270342,8~ E- 467~9~,~0 1 32 Y- ~97081~.21 N- 7801826,06 700~9'1B.B231' ~47°5~'43.40~2' 2679.40 X- 270~60.~8 E- 467601.76 ~3 ~- ~70~8~,$~ ~- ~801877,8~ ~0~1~'20,~.~1· 1~°$1'~,~· 250~,$0 X- 270352.76 E- 467~98.53 ' 34 Y- 5970816.26 N- 7801826,43 70°19'18,~64' 147°~1'4~.1160' 2678.04 &67.26 X- 270370,53 E- 467604.79 35 Y- 5970986.37 N- 7801878.21 70°19'20.~063' 147°51;4~.~961' 2508,25 ~ &79.79 X~ 270362.70 E- 467601.5~ 36 Y- ~970817.31 N- 7801826.80 70°19'18.B496' 147°~1'42.B268' 267&,&9t,, X~ 270380.47 E- 467607.81 37 Y~ 5970987.42 N~ 7801878.58 70c19 ' 20. 5196' 147°51'43.2069' 2506,19 &69.18 X~ 270372.65 E~ 467604.58 38 Y' ~970818,3~ N" 7801827,1~ 70°19'18,8629' 147°51'42,~37&' ~ 2~75,34 &47,43 X' 270390.42 E' 467610.B4 39 Y' 5970988,46 N' 7B01878,95 70°~9'20,5329' 147°51'42.9170' 2S'~5.54 659,97~ Xm 270382,59 E- 467607,60 40 Y- 5970819,40 N- 7801827,53 70°~9'18.B762' 147°5~'42,2484' 2673,99 637,52 X- 270400.36 E- 4676~3,86 41 Y- 5970989,51 N- 7801879,32 70°~9'20,546~' 147°51'42.6286' 2504,19 6S0,05 X- 270392,54 Es 467610,62 4~ Ye 5970820,44 N- 7g01827,90 70~9'19,B894· 14~'5~'41,9592, 2672,64 627.6~ X~ 270410,3~ E- 467616.88 ~ ii ii SDI ~O~SED WELL L~ATION LIST ~~~- LOCATED IN SEC. I,.T. II N., RITE. UMIAT M. ~ ,' ~ PREPAREO FO~ '1,~**'~'~~~~ F.R BELL ~ ASSOC .~2~...~~ SHEET ~ of IO ' - SCALE' · ~ssl~~ PRUDHOE BAY OF~CE CHECKED · ~ ~ I __111 II I I iiiii ii I iii iiii i II I II III m.L ,... , "44 f- s970i21.49 N- 710~121.27 70~"19'tl.tOZ7· S47~51'41.&7~· X- 270420.2S E' 4676i9.91 45 Y- 597099Z.AO N- 7SOIBBO.OA 70~19'20.5727' ~47~5~/42.'~02' 2501'.49 .... ~ X, 270422.4~ ~ E- 467616.67 46 Y- 5970B~-2-~-'~'~-~N- 780~'-828.64 70:19'18.91~0~-~-i-4~Y'5-{"~-~-~-~9" T"'26&~.'9~ ..... 607.78' ' X- 2704~0.20 ' E- 467622.9~ ; ~ X- 270422.~8 [- 4676t9.70 4~ Y- ~7'0~3.~ ~- 7~0~880.7~ 70'°'~'"'20.~2" ~I~7o~i'~t.~Tti· 2~.')I ~0.~0 Z- 2704~2.32 E- 467&22.72 50 Y- ~970824,62 N- 7802829.37 70~9'1g.9425' ) 147~'40.i02~· 2667.'23 X- 2704~0.09 E- 467,28.t8 i SOl ~OPOS[O WILL LOCATION LIST ~--'~ ' ~'~ ~- LOCATED ,. '' ~'--' _~ SOHIO ALASKA PETROLEUM CO. ~I-~*"~-~ SHEET ~of Io F.R. BELL ~ A~OC. SCALE' N/A ~ESSi~~ PRUDHOE BAY OFFICE ~%%~~ ~ A W N a Y · R. ;. T, ;Ev. O PRUDHOE BAY~ ALASKA . ,, C,[CK[O ~Y' ENDICOTT DEVELOPMENT WELL 3-1 / N-29 {SDI), SLOT 3-1 SURFACE LOCATION X = 270,164 FT ; Y = 5,970,965 FT 2535 FT SNL; 878 FT WEL SEC8, T11N, R17E DEPARTURE TO TARGET: 6371 FT 12552 FT MD 10049 FT TVD BKB DEPARTURE TO BHL: 6857 FT 13247 FT M D 10546 FT TVD BKB TRUE NORTH GRID N 14~ 30' W NOTE: THE NEAREST WELL TO N-29 IS 0-29 LOCATED 20 FT EAST AT SLOT 3-5 IRR / 11-25-86 ENDICOTT MUD PROGRAM SATELLITE DRILLING ISLAND WELL 3-1/N-29 Interval Mud Weight Viscosity Fluid Loss LP_P_g). (sec/qt) (ml/30min) pH 0-2500 8.8-9.8 100-200 20-15 8.5-9.0 2,500- 12,128 Set 13-3/8" casing 9.2-10.2 40-45 15-16 Set 9-5/8" casing 9.6-10.2 40-45 Hang 7" Liner 12,128- 13,247 9.5-10.0 9.0-10.0 Mud Type/ Components Generic Mud #6 Seawater Durogel Gelite Soda Ash Caustic Soda Generic Mud #2 Seawater Gelite Maxpac VC-10 Caustic Soda Soda Ash Barite Generic Mud #2 Seawater Gelite Maxpac VC-10 Caustic Soda Soda Ash Barite POOL ARCTIC ALASKA RIG NO. 7 Mud Tank/Trip Tank Monitorin~)-Recordi~ TOTCO, PITOMETER UNIT L-8 (PNEUMATIC) DRILLING RECORDER SYSTEM TOTCO, MODEL DR8WPT (E) RS (2) F DRILLER'S CONSOLE TOTCO "COMMAND" POOL ARCTIC ALASKA RIG NO. 7 MUD AND SOLIDS CONTROL EQUIPMENT Equipment Manufacturer Model Nominal Capacity Shaker Brandt Dual Double 1000 gpm Desanders Tri Flow/Pioneer Mann-Design 2 each - TFI-126 screens 4 each - Pioneer 12" Economaster Cones 1000 gpm (each) Mudcleaners Brandt Double 8 each - 4" Cones 400 gpm (each) Centrifuge Oiltools ' Decanting, Type S-3-0 160 gpm Degasser SWACO Vacuum 1000 gpm Agitators Brandt 7 each - 5 h.p., 32" Impellers Hoppers Geosource 2 each - 1000 gpm S-800 Sidewinders The trip tank and mud tank sections each have one vertical pit level float indicator which are connected to the drilling recorder system that contains visual and audio warning devices located in the driller's console. _,.-:-cm. ISSUED i t I FOR INFORMATION ONLY THL~ IS A PRO- PRIETARY OESIGt OF P.AJL REPRODUCTION USE OF THIS DESIGN t$ PER- MI~BLE ONLY AUTHORIZED IN WRITING BY P.A.A f I t L_=.V~L ~ - .~T TOP I~HIS IS A PRIEIAR'f DESIGN OF RF.J~RODUCTIC)N OR U~ OF THIS DE~N ~ PER. M~E ONLY IF A~R~EO IN Vlllml, dO BY P.~.~. ISSUED M~ 1~1!~ FOR INFORA~TION ONLY TESTING THE'B.O.P. STAGK WITH THE 13-1/8" x 4½" IF BOX X BOX, (THRU-BORE) , TEST PLUG (FIG, 7) · 1.) Make up the 13-1/8" x 4½" IF test plug to a stand of drill pipe. (Illustration 9) NOTE: Sometimes it is helpful to make a stand of heavy wall up to the bottom of the test plug in order to help energize the compression packing. 2.) Lower the ~est plug through the B.O.P. stack until it lands on the lower load shoulder of the. split unihead unit. 3.) Run in at least two of the lower set of lockdown screws 180° opposed to hold the test plug in place. This is so the drill pipe can be backed out in order to test the blind rams. NOTE: All lockdown screws can be run in if need to energize the compression packing on the test plug. 4.) Test the B.O.P. stack. 5.) Back out all lockdown screws which have been run in. 6.) Remove the test plug. 13-1/8" X 4-1/2" IF BOX X BOX (THRU-BORE) TEST PLUG THiS END UP .7.. L FMC PoN. 48-261-082 REQ'D PART NO. DESCRIPTION 1 48-261-268 Test Plug 1 48-261-083 Body 1 48-261-673 Compression Ring 4 79-040-074 Set Screws 1 48-081-529 Packing 1 51-092-001 2" Ball Check Figure #7 (Part number 48-261-082 continued on next page) FMC ?.N. 48-261-082 continued REQ' D. pART NO'. D~scRIPTION 1 19-505-663 Coil Spring 1 25-411-356 Retaining Plate ,, 1 25-411-357 Circ.-O-Lox Ring 2 48-180-027 Pipe Plug 1 52-304-013 Drlg. Pipe Sub. ILLUSTRATION 9 B.O.P. STACK 3-5/8" 5000 WP "3000 WP TESTING THE~B.O.P. STACK WITH THE 13%" X 4%" IF BOX X BOX, (UPPER) , TEST PLUG (FIG. 19) 1.) Make up the 13%" x 4%" IF test plug (upper) to a stand of drill pipe. (Illustration 13) NOTE: Sometimes it is helpful to make a stand of heavy wall 6p to the bottom of the test plug in order to help energize the compression packing. 2.) Lower the test plug through the B.O.P. stack until it lands on the upper load shoulder of the split unihead unit. , 3.) Run in at least two of the upper set of lockdown screws 180° opposed to hold the test plug in place. This is so the drill pipe can be backed out in order to test the blind rams. NOTE: All lockdown screws can be run in if you need to · energize the compression packing on the test plug. 4 ) Test the B.O.P. stack· 5.) Back out all 10ckdown screws which have been run in. 6.) Remove the test plug. 13-1/2" X 4-1/~2" IF BOX X BOX (UPPER) TEST PLUG FMC P.N. 48-261-068 REQ'D PART NO. DESCRIPTION . 1 48-261-067 Body 1 48-261-671 Compression Ring 4 79-040-074 Set Screw 1 82-741-117 Packing 1 51-092-001 2" Ball Check 1 i9-505-663 Coil Spring 1 25-411-356 Retaining Plate , ,, 1 25-411-357 Circ.-O-Lox Ring 2 48-180-027 Pipe Plug END UP Figure #19 ILLUSTRATION# 13 B.o.p. sTACK 5/8" 5000 WP 13-5/8" 3000 WP TESTING THE B.O.P. STACR WITH THE 10" X 4-1/2" IF BOX X BOX (COMBINATION) , TEST PLUG (FIG. 22A) · 1.) Make up the 10" x 4%" IF test plug (combination) to a stand of drill pipe. 2.). Lower the test plug through the B.O.P. stack until it lands on the-upper load shoulder of the tubing/casing head. 3.) Rin in at least two of the upper set of lockdown screws 180" opposed to hold the test plug in place. This is so the drill Pipe can ~e backed out in order to test the blind rams. 4.) Test the B.O.P. stack. 5.) Back out all the lockdown scres which have been run in. 6.) Remove the test plug. 10" CO-~4BINATION TEST PLUG AND BOWL PROTECTOR RUNNING/RETRIEVING TOOL · THIS END UP FMC PART NO o 48-261-503 REQ,D~- - ~kRT NO. DESCRIPTION 1 48-261-504 BODY 1 48-085-833 BELT PACKING 1 48-180-025 PLUG, 1¼ L.P. _ 1 48-180-025 PLUG, 1¼ L'P. , 4 48-180-015 PLUG, ½ L.P. 1 48-010-009 WRENCH · (Figure #22A) ~ B.O.P. STACK ..... ..... 1" 5000 WP I- 13-5/8" 3000 STACK ............. 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'" '~"'" :":e:" '" :~ ' ' ' ~:... '.. .'.,:.:,?'.::~o~-~ t' 6~4.oo' ?:;~~=..' ~?..:':?'~:?:'.?.,::":~:.'..='.'. :.' .. ' '"":'"" Ci:'Ose'''s P'p'~.o~ch 'st:a " ' il~?~ ~ " " ........ :" '':"'" '"""' ~.:.. ..' t' a' ":.".di n,C...,e.. := ' ": .~"."':"~'"'.::"'~'""~'"<":""~":":::;:~:?':'~': .......... :.: ...... ~ " '~ ': .. "':' ..." " ' '" " ' '" ' I'~ '~' ' ' '~'~' "" '"'""' ~':~'''':''':''''': ..... ' " ' ' ' .. i~',;;:.,::.:i:? .' ..:. . · "'.' .. · '.""'. · · .','..:".' · ". .... · ...... , . · · ............:.......... ... :. · . ;~· ~<~~:..,~i;~ .': .... · ...... '"' '" '"'"'"' ' ' ' ""' .... ' ' ' ' ' ' '; ' ' " ' ' ' "' ' = '" ":' ' ' "' " '" ":" ' C . 'i~I'CK '.:OFF ~ t'h. is. T'Un'. · ""-- 2'600. 0 ~'eet .... "' ...... ' ..... .....'. ...,' .... '..'. .. .' .' ~'""' '"' ' ' ' ,! .... . ' i" ;' ...~ ,~:. ~,, ~.~.':, , ,'.. '..' ;. ...,.. ........ ........... ~x .. ......... ..~ ........... ,:', ............ (,':.....,~ ........ . ........... t,.? ...................... ,-~ ............. ~.....' ....................... .... ..,......,,,,.-.~' ........ · ,,......;'.......,..~.. . .......... ,.'....-,'...: .............. :...C '~, ,.~..r .2,,_: ........ · ." ' '.. "....: .' ..... ' ..... :... ' ' ..:: .... ' ' . ... . .' '. '. ...... '. ' ' · . ·. ' .....' ....... ' .. L. · .... . ........ ' · ..' ' ' "'.. · .....' .... : .: " ..... ", ..... ... ............. ', :' . .... ' . ' ...... ' .' .....' ' . . ¢2> LO= (3) Admin (4) Casg (8) ' (9 thru (10 ana t ru 22) (5) BOPE ~f~ / (23 thru/289 (6) OTHER (2~~ 31) Geology: WVA~ ncs rev: 07/18/86 6.011 0 3. 4. 5. 6. 7. 8. ® 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. For 29. 30. 31. 32. Cou~any ':':: ..3 /~"/' - - :.':'~ ,. YES the permit fee Is Is ~11 to be lo,ted ~ a defied ~ol ............................. Is well lo~ted p~per dis~ce fr~ proper~ l~e .................. Is ~11 lo~ted pro~r dist~ce fr~ other ~lls , ...... Is s~fici~t ~~ted acr~ge available ~ this Is ~11 to be ~ated ~d is ~ll~re plat inclu~d ................ Is operator ~e only affected party ....... ~ .......................... ~ pe~t be approved before fifteen-~y ~it ...................... ~s operator ~e a b~d ~ force .................................. Is a conse~ation order nee~d ....................... ............... Is a~is~ati~ appr~al nee~d ................................... Is the lease n~er appropriate ..................................... ~es t~ ~11 ~ve a ~~e ~ ~d n~er ......................... ~e & Well' No. NO , Is conductor string provided ........................................ fzff Will surface casing protect fresh water zones ....................... #zrH Is enough cement used to circulate on conductor and surface . ~2"// Will cenmnt tie in surface and intermediate or production strings ... .~H Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbere ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ..... ................................. Is the drilling fluid program schematic and list of equipmmnt adequate~ Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to Does the choke manifold comply w/API RP-53 ~,i~y 84)..J ............... ., Is the presence of H2S gas probable ................................. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented__ Additional requirenents ............................................. POOL INITIAL CLASS STA2~dS ON/OFF SHORE Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special'effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * * . ****************************** * ............................ * * ....... SCHLUMBERGER ....... * * ............................ * ****************************** RECEIVED APR 0 4 Alaska Oii& Gas Cons. Anchorage COMPANY NAME : BP EXPLORATION (ALASKA) WELL NAME : 3-O1/N-29SDI FIELD NAME : ENDICOTT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-21678-00 REFERENCE NO : 97148 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-APR-1997 23:58 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 97/04/ 3 ORIGIN : FLIC REEL NAME : 97148 CONTINUATION # : PREVIOUS REEL : COMMENT : BP EXPLORATION (ALASKA), 3-01/N-29 SDI, ENDICOTT, 50-029-21678-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 97/04/ 3 ORIGIN : FLIC TAPE NAME : 97148 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : BP EXPLORATION (ALASKA), 3-01/N-29 SDI, ENDICOTT, 50-029-21678-00 TAPE HEADER ENDICOTT CASED HOLE WIRELINE LOGS WELL NAME: 3 - O1/N-29SDI API NUMBER: 501032167800 OPERATOR: BP EXPLORATION (ALASKA) LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 3-APR- 97 JOB NUMBER: 97148 LOGGING ENGINEER: PALMER OPERATOR WITNESS: CLUMP SURFACE LOCATION SECTION: 8 TOWNSHIP: 1 IN RANGE: 17E FNL: 2535 FSL: FEL: 878 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 55.30 DERRICK FLOOR: 54.30 GROUND LEVEL: 14.50 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) iST STRING 8. 500 7. 000 13050.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-APR-1997 23:58 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: TDTP LDWG CURVE CODE: GR RUN NUMBER: 1 PASS NUMBER: 1 DATE LOGGED: 28-FEB-91 LOGGING COMPANY: SCHLUMBERGER WELL SERVICES .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH 88888.0 88886.5 12388.0 12386.5 12371.0 12369.5 12358.0 12356.5 12343.5 12343.5 12330.5 12329.5 12328.0 12326.5 12324.5 12324.0 12321.5 12322.0 12312.5 12311.0 12302.5 12301.0 12293.0 12291.5 12277.0 12276.0 12271.5 12270.5 12263.5 12262.0 12259.5 12259.0 12211.5 12211.5 12191.5 12190.0 12180.0 12179.0 12158.0 12157.5 12127.0 12128.0 12103.0 12105.0 100.0 102.0 $ REMARKS: This file contains the LDWG edit for BP Exploration well 3-01/N-29 SDI TDTP. This tape contains 3 edited passes, an average pass and 3 raw data passes. The depth adjustments shown above reflect cased hole GR to open hole BCS GR. All other TDTP curves were carried with the GR shifts. Well was logged 25-March-1997. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/04/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-APR-1997 23:58 PAGE: FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: O . 5000 FILE SU~ff~AR Y LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 12437.0 12074.0 TDTP 12450.0 12074.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: NONE PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH TDTP TDTP REMARKS: This file contains TDTP Pass #1 (Base Pass #1). pass to pass shifts were applied to this data. $ LIS FORMAT DATA No ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-APR-1997 23:58 PAGE: ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE .CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 553840 O0 000 O0 0 1 1 1 4 68 0000000000 SIGM TDTP CU 553840 O0 000 O0 0 1 1 1 4 68 0000000000 TPHI TDTP PU-S 553840 O0 000 O0 0 1 1 1 4 68 0000000000 SBHF TDTP CU 553840 O0 000 O0 0 1 1 1 4 68 0000000000 SBHNTDTP CU 553840 O0 000 O0 0 1 1 1 4 68 0000000000 SIGC TDTP CU 553840 O0 000 O0 0 1 1 1 4 68 0000000000 SIBH TDTP CU 553840 O0 000 O0 0 1 1 1 4 68 0000000000 TRAT TDTP 553840 O0 000 O0 0 1 1 1 4 68 0000000000 SDSI TDTP CU 553840 O0 000 O0 0 1 1 1 4 68 0000000000 BACK TDTP CPS 553840 O0 000 O0 0 1 1 1 4 68 0000000000 FBAC TDTP CPS 553840 O0 000 O0 0 1 1 1 4 68 0000000000 TCANTDTP CPS 553840 O0 000 O0 0 1 1 1 4 68 0000000000 TCAF TDTP CPS 553840 O0 000 O0 0 1 1 1 4 68 0000000000 TCND TDTP CPS 553840 O0 000 O0 0 1 1 1 4 68 0000000000 TCFD TDTP CPS 553840 O0 000 O0 0 1 1 1 4 68 0000000000 TSCN TDTP CPS 553840 O0 000 O0 0 1 1 1 4 68 0000000000 TSCF TDTP CPS 553840 O0 000 O0 0 1 1 1 4 68 0000000000 INND TDTP CPS 553840 O0 000 O0 0 1 1 1 4 68 0000000000 INFD TDTP CPS 553840 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH TDTP GAPI 553840 O0 000 O0 0 1 1 1 4 68 0000000000 TENS TDTP LB 553840 O0 000 O0 0 1 1 1 4 68 0000000000 CCL TDTP V 553840 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 12435.500 SIGM. TDTP 10. 044 TPHI. TDTP 19. 727 SBHF. TDTP SBHN. TDTP 45.177 SIGC. TDTP O. 685 SIBH. TDTP 47. 602 TRAT. TDTP SDSI . TDTP O . 149 BACK. TDTP 118.184 FBAC. TDTP 38. 691 TCAN. TDTP TCAF. TDTP 45779. 156 TCND. TDTP 28228. 383 TCFD. TDTP 10360. 846 TSCN. TDTP TSCF. TDTP 4833.208 INND. TDTP 2026. 247 INFD. TDTP 358. 419 GRCH. TDTP TENS. TDTP 1259. 000 CCL. TDTP O. 000 DEPT. 12076. 000 SIGM. TDTP 41. 611 TPHI. TDTP 64. 045 SBHF. TDTP SBHN. TDTP 52.119 SIGC. TDTP O. 000 SIBH. TDTP 64 . 423 TRAT. TDTP SDSI. TDTP 1.588 BACK. TDTP 110. 705 FBAC. TDTP 26.237 TCAN. TDTP TCAF. TDTP 7612. 980 TCND. TDTP 13495. 449 TCFD. TDTP 3349. 976 TSCN. TDTP TSCF. TDTP 407. 011 INND. TDTP 1662. 853 INFD. TDTP 280.392 GRCH. TDTP TENS. TDTP 1487. 000 CCL. TDTP O . 000 33. 576 1 . 702 96065. 453 10142.264 61. 394 45.287 1. 812 27762. 945 1458. 772 71. 819 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-APR-1997 23:58 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE · FLIC VERSION : O01CO1 DATE : 97/04/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/04/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE i~JMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: O . 5000 FILE SUBmlARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 12431.0 12068.0 TDTP 12445.0 12068.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH TDTP 88888.0 88887.0 88886.5 12387.5 12386.5 12386.5 12385.0 12370.5 12369.5 12357.5 12356.0 12355.5 12355.0 12324.5 12324.0 12304.0 12302.5 12296.5 12295.5 12290.5 12289.0 12271.5 12270.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-APR-1997 23:58 PAGE: 12263 12263 12259 12255 12247 12212 12206. 12192 12188 12158 12158 12149 12133 12127 12105 12101 12081 100 $ 5 12262.0 0 12262.0 5 12259.0 5 12255.5 0 12246.5 0 12211.5 5 12206.0 0 12190.5 5 12187.5 5 12158.0 0 12157.5 0 12149.0 5 12133.0 0 12128.0 0 12104.5 0 12103.0 0 12083.5 0 102.5 99.5 REMARKS: This file contains TDTP Pass #2 (Base Pass #2). The depth shifts shown above relect GRCH Pass #2 to GRCH Pass #1 and SIGM Pass #2 to SIGM Pass #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-APR-1997 23:58 PAGE: ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 553840 O0 000 O0 0 2 1 1 4 68 0000000000 SIGM TDTP CU 553840 O0 000 O0 0 2 1 1 4 68 0000000000 TPHI TDTP PU-S 553840 O0 000 O0 0 2 1 1 4 68 0000000000 SBHF TDTP CU 553840 O0 000 O0 0 2 1 1 4 68 0000000000 SBHN TDTP CU 553840 O0 000 O0 0 2 1 1 4 68 0000000000 SIGC TDTP CU 553840 O0 000 O0 0 2 1 1 4 68 0000000000 SIBH TDTP CU 553840 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT TDTP 553840 O0 000 O0 0 2 1 1 4 68 0000000000 SDSI TDTP CU 553840 O0 000 O0 0 2 1 1 4 68 0000000000 BACK TDTP CPS 553840 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC TDTP CPS 553840 O0 000 O0 0 2 1 1 4 68 0000000000 TCANTDTP CPS 553840 O0 000 O0 0 2 1 1 4 68 0000000000 TCAF TDTP CPS 553840 O0 000 O0 0 2 1 1 4 68 0000000000 TCND TDTP CPS 553840 O0 000 O0 0 2 1 1 4 68 0000000000 TCFD TDTP CPS 553840 O0 000 O0 0 2 1 1 4 68 0000000000 TSCN TDTP CPS 553840 O0 000 O0 0 2 1 1 4 68 0000000000 TSCF TDTP CPS 553840 O0 000 O0 0 2 1 1 4 68 0000000000 INND TDTP CPS 553840 O0 000 O0 0 2 1 1 4 68 0000000000 INFD TDTP CPS 553840 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH TDTP GAPI 553840 O0 000 O0 0 2 1 1 4 68 0000000000 TENS TDTP LB 553840 O0 000 O0 0 2 1 1 4 68 0000000000 CCL TDTP V 553840 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 12443. 500 SIGM. TDTP 10. 903 TPHI. TDTP 16. 578 SBHF. TDTP 21. 095 SBHN. TDTP 38. 040 SIGC. TDTP O. 819 SIBH. TDTP 38. 040 TRAT. TDTP 1 . 594 SDSI.TDTP 0.234 BACK. TDTP 181.563 FBAC. TDTP 61.746 TCAN. TDTP 103328.172 TCAF. TDTP 52503.211 TCND. TDTP 29739.332 TCFD. TDTP 10841.291 TSCN. TDTP 10202. 408 TSCF. TDTP 5184. 058 INND. TDTP 2632. 961 INFD. TDTP 305. 751 GRCH. TDTP -999. 250 TENS. TDTP 1258. 000 CCL. TDTP O. 000 DEPT. 12067. 500 SIGM. TDTP 45. 663 TPHI. TDTP 76. 654 SBHF. TDTP 59. 293 SBHN. TDTP 61.249 SIGC. TDTP O. 000 SIBH. TDTP 85. 135 TRAT. TDTP 1 . 876 SDSI. TDTP O. 932 BACK. TDTP 134. 032 FBAC. TDTP 28. 440 TCAN. TDTP 37120. 055 TCAF. TDTP 8992. 418 TCND. TDTP 12003.277 TCFD. TDTP 2853. 158 TSCN. TDTP 1011. 658 TSCF. TDTP 244. 849 INND. TDTP 1661. 485 INFD. TDTP 259. 307 GRCH. TDTP - 999. 250 TENS. TDTP 1518. 000 CCL. TDTP O. 000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-APR-1997 23:58 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION · 001 CO1 DATE : 97/04/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE ' 97/04/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE iV-UMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: O. 5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 12479.0 12076.0 TDTP 12485.0 12076.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 12432.5 12394.5 12388.5 12387.5 12371.5 12358.5 12358.0 12345.5 12333.5 12324.5 .......... EQUIVALENT UNSHIFTED DEPTH GRCH TDTP 88886.0 88885.5 12430.5 12392.0 12386.5 12385.0 12369.5 12356.5 12356.0 12345.0 12332.0 12324.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-APR-1997 23:58 PAGE: 12311. 12304. 12297. 12293 12264 12260 12260 12244 12212 12207 12198 12192 12159 12158. 12132. 12114. 12102. 12099. 12090. 100. $ 0 12309.0 5 12302.5 0 12295.0 5 12291.5 0 12262.0 12262.0 5 12259.0 0 12259.0 5 12244.0 5 12211.5 0 12206.0 0 12196.5 5 12190.5 0 12158.0 5 12157.5 5 12133.0 5 12115.0 5 12104.5 0 12100.5 5 12093.0 0 102.5 100.5 REMARKS: This file contains TDTP Pass #3 (Base Pass #3). The depth shifts shown above relect GRCH Pass #3 to GRCH Pass #1 and SIGM Pass #3 to SIGM Pass #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-APR-1997 23:58 PAGE: 10 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 553840 SIGM TDTP CU 553840 TPHI TDTP PU-S 553840 SBHF TDTP CU 553840 SBHN TDTP CU 553840 SIGC TDTP CU 553840 SIBH TDTP CU 553840 TRAT TDTP 553840 SDSI TDTP CU 553840 BACK TDTP CPS 553840 FBAC TDTP CPS 553840 TCAN TDTP CPS 553840 TCAF TDTP CPS 553840 TCND TDTP CPS 553840 TCFD TDTP CPS 553840 TSCN TDTP CPS 553840 TSCF TDTP CPS 553840 INND TDTP CPS 553840 INFD TDTP CPS 553840 GRCH TDTP GAPI 553840 TENS TDTP LB 553840 CCL TDTP V 553840 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 12482. 500 SIGM. TDTP 10. 644 TPHI. TDTP 19. 302 SBHF. TDTP 34. 425 SBHN. TDTP 42. 296 SIGC. TDTP O. 506 SIBH. TDTP 42. 296 TRAT. TDTP 1 . 695 SDSI. TDTP O. 487 BACK. TDTP 194.557 FBAC. TDTP 49. 824 TCAN. TDTP 13158.211 TCAF. TDTP 6300.519 TCND. TDTP 26822. 527 TCFD. TDTP 9851 . 107 TSCN. TDTP 9562. 367 TSCF. TDTP 4578. 729 INND. TDTP 2089. 874 INFD. TDTP 376. 052 GRCH. TDTP - 999. 250 TENS. TDTP 1236. 000 CCL. TDTP O. 000 DEPT. 12076. 500 SIGM. TDTP 44. 696 TPHI. TDTP 64 . 575 SBHF. TDTP SBHN. TDTP 62. 730 SIGC. TDTP O. 508 SIBH. TDTP 88. 494 TRAT. TDTP SDSI. TDTP O. 931 BACK. TDTP 153. 800 FBAC. TDTP 35. 822 TCAN. TDTP TCAF. TDTP 9225. 773 TCND. TDTP 11793. 908 TCFD. TDTP 2771 . 937 TSCN. TDTP TSCF. TDTP 254. 598 INND. TDTP 1726. 032 INFD. TDTP 249. 878 GRCH. TDTP TENS. TDTP 1539. 000 CCL. TDTP O. 000 53.486 1.642 35406.914 934.843 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-APR-1997 23:58 PAGE: 11 **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/04/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/04/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~BER: 4 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT O. 5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS 1, 2, 3, TDTP $ REMARKS: The arithmetic average of passes 1, 2 & 3 was computed after all depth shifts and clipping was applied. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 80 4 66 1 5 66 6 73 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-APR-1997 23:58 PAGE: 12 TYPE REPR CODE VALUE 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 553840 O0 SIGM PNAV CU 553840 O0 TPHI PNAV PU-S 553840 O0 SBHF PNAV CU 553840 O0 SBHNPNAV CU 553840 O0 SIGC PNAV CU 553840 O0 SIBH PNAV CU 553840 O0 TRAT PNAV 553840 O0 SDSI PNAV CU 553840 O0 BACK TDTP CPS 553840 O0 FBAC TDTP CPS 553840 O0 TCANPNAV CPS 553840 O0 TCAF PNAV CPS 553840 O0 TCND PNAV CPS 553840 O0 TCFD PNAV CPS 553840 O0 TSCN PNAV CPS 553840 O0 TSCF PNAV CPS 553840 O0 INND PNAV CPS 553840 O0 INFD PNAV CPS 553840 O0 GRCH TDTP GAPI 553840 O0 000 O0 0 4 1 1 4 68 0000000000 000 O0 0 4 1 1 4 68 0000000000 000 O0 0 4 1 1 4 68 0000000000 000 O0 0 4 1 1 4 68 0000000000 000 O0 0 4 1 1 4 68 0000000000 000 O0 0 4 1 1 4 68 0000000000 000 O0 0 4 1 1 4 68 0000000000 000 O0 0 4 1 1 4 68 0000000000 000 O0 0 4 1 1 4 68 0000000000 000 O0 0 4 1 1 4 68 0000000000 000 O0 0 4 1 1 4 68 0000000000 000 O0 0 4 1 1 4 68 0000000000 000 O0 0 4 1 1 4 68 0000000000 000 O0 0 4 1 1 4 68 0000000000 000 O0 0 4 1 1 4 68 0000000000 000 O0 0 4 1 1 4 68 0000000000 000 O0 0 4 1 1 4 68 0000000000 000 O0 0 4 1 1 4 68 0000000000 000 O0 0 4 1 1 4 68 0000000000 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 12435.500 SIGM. PNAV 10.131 TPHI.PNAV 20.170 SBHF. PNAV 33.825 SBHN. PNAV 43.699 SIGC. PNAV 0.627 SIBH. PNAV 44.910 TRAT. PNAV 1. 728 SDSI. PNAV 0.259 BACK. TDTP 118.184 FBAC. TDTP 38.691 TCAN. PNAV 70386.500 TCAF. PNAV 33300.195 TCND.PNAV 27602.863 TCFD.PNAV 10038. 426 TSCN. PNAV 9959.129 TSCF. PNAV 4660.849 INND.PNAV 1925.703 INFD.PNAV 355.582 GRCH. TDTP 61.394 DEPT. 12076.000 SIGM. PNAV -999.250 TPHI.PNAV -999.250 SBHF. PNAV -999.250 SBHN. PNAV -999.250 SIGC. PNAV -999.250 SIBH. PNAV -999.250 TRAT. PNAV -999.250 SDSI.PNAV -999.250 BACK. TDTP 110.705 FBAC. TDTP 26.237 TCAN. PNAV -999.250 TCAF. PNAV -999.250 TCND.PNAV -999.250 TCFD.PNAV -999.250 TSCN. PNAV -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-APR-1997 23:58 PAGE: 13 TSCF. PNAV -999.250 INND.PNAV -999.250 INFD. PNAV -999.250 GRCH. TDTP 71.819 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/04/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/04/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: O . 5000 FILE SU~FiARY VENDOR TOOL CODE START DEPTH STOP DEPTH 12459.0 12072.0 TDTP $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO) TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 25-MAR-97 8C0-609 1511 25-MAR-97 12960.0 0.0 12100.0 12941.0 900.0 NO TOOL NUMBER LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-APR-1997 23:58 PAGE: 14 TDTP TDTP TDTP TDTP TDTP TDTP TDTP $ COLLAR LOG GA~A RAY THERMAL DECAY TDTP CARTRIDGE THERMAL DECAY TDTP SONDE GENERATOR TDTP SONDE DETECTOR BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : CAL-U ATT-B TDT- P TNC- P TNH-MA TNG- PB TND-P 8.500 13050.0 8.40 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 13000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): 1.0 REMARKS: THIS FILE CONTAINS THE RAW DATA FOR PASS 1. ************ RUN 1 ************* DEPTH CORRELATED WITH TDT RAN 28-FEB-91 WELL SHUT IN WITH 1100 PSI WHP TOOL WOULD NOT PASS BELOW 12430 INTERVAL LOGGED 12430-12100 $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-APR-1997 23:58 PAGE: 15 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 553840 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM PS1 CU 553840 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI PS1 PU 553840 O0 000 O0 0 $ 1 1 4 68 0000000000 SBHF PS1 CU 553840 O0 000 O0 0 5 1 1 4 68 0000000000 SBHNPS1 CU 553840 O0 000 O0 0 5 1 1 4 68 0000000000 SIGC PSI CU 553840 O0 000 O0 0 5 1 1 4 68 0000000000 SIBH PS1 CU 553840 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT PS1 553840 O0 000 O0 0 5 1 1 4 68 0000000000 SDSI PS1 CU 553840 O0 000 O0 0 5 1 1 4 68 0000000000 BACK PS1 CPS 553840 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC PS1 CPS 553840 O0 000 O0 0 5 1 1 4 68 0000000000 TCANPS1 CPS 553840 O0 000 O0 0 5 1 1 4 68 0000000000 TCAF PS1 CPS 553840 O0 000 O0 0 5 1 1 4 68 0000000000 TCND PS1 CPS 553840 O0 000 O0 0 5 1 1 4 68 0000000000 TCFD PSI CPS 553840 O0 000 O0 0 5 1 1 4 68 0000000000 TSCN PSi CPS 553840 O0 000 O0 0 5 i 1 4 68 0000000000 TSCF PS1 CPS 553840 O0 000 O0 0 5 1 1 4 68 0000000000 INND PS1 CPS 553840 O0 000 O0 0 5 1 1 4 68 0000000000 INFD PS1 CPS 553840 O0 000 O0 0 5 1 1 4 68 0000000000 TENS PS1 LB 553840 O0 000 O0 0 5 1 1 4 68 0000000000 GR PS1 GAPI 553840 O0 000 O0 0 5 1 1 4 68 0000000000 CCL PS1 V 553840 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-APR-1997 23:58 PAGE: 16 ** DATA ** DEPT. 12459.000 SIGM. PS1 SBHN. PS1 -999.250 SIGC. PS1 SDSI. PS1 -999.250 BACK. PSi TCAF. PS1 -999.250 TCND.PS1 TSCF. PS1 -999.250 INND.PS1 GR.PS1 105.498 CCL.PS1 DEPT. 12072.500 SIGM. PS1 SBHN. PS1 52.119 SIGC.PS1 SDSI.PS1 1.588 BACK. PSi TCAF. PS1 7612.980 TCND.PS1 TSCF. PS1 407.011 INND. PS1 GR.PS1 71.819 CCL. PS1 -999.250 TPHI.PS1 -999.250 SIBH. PS1 -999.250 FBAC. PS1 -999.250 TCFD.PS1 -999.250 INFD. PS1 0.000 41.611 TPHI.PS1 0.000 SIBH. PS1 110.705 FBAC.PS1 13495.449 TCFD.PS1 1662.853 INFD.PS1 -999.250 -999.250 SBHF. PS1 -999.250 TRAT. PS1 -999.250 TCAN. PS1 -999.250 TSCN. PS1 -999.250 TENS.PSI 64.045 SBHF. PS1 64.423 TRAT. PS1 26.237 TCAN. PS1 3349.976 TSCN. PS1 280.392 TENS. PSi -999.250 -999.250 -999.250 -999.250 716.000 45.287 1.812 27762.945 1458.772 1487.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/04/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/04/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: O. 5000 FILE S~Y VENDOR TOOL CODE START DEPTH STOP DEPTH TDTP 12451.0 12030.0 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-APR-1997 23:58 PAGE: 17 LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TDTP TDTP TDTP TDTP TDTP TDTP TDTP $ COLLAR LOG GAi~4A RAY THERMAL DECAY TDTP CARTRIDGE THERMAL DECAY TDTP SONDE GENERATOR TDTP SONDE DETECTOR BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MA TRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): 25-MAR-97 8C0-609 1511 25-MAR-97 12960.0 0.0 12100.0 12941.0 900.0 NO TOOL NUMBER ATT-B TDT- P TNC- P TNH-MA TNG- PB TND-P 8.500 13050.0 8.40 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 13000 NEAR COUNT RATE LOW SCALE (CPS): 0 THERMAL SANDSTONE 2.65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-APR-1997 23:58 PAGE: 18 NEAR COUNT R~TE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): 1.0 REMARKS: THIS FILE CONTAINS THE RAW DATA FOR PASS 2. ************ RUN 1 DEPTH CORRELATED WITH TDT RAN 28-FEB-91 WELL SHUT IN WITH 1100 PSI WHP TOOL WOULD NOT PASS BELOW 12430 INTERVAL LOGGED 12430-12100 $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 553840 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM PS2 CU 553840 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI PS2 PU 553840 O0 000 O0 0 6 1 1 4 68 0000000000 SBHF PS2 CU 553840 O0 000 O0 0 6 1 1 4 68 0000000000 SBHNPS2 CU 553840 O0 000 O0 0 6 1 1 4 68 0000000000 SIGC PS2 CU 553840 O0 000 O0 0 6 1 1 4 68 0000000000 SIBH PS2 CU 553840 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT PS2 553840 O0 000 O0 0 6 1 1 4 68 0000000000 SDSI PS2 CU 553840 O0 000 O0 0 6 1 1 4 68 0000000000 BACK PS2 CPS 553840 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-APR-1997 23:58 PAGE: 19 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUmB SAMP ELEM CODE (HEX) FBAC PS2 CPS 553840 TCANPS2 CPS 553840 TCAF PS2 CPS 553840 TCND PS2 CPS 553840 TCFD PS2 CPS 553840 TSCN PS2 CPS 553840 O0 TSCF PS2 CPS 553840 O0 INND PS2 CPS 553840 O0 INFD PS2 CPS 553840 O0 TENS PS2 LB 553840 O0 GR PS2 GAPI 553840 O0 CCL PS2 V 553840 O0 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 000 O0 0 6 1 1 4 68 0000000000 000 O0 0 6 1 1 4 68 0000000000 000 O0 0 6 1 1 4 68 0000000000 000 O0 0 6 1 1 4 68 0000000000 000 O0 0 6 1 1 4 68 0000000000 000 O0 0 6 1 1 4 68 0000000000 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 12451.000 SIGM. PS2 -999.250 TPHI.PS2 -999.250 SBHF. PS2 SBHN. PS2 -999.250 SIGC. PS2 -999.250 SIBH. PS2 -999.250 TRAT. PS2 SDSI.PS2 -999.250 BACK. PS2 -999.250 FBAC. PS2 -999.250 TCAN. PS2 TCAF.PS2 -999.250 TCND. PS2 -999.250 TCFD. PS2 -999.250 TSCN. PS2 TSCF. PS2 -999.250 INND.PS2 -999.250 INFD. PS2 -999.250 TENS.PS2 GR.PS2 105.498 CCL.PS2 0.000 DEPT. 12030.000 SIGM. PS2 45.690 TPHI.PS2 75.380 SBHF. PS2 SBHN. PS2 61.143 SIGC. PS2 0.000 SIBH. PS2 84.895 TRAT. PS2 SDSI.PS2 0.935 BACK. PS2 132.312 FBAC. PS2 26.966 TCAN. PS2 TCAF. PS2 9449.412 TCND.PS2 12027.729 TCFD. PS2 2878.588 TSCN. PS2 TSCF. PS2 253.677 INND.PS2 1661.586 INFD.PS2 253.839 TENS.PS2 GR.PS2 86.364 CCL.PS2 -999.250 -999.250 -999.250 -999.250 -999.250 692.000 58. 357 1. 851 38337. 656 1028. 495 1518. 000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/04/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-APR-1997 23:58 PAGE: 2O **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 97/04/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: O . 5000 FILE SUFk/La2~Y VENDOR TOOL CODE START DEPTH STOP DEPTH 12500 . 5 12049.0 TDTP $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TDTP TDTP TDTP TDTP TDTP TDTP TDTP $ COLLAR LOG GAMMA RAY THERMAL DECAY TDTP CARTRIDGE THERMAL DECAY TDTP SONDE GENERATOR TDTP SONDE DETECTOR BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: 25-MAR-97 8C0-609 1511 25-MAR-97 12960.0 0.0 12100.0 12941.0 900.0 NO TOOL NUMBER ATT-B TDT- P TNC- P TNH-MA TNG- PB TND-P 8.500 13050.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-APR-1997 23:58 PAGE: 21 FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : 8.40 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 13000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): 1.0 REMARKS: THIS FILE CONTAINS THE RAW DATA FOR PASS 3. ************ RUN 1 ************* DEPTH CORRELATED WITH TDT RAN 28-FEB-9! WELL SHUT IN WITH 1100 PSI WHP TOOL WOULD NOT PASS BELOW 12430 INTERVAL LOGGED 12430-12100 $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-APR-1997 23:58 PAGE: 22 TYPE REPR CODE VALUE 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 553840 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM PS3 CU 553840 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI PS3 PU 553840 O0 000 O0 0 7 1 1 4 68 0000000000 SBHF PS3 CU 553840 O0 000 O0 0 7 1 1 4 68 0000000000 SBHN PS3 CU 553840 O0 000 O0 0 7 1 1 4 68 0000000000 SIGC PS3 CU 553840 O0 000 O0 0 7 1 1 4 68 0000000000 SIBH PS3 CU 553840 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT PS3 553840 O0 000 O0 0 7 1 1 4 68 0000000000 SDSI PS3 CU 553840 O0 000 O0 0 7 1 1 4 68 0000000000 BACK PS3 CPS 553840 O0 000 O0 0 7 1 1 4 68 0000000000 FBAC PS3 CPS 553840 O0 000 O0 0 7 1 1 4 68 0000000000 TCANPS3 CPS 553840 O0 000 O0 0 7 1 1 4 68 0000000000 TCAF PS3 CPS 553840 O0 000 O0 0 7 1 1 4 68 0000000000 TCNDPS3 CPS 553840 O0 000 O0 0 7 1 1 4 68 0000000000 TCFD PS3 CPS 553840 O0 000 O0 0 7 1 1 4 68 0000000000 TSCN PS3 CPS 553840 O0 000 O0 0 7 1 1 4 68 0000000000 TSCF PS3 CPS 553840 O0 000 O0 0 7 1 1 4 68 0000000000 INNDPS3 CPS 553840 O0 000 O0 0 7 1 1 4 68 0000000000 INFD PS3 CPS 553840 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS3 LB 553840 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS3 GAPI 553840 O0 000 O0 0 7 1 1 4 68 0000000000 CCL PS3 V 553840 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 12500.500 SIGM. PS3 -999.250 TPHI. PS3 -999.250 SBHF. PS3 SBHN. PS3 -999.250 SIGC. PS3 -999.250 SIBH. PS3 -999.250 TRAT. PS3 SDSI.PS3 -999.250 BACK. PS3 -999.250 FBAC. PS3 -999.250 TCAN. PS3 TCAF. PS3 -999.250 TCND. PS3 -999.250 TCFD.PS3 -999.250 TSCN. PS3 TSCF. PS3 -999.250 INND.PS3 -999.250 INFD.PS3 -999.250 TENS. PS3 GR.PS3 105.498 CCL.PS3 0.000 DEPT. 12049.000 SIGM. PS3 44.696 TPHI.PS3 64.575 SBHF. PS3 SBHN. PS3 62.730 SIGC. PS3 0.508 SIBH. PS3 88.494 TRAT. PS3 SDSI.PS3 0.931 BACK. PS3 153.800 FBAC. PS3 35.822 TCAN. PS3 TCAF. PS3 9225.773 TCND. PS3 11793.908 TCFD. PS3 2771.937 TSCN. PS3 -999.250 -999.250 -999.250 -999.250 829.000 53.486 1.642 35406.914 934.843 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-APR-1997 23:58 PAGE: 23 TSCF. PS3 254.598 INND. PS3 GR.PS3 92.690 CCL.PS3 1726.032 INFD.PS3 -999.250 249.878 TENS.PS3 1539.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION · O01CO1 DATE : 97/04/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 97/04/ 3 ORIGIN : FLIC TAPE NAME : 97148 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : BP EXPLORATION (ALASKA), 3-01/N-29 SDI, ENDICOTT, 50-029-21678-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 97/04/ 3 ORIGIN : FLIC REEL NAME : 97148 CONTINUATION # : PREVIOUS REEL : COf4~ENT : BP EXPLORATION (ALASKA), 3-01/N-29 SDI, ENDICOTT, 50-029-21678-00 LiS TAPE VERIFICATION LISTING LVP OiO.H02 VERiFiCATiON LISTING PAGE i ~ REEL HEADER SERVICE NAME :EOIT DATE :8'7/01/28 ORIGIN : REEL NAME :72170 CONTINUATION ~ :01 PREVIOUS REEL COMMENTS :~LIS T~PE, '-, 'TAPE HEADER SERVICE NAME :EDIT DATE :87101/28 ORIGIN :7217 TAPE NAME : CONTINUATION ~ :01 PREVIOUS TAPE : COMMENTS :LIS TAPE, ST~NDAR~ ENDICOTT N-29, .4Pi ST~INDARD ENDICOTT N-29, API *" .... ~'"'"' ........ '" ;'OF " .........."'""* ...... 50-029-21678 50-029-21678 -, .... FILE HEADER,,--,-'~ FILE NAME :EDIT SERVICE N~ME : VERSION ~ : DATE : MAXIMUM 'LENGTH : FILE TYPE : PREVIOUS FiLE : .00i 1024 · ~'"~--,. .T N~ 0 RM A T i ON, R ECO R 0 S -,.'~'~, MNEM CONTENTS UNiT TYPE CATE SIZE COCE CN : STANDARO ALASKA PRODUCTION CO. 000 000 030 065 WN : 3-1/N-29 SDi 000 000 012 065 FN : ENDICOTT 000 000 008 065 RANG: 17E 000 000 00~ 055 TOWN: IIN 000 000 004 065 SECT: 8 000 000 002 065 COUN: NORTH SLOPE 000 000 012 065 STAT: ALASKA 000 000 006 055 CTRY: USA 000 000 003 065 .MN~M. CONTENTS UNIT TYP~. CAT~. SI~=~. COCE LVP OlO.M02 VERIF!CATI~ LISTING P~GE 2 · ,, SCHLUMBERGER '".,. ~LASK~ COMPUTING CENTER COMPANY : STaND,PO ~LASK~ PRODUCTION CO WELL . : 3-1/N-29 SDI FIELD = ENDICCTT COUNTY = NORTH SLOPE 8~ROUGH STATE = ALASK~ API ~ = 50-029-21678 LOCATION : 2535' :NL G 8?8' FEL SEC 8 ~ , TilN, RI?E JOB NUMBER AT AKC~C: 72170 RUN N1, DATE LOGGEO: 21-JAN-87 LOP: RICK KRUWELL CASING CASING TYPE FLUID DENSITY VISCOSITY FLUID LOSS MATRIX SANDSTONE : 13.375" 2 2480' : 9.625" ~ 12111' - BIT SIZE : $.5" TO 13050' : ~ ? LIGNOSULFONATE = I0.0 LS/G RM = 1.34 ~ 65 DF = 40 S RMF ': !.04 @ 65 DF : 11.0 RMC : 1.64 ~ 65 DF : 6.8 C3 RM AT BHT = .473 ~ 197 DF LVP OlO.H02 VERIFICATION LISTING PAGE 3 NOTE: FILE EDIT.001 CONTAINS DATA SAMPLED AT .5' FILE EOIT.O02 CONTAINS MSFL SAMPLEO AT FILE EDIT.O03 CONTAINS HTEN OATA SAMPLEO 4T .0416' LOT/CNL/OLL/MSFL/NGT A~LL HAVE PORTIONS OF REPENT FILE REPLACING LOG FILE OUE TO PULLS ON LOG FILE .... ,--,- THIS DATA HAS ~AEEN D:PTH. SHIFTED TO DUAL LATEROLOG TOOL SCHLUMBERGER LOGS INCLUDEO WI'TH 'THIS MAGNETIC TAPE: D~L LATERLOG (OLL) DATA ~VAILABLE: lJO3~' TO I2100' ARRAY SONIC LOG (SOT) DATA AVAILABLE: 13041' TO i2100' LITHO OENSITY COMPENSA'TE~ :LOG (LOT) COMPENSATED NEUTRON LOG (LOT) DATA AVAILABLE: 13016' TO 12100' NATURAL GAMMA TOOL (NGT) DATA A~AILABLE: 12986' T~ 12100' LVP OiO.HOZ VErIFICATiON LISTING PAG~ 4 ;:: GAMMA RAY IN CASING (CSG) * OAT4 AVAILABLE: 12100' TO 11730' ;~.,~ ,. ........... .,o .,. ,~ .... ~'~ DATA FORMAT R~CORD. ~.'"'"-~. ENTRY BLOCKS TYPE SIZE REPR :CODE ENTRY 2 1 66 0 4 1 66 1 8 4 73 60 9 4 85 .liN 16 1 65 1 0 1 66 0 ]ATUM S:PE:CIFICATION BLO'CKS MNEM SERVICE SERVICE UNIT API API APi ~PI FILE SIZE SPL REP'R ID OROER# LOG TYPE CLASS MOO NO.. DEPT FT O0 000 O0 0 0 LLS DLL OHMM O0 220 09 0 0 ~LD DLL OHMM O0 220 10 0 0 SALS DLL IN O0 000 O0 0 0 SP DLL MV O0 010 01 0 0 SGR DLL GAPI O0 310 O1 0 0 DVO DLL MV O0 000 O0 0 0 OIO DLL U~ O0 000 O0 0 0 5VO DLL MV O0 000 O0 0 0 SIO OLL UA O0 000 O0 0 0 DV1 DLL MV O0 000 O0 0 0 ~RES DLL DHMM O0 823 50 0 0 qTEM DLL DEGF O0 660 50 0 0 ~ENS DLL LB O0 635 21 0 0 ~HOB LOT G/C3 O0 350 02 0 0 ]RHO LOT G/CB O0 356 O1 0 0 ]PHI LOT PU O0 890 O0 0 0 ~EF LOT O0 358 O1 0 0 :ALI LOT IN O0 280 O1 O 0 5GR LOT GAPI O0 310 01 0 0 .SHY LOT V O0 000 O0 0 0 ~SHV LOT V O0 000 O0 0 0 ~LS LOT O0 000 O0 0 0 2SS LOT O0 000 O0 0 0 .L LOT CPS O0 35~ O! O 0 -U LOT CPS O0 35~ O1 0 0 .ITH LOT CPS O0 354 01 0 0 PROCESS CODE (OCTAL) 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 6B 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 58 O000OO00000000 58 O0000OO0000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 O0000000OO0000 68 00000000000000 68 00000000000000 68 00000000000000 LVP OlO.H02 VERIFICaTiON LISTING PaGE 5 SS1 LOT SS2 LOT NPHI LOT NRAT LOT RNRA LOT NC NL LOT FCNL LDT MRES LDT MTEM LD'T TENS LDT U R ~ N N G T THOR NGT POTA NGT SG R NG'T C G R' N G T WSNG NGT W4NG NGT W3NG NGT W2NG NGT W1 NG NGT CS NGT MRES NGT MTEM NGT TENS NGT DTCO SDT DTST SDT DTSM SDT OT SOT D T L S D T LSDT SDT LDTL SDT GR SDT MRES SDT MTEM SOT TENS SDT GR CSG MRES CSG MTEM CSG TENS CSG ..... DA DEPT SP SVO ~TEM DPHI LSHV LL S S 2 NCNL TENS SGR 13078.0000 LLS -999.2500 SGR -999.2500 SIO -999.2500 TENS -999.2500 PEF -999.2500 SSHV -999.2500 LU -999.2500 NPHi -999.2500 FCNL -999.2500 URAN 0.0000 CGR CPS O0 000 O0 0 CPS O0 000 O0 0 PU O0 890 O0 0 O0 420 O! 0 O0 000 O0 0 CPS O0 330 31 0 CPS O0 330 30 0 OHMM O0 823 50 0 DEGF O0 660 50 0 L5 O0 635 21 0 PPM O0 792 50 0 PP~ O0 790 50 0 PU O0 719 50 0 GAPI O0 310 O1 0 GAPI O0 310 O1 0 CPS O0 310 Oi 0 CPS O0 310 01 0 CPS O0 310 Ot 0 CPS O0 310 Ol 0 CPS O0 310 O1 0 F/HR O0 636 21 0 OHMM O0 823 50 0 DEGF O0 660 50 0 LB O0 635 21 0 US/F O0 000 O0 0 US O0 000 O0 0 UStF O0 530 t6 0 US/F O0 520 80 0 US/F O0 520 80 0 UStF O0 520 80 0 US/F O0 520 80 0 G~PI O0 310 O1 0 OHMM O0 823 50 0 DEGF O0 660 50 0 LB O0 635 21 0 G~PI O0 310 01 0 OHMM O0 823 50 0 DEGF O0 660 50 0 LB O0 635 21 0 -999 · O. -999. -999. -999. -999 · -999. -999. -999. O. O. 2500 0000 2500 2500 2500 2500 2500 2500 2500 0000 0000 LLD OVO DVl RHOB CALI ~LS LITH NRAT MRES TmOR 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 -999. -999. -999. -999. -999. -999. -999. -999. O. 18. 2500 2500 2500 2500 2500 2500 2500 2500 2500 0000 3906 68 00000000000000 68 O0000000OO0000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 O000OO00000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000~000000 68 00000000000000 68 00000000000000 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 0'0000000000000 68 00000000000000 68 O000OO00000000 68 00000000000000 88 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 O00000000000DO 68 00000000000000 68 O000000OO00000 CA OI MR DR SG ~S SS RN MT PO W4 LS -999.2500 0 -999.2500 ES -999.2500 HO -999.2500 R 0.0000 S -999.2500 1 -999.2500 RA -999.2500 EM -999.2500 T~ 0.0000 NG 24.1250 LVP OlO,H02 VERIFICATION LISTING PAGE 6 W3NG M R E S DTST LSDT MTEM MTEM OEPT SP SVO MTEM DPHI LSHV LL SS2 NCNL TENS SGR W3NG MRES DTST LSDT MTEM MTEM DE PT SP SVO MTEM DPHI LSHV LL SS2 NCNL T;NS SGR 43NG ~RES DTST .SOT qTEM ~.TEM )EPT ~P 5VO ~TEM }PHi .SHV .L ~S2 ~CNL FENS 43.6563 NZNG -999.2500 MTEM -999.2500 DTSM -999,2500 ~LDTL -999,2500 TENS -999.2500 TENS 167.7500 WING -!999.2500 TENS -999,2500 DT -999.2500 GR -999.2500 GR -999.2500 13000,0000 LiLS -78,7500 SGR 10,6797 SIO 195,1250 TENS 4.2969 PEF 1256.0000 SSHV 119.8750 LU 286,2500 NPHi 3640.0000 FCNL 8280,0000 URAN 106,7500 CGR 53.5938 W2NG 0.3677 MTEM 210.0000 DTSM 82,0000 LDTL 205,6250 'TENS -999,2500 TENS 44,9028 LLD 106,7500 DVO 345.0000 DY1 8280,0000 RHOB 2,2500 CALI 1238,0000 ~LS 229,6250 LITH 24.5117 NRAT 1448.0000 MRE$ 5.5391 THOR 66.6875 WSNG 168.6250 WING 195,1250 TENS 117.0000 DT 82,6250 GR 7508,0000 GR -999,2500 12900,0000 LLS -73,6875 SGR 10,4219 SIO 196,2500 TENS 24,9023 PEF 1257.0000 SSH¥' 228.6250 LU 337,0000 NPHi 2470,0000 FCNL $248.0000 ORAN 103.2500 CGR 47.4688 WZNG 0.3784 MTEM 224.0000 DTSM 105.5000 LOTL 206,2500 TENS -999.2500 TENS 37.2446 LLD 103,250'0 DVO 405.7500 DV1 8248.0000 RHOS 2,0605 CALi 1240,0000 QLS 405,5000 LiTH 47.9614 NRAT 645.8125 MRES 4.9687 THOR 67.3125 WSNG 169.6250 W1NG 196.2500 TENS 153.0000 DT 105.0000 GR 7364.0000 GR -999.2500 12800,0000 LLS -106.0625 SGR 1.7588 SIO 195.0000 TENS 22,0215 PEF 1258,0000 SSHV 203.5000 LU 315.0000 NPHi 4204.0000 FCNL 7300.0000 URAN 24,0000 CGR 2.755~ LLD 24,0000 DVO 922,0000 DV1 7300.0000 2.1211 CALI 1240.0000 ~LS 3~8.5000 LITH 21.6797 NRAT 1859.0000 MRES 0.5606 THOR 19.2187 WSNG 393,0000 -999,2500 -999,2500 -999,2500 -999,2500 31.9560 11.3906 13.3594 2.5781 8.5156 -0.0010 72,8750 2.3809 0.3677 14.6875 18.4531 352,2500 8280,0000 82,31125 146.8750 -999.2500 26.4490 10,6~06 12,1562 2.2383 8.7891 -0,0127 162,5000 3.7837 0,3784 12.5313 11.4297 334.0000 $248.0000 107.7500 98.0625 -999.2500 2.1913 1,6848 2.3164 2,2852 8,4922 0,0259 127,9375 2.1758 0.3809 3.1191 4.6641 CS DTCO DTL MRES MRES CALS 010 MRES DRHO C~SS SS1 RNRA MTEM PL}TA W4NG CS OTC 0 D TL MRES MRE S CALS DIO MRES DRHO SGR QSS SS1 RNRA MTEM POTA W4NG CS DTC3 DTL MRES MRES CALS DIO MRES DRHC SGR ~SS SS1 RNRA MTEM P~TA W4NG 1420.0000 -999.2500 -999.2500 -999.2500 -999.2500 8,8750 317.2500 0.3677 0,0239 106,7500 0,0264 214.,6250 2.5137 195.1250 0.7324 21.9531 1622,0000 67.0000 81,5000 0,3511 -999,2500 8.8437 358.2500 0.378,4 0.0366 103.2500 0.0425 241.2500 3.8213 196.2500 1.3184 16.7031 1682.0000 91.0000 109.6250 0.3555 -999.2500 8,5234 765.5000 0.3809 0.0132 24,0000 0,0488 229.7500 2.2598 195.0000 0.4883 4.6641 LVP OlO.MOZ VERIFICATION LISTING PAGE W3NG 10,2578 W2NG MRES 0,3809 MTEM DTST 231,0000 OTSM LSDT 95,0000 LDTL MTEM 200.8750 'TENS MTEM -999.2500 'TENS DEPT 12700,0000 LLS SP -114.4375 SGR SVO 4.2.539 SIO MTEM 195,2500 TENS DPHI 22.!298 PEF LSHV 1259.0000 SSHV LL 198,8437 LU SS2 317o7422 NPHI NCNL 4028,0000 FCNL 'TENS 7408,0000 URAN SGR 28.5000 CGR W3NG 12.5781 W2NG MRES 0.3?84 MTEM' DTST 229.0000 DTSM LSDT 94,1250 LDTL MTEM 202,2500 TENS MTEM -999,2500 TENS' DEPT 12500,0000 LLS SP -63.5000 SGR SVO 25,5322 SIO MTEM 199.6250 TENS DPHI 23.4573 PEF LSHV 1260.0000 SSHV LL 203.0996 LU SS2 317.1406 NPHI NCNL 4636.0000 FCNL TENS ?296,5000 URAN SGR 21.0508 CGR ~3NG 9.4414 W2NG ~RES 0.3726 MTEM 3TST 234.0000 DTSM .SDT 96.1250 LDTL qTEM 199.6250 TENS qTEM -999.2500 TENS 3EFT 12500.0000 LLS 5P -94.6250 SGR SVO 35.3438 S!O qTEM 191.8750 TENS ]PHI 23.6328 PEF .SHV 1260.0000 SSHV .L 204.7500 LU ~S2 312.7500 NPHi ~CNL ~192.0000 FCNC tENS 7320.0000 URAN ~GR 19.8135 CGR 37. 195. 136. 95. 6864. -999. . 28. 699. 7408, t, 1241, 352. 19, 1936. O, 27, 44. 195, 131. 94. 6804. -999. 290. 2t, 127. 7296. 1. 1240. 364, 20. 2124. O, 16. 36. 199. 150. 95. 6964. -999. 974. 19. 52. 7320. 1. 1240. 359. 22. 1786. O. 13. 3125 0000 0000 2500 0000 2500 8208 5000 5000 0000 9024 9180 8281 1406 0000 0947 8164 3008 2500 0000 3750 0000 25 O0 0000 0506 6875 50OO 7t90 7598 1406 O195 0000 5967 7305 5176 6250 0000 7500 0000 2500 9851 8135 5938 0000 8057 0000 2500 1191 4219 8083 9651 WING TENS gT GR GR L L D DVO DV 1 RHO8 CALI QL S L!TH NRAT MRES THOR WSNG WING TENS DT GR GR LLD DVO RHOB CALI QLS LITH NRAT MRES THOR W5NG WING TENS DT GR GR LLD DVO DV1 CALI ~LS LITH NRAT MRES THOR WSNG 78.3125 CS '7300.0000 gTCO 95.8125 DTL 20.3281 MRES -999.2500 MRES 6,1707 CALS 4.0938 5.0352 MRES 2.2842 DRHO 8.3600 SGR -0.0:007 QSS 134.9375 SSI 2.0176 RNRA 0.3784 MTEM 5.0371 PCTA 7,2,422 WHNG 94.8125 CS 7408.0000 D'TCO 95.3750 DTL 29.4375 MRES -999.2500 MRES 272.312~ CALS 26.3652 OIO 31.2773 MRES 2.2611 DRHO 8.5671 SGR -0.0110 ~SS 143.1875 SSi 2.0781 RNRA 0.3726 MTEM 2.5173 PCTA 3.3203 W4NG 64.0000 CS 7296.5000 DTCO 97.7500 DTL 22.2187 MRES -999.2500 MRES 1423.2078 CALS 42.0938 OiO 52.0525 MRES 2.2578 DRHS 8.5313 SGR 0.0054 QSS 138.2500 SSi 2.2231 RNRA 0.3960 MTEM 1.6189 PCTA 1.9766 WHNG 1688.0000 81.0000 94.9375 0.3677 -999.2500 8.5000 590.5000 0.3784 0.0057 28.5000 0.0253 224.7422 2.0801 195.2500 0.5703 3.3242 1687,5605 80.0000 93.9375 0.3755 -999,2500 8.6172 86,2109 0.3726 -0.0030 21.0508 0.0143 220.2617 2.1816 199.6250 0.4449 1.1406 1687.7773 82.0000 95.8125 0.3745 -999.2500 ~.4453 26.3281 0.3960 -0.0059 19.~135 0.0186 218.5000 2.3454 191.8750 0.4883 1.3730 LYP OiO.H02 VERIfICATiON LISTING PAGE 8 WSNG MRES DT S T LSDT MT EM MTE M DEPT SP SVO MTEM OPHI LSHV LL SS2 NCNL TENS SGR W3NG MRES DTST LSDT MTEM MTEM 9,7109 WZNG 31,5000 0,3960 MTEM 191,8750 226,0000 DTSM 142,0000 99,3750 LgTL 98.7500 197,7500 TENS 6792,0000 -999,2500 TENS -999,2500 12400.0000 LLS 405,4536 -97,2500 SGR 24,1328 29,09B8 SIO 104,0000 190.5000 TENS 7440,0000 24,6691 PEF 1,7428 1260,0000 SSHV t241,0000 215,4570 LU 377,0000 320,8594 NPHI 22.5159 4204,0000 FCNL 1760,2500 ?440,0000 URAN 0,6554 24,1328 CGR 19,389.2 9.5234 W2NG 3t.3672 0.3965 MTEM 190,5000 2Z6,0000 DTSM 139.0000 98,5000 LOTL 98,6250 196,3750 TENS 6884,0000 -999,2500 TENS -999,2500 OEPT 12300..0000 LLS 63,1203 SP -66,3750 SGR 55,3438 SVO 14,3750 SiO 330,2500 MTEM 188.1250 TENS 7748,0000 OPHI 19,5404 PEF 2.1155 LSHV 1258,0723 SSHV t240.0000 LL 184,7031 LU 331.3125 5S2 307,9062 NPHI 25,8301 NCNL 3660,0000 FCNL 1404.0000 TENS 7748,0000 URAN 2,3501 SGR 55,3438 CGR 38.3242 ~3NG 10,2578 W2NG 69,0000 MRES 0,4087 MTEM 188.1250 ]TST 258,0000 DTSM 140.0000 LSDT 99. 2500 LDTL 97. 3750 qTEM 192.5000 TENS 6884.0000 ~TEM -999.2500 TENS -999,2500 )EPT 12200,0000 LLS 12.7452 SP -39,5938 SGR 86.7813 SVO 4.5586 SIO 518.5000 ~TEM I87.0000 TENS TZ2$.0000 ]PHi -0.7080 PEF 2.8843 .SHV 1259.0000 SSHV 1239,0000 .L 101,4922 LU 201.7500 ~S2 270,9844 NPHi 18,1366 '~CNL 450~ 5000 F~ '' · .. ~,NL 2052 OOO0 FENS 7228.0000 URAN 4.9092 ~GR 86.7813 CGR 51.2734 WING ~ENS DT GR GR LLD DVO RH~B CALI QLS 'LITH NRAT MRES THOR WSNG WI'NG TENS DT GR GR LLO DVI RHOB CALi QLS LITH NRAT MRES T~OR WSNG WiNG TENS DT GR GR LLD DVO RHOB CALI GLS LiTH NRAT MR~S THGR WSNG 66,3125 CS 7320.0000 D'TC~ 99.0625 DTL 20,6094 MRES -999,2500 MRES 529.4515 CALS 33,6250 DIO 39.0313 MRES 2.2418 DRHO 8,5026 SGR 0,0027 QSS t52,8320 SSi 2,2%13 RNRA 0.3965 MTEM 3.~568 PCTA 3,3125 W4NG 86,3750 CS 7~40.0000 DTC~ 99.6875 OTL 26.4219 MRES -999.2500 MRES 61,7107 CALS 17,3438 DIO 18,4844 MRES 2,3265 DRMU 8.6412 SGR -0.0023 ~SS 123.9331 SS1 2,4746 RNRA 0,4087 MTEM 7.0361 POTA 1.8652 W4NG 146.3750 CS 7748.0000 OTCO 97.18'75 DTL ~3.7813 MRES -999.2500 MRES 11,5647 CALS 5· 6'11~ OIO 7,1172 MRES 2,6395 DRHO 9.3667 SGR -0.0050 QSS 52.9883 SSi 2,0710 RNRA 0.4058 MTEM 10.2813 PGTA 13.8123 1584,1172 83,000:0 98,6250 0,3887 -999.2500 8,4531 56,3000 0.3965 0.0033 24,132B 0,0278 225,9590 2.3883 190,5000 0,3906 3,3125 1677,4453 81,0000 99,1250 0,3867 -999.2500 8.5859 250.2500 0.4087 0.0098 35.3438 0.0432 224,6914 2,6055 188,1250 0,'7463 2,7959 1718,2852 89,0000 98.2500 0.3984 -999.2~00 8.8281 432.5000 0.4058 0.0157 86.7813 0.0252 206.3984 2.1958 187.0000 0.7942 12.6836 LVP OlO.H02 VERIFICATION LISTING PAGE 9 W3NG MRES DT ST LSDT MTEM M~T EM DEPT SP SVO MTEM OPHI LSHV LL SS2 NCNL TENS SGR W3NG MRES DTST LSDT HTEM MT E M DEPT SP SVO MTEM DPHI LSHV LL SS2 NCNL fENS SGR ~3NG ~RES ]TST .SOT ~TEM ~TEM )EPT ~'VO 4TEM ]PHI .SHV .L .~S2 4CNL FENS ~GR 35,8521 W2NG 0,4058 MTEM 202.0000 DTSM 84,1250 LDTL 191,0000 TENS -999.2500 TENS 12100,0000 LLS .-25-5156 SGR 0,3008 SIO 183,1250 TENS -2.0851 PEF 1259,0781 SSHV 42,9609 LU 73,9062 NPHI 1951.0000 FCNL 7400,3750 UR~N 125,6250 CGR 59.8750 W2NG 0.4263 MTEM 209.2500 DTSM 138.1250 LDTL 186.1250 TENS 189,0000 TENS 12000,0000 LLS -999,2500 SGR -999,2500 SIO -999,2500 TENS -999.2500 PEF -999.2500 SSHV -999,2500 LU -999.2500 NPHi -999.2500 FCNL -999.2500 URAN '-999.2500 CGR -999.2500 W2NG -999.2500 MTEM -999.2500 DTSM -999.2500 LDTL -999,2500 TENS 187.2500 TENS 11900,0000 LLS -999,2500 SGR -999.2500 -999.2500 TENS -999.2500 PEF -999.2500 SSH¥ -999.2500 LU -999.2500 NPHi -999.2500 PCNL -999.2500 UR~N -999.2500 CGR 138,6875 WING 187.0000 TENS tt7.0000 83.5000 GR 6880.0000 GR -999.2500 0,1407 LLD 125,6250 DVO 3100.0000 OVl 7400,3750 RHOB 35.41531 CALi 1242,0000 ~LS 113.0156 LITH 50,8789 NRAT 441.0000 MRES 9.1328 THOR 59.5000 WSNG 183.6250 WiNG 183.1250 TENS 160.0000 DT 109.0000 GR 6612.0000 GR 6340.0000 -999,2500 LLD -999,2500 DVO -999,2500 -999,2500 RHO~ '-999,2500 C~Li -999.2500 ~LS -999.2500 LiTH -999,2500 NRA'T -999.2500 MRE$ -999.2500 THOR -999,2500 WSNG -999,2500 WING -9'99.2500 TENS -999.2500 OT -999.2500 GR -999.2500 GR 6320.0000 -999.2500 LLD -999.2500 GVO -999.2500 DVi -999.2500 RHOB -999,2500 C~LI -999.2500 ~LS -999.2500 LITm -999.2500 NRAT -999.2500 MRES -999.2500 TmO;~ -999.2500 WSNG 293.5625 CS 7228,0000 DTCO 84.2500 DTL 89.9375 MRES -999.2500 MRES 0.1602 CALS 0,3330 DIO 0,6538 MRES 2o6841 DRHD B.7891 SGR -0.0530 QSS I0.3081 SSi 3.9707 RNRA 0,4263 MTEM 9.6563 P~TA iB.9687 W4NG 4~7,0000 CS 7400.3750 DTCO 120.68'75 DTiL 111.8750 MRES 143.6250 MRES -999.2500 CALS -999.2500 gIO -999.2500 MRES -999'2500 DRHO -999.2500 SGR -999.2500 QSS -999.2500 SSi -999.2500 RNR~ -999.2500 MTEM -999.2500 PDTA -999.2500 W4NG -999,2500 CS -999.2500 DTC~ -999.2500 DTL -999.2500 MRES 200.1250 MRES -999.2500 CALS -999.2500 OlO -999.2500 MRES -999.2500 DRH~ -999.2500 SGR -9~9.2500 ~SS -999,2500 SS1 -999.2500 RNRA -999.2500 MTEM -999.2500 PCTA -999.2500 W4NG 1814,0000 '71,0000 80,3750 0,3975 -999,2500 9.1484 1850.0000 0.4263 -0.4978 125.6250 -0.1633 50.2031 4.4219 183,1250 1.5137 20.9531 1'730.0000 85.0000 144.3750 0.4170 0.42'72 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999°2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -99~.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 LVP 010.H02 VERIFICATION LISTING PAGE 10 W3NG -999.2500 W2NG -999, MRES '-99'9,2500 MT~M -999, DTST -999.2500 DTSM .-999. LSD'T -999,2500 LDTL -999, MTEM -999.2500 TENS -999. MTEM 184.0000 TENS 6248. DEPT 11800,0000 L~LS -9'99, SP -999,1500 SG2 -999, SrO -999,2500 SiO -999, MTEM -999,2500 TENS -995, DPHI -999,2500 PEF -999. LSHV -999,2500 SSHV -999, LL -999,2500 LU .-999, SS2 -999,2500 NPHI -999, NCNL -999,2500 FCNL -999, TENS -999,2500 URAN .-999. SGR -999,2500 CGR -999, WBNG -999.2500 W2NG -999, MRES -999,2500 MTEM -999, DTST -999-2500 DTSM -999. LSDT -999.2500 LOTL -999. MTEM -999,2500 TENS -999. MTEM 181.6250 TENS 6204. DEPT 11722,0000 LLS -999, SP -999.2500 SGR -999, SVO -999,2500 SiO -999, MTEM -999,2500 TENS -999, DPHI -999,2500 PEF -999, LSHV -999,2500 SSMV -999, L'L -999,2500 LU -999, SS2 -999.2500 NPHi -999. ~CNL -999.2500 FCNL -999. TENS -999.2300 URAN -999. SGR -999,2500 CGR -999. ~3NG -999,2500 WZNG -999, ~RES -999.2500 MTEM -999. ]TST -999.2500 DTSM -999. LSDT -999.2500 LOTL -999. qTEM -999,2500 TENS -999, qTEM 180.2500 TENS 6164. ~: FILE TRAILER =ILE NAME :EOIT .OO1 SERVICE NAME : ~ERSION ~ : ]ATE : qAXiMUM L~NGTH : :IL:- TYP= : '~EXT FILE NAME : 2500 WiNG 2500 TENS 2500 OT 2500 SR 2500 GR 0000 2500 LLO 250O DVO 2500 DV1 2500 RHOB 2500 CALi 2500 QLS 2500 LITH 2500 NRAT 2500 MR~S' 2500 THOR 2500 W5NG 2500 WiNG 2500 ~ENS 2500 DT 2500 GR 2500 GR 0000 2500 ~LLD 2500 D¥O 2500 DY1 2500 RHOB 2500 CALi 2500 ~LS 2500 LITH 2500 NRAT 2500 MRES 2500 THOR 2500 WENG 2500 WiNG 2500 TENS 2500 gT 2500 GR 2500 GR 0000 -999.2500 CS -999,2500 DTCO -999.2500 DTL -999.2500 MRES 129,6250 MRES -9'99,2500 CALS -999.2500 DIO -999,2500 MRES -999,2500 DRHO -999,2500 SG~ -999,2500 QSS -999,2500 SS1 -999,2500 RNRA -999.2500 MT~M -999,2500 POTA -999,2500 W4NG -999,2500 CS -999,2500 gTCO -999.2500 DTL -999,2500 MRES 87.9375 MRES -999,2500 CALS -999.2500 DIO -999,2500 MRES -999,2500 DRHO -999,2500 SGR -999,2500 QSS -999.2500 SS1 -999.2500 RNRA -999,2500 MTEM -999,2500 POTA -999.2500 W4NG -999.2~00 CS -999.2500 gTCO -999.2500 DTL -999.2~00 MRES 76.0625 MRES -999.2500 -999.2500 -999.2500 -999.2500 0.4507 -999.2500 -999.2500 -999,2500 -999,2500 -999.2500 -999.2500 -999.2500 -999,2500 -999,2500 -999.2500 -99:9.2500 -999.2500 -999.2500 -999.2500 -999.2500 0.4609 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 0.466~ LVP OlO.H02 VERIFICATION LISTING P4GE 11 ~ FILE HEADER FILE NAME :EDIT' SERVI.CE NAME VERSION ~ : DATE : MAXIMUM LENGTH : FILE TYPE : PREVIOUS FILE : .002 1024 ~',~* DATA FORMAT ENTRY BLOCKS RECORO ~ TYPE SIZE Z 4 1 9 4 16 1 0 DATUM MNEM DEPT MSFL REPR CODE 65 x6 65 66 66 SPECIFICATION 5LOCKS SERVICE SERVICE UNIT API API APi ID ORDER ~ LOG TYPE CLASS FT O0 000 O0 DLL OHMM O0 270 04 ENTRY 0 i 20 .liN t 0 AP1 FILE SIZE SPL MO0 N3. 0 0 4 0 0 4 I REPR CGDE 68 PROCESS (OCTAL) 00000000000000 00000000000000 DEPT D:PT~ 3EPT JEPT ]EPT ]EPT ]EPT 'EPT ]EPT ]EPT ATA 13076.8320 MSFL 321.5000 13000.1660 MS'FL 40.2500 12900.1660 MSEL 37.0000 1 2800. 1660 MS~L 6. 1992 12700.1660 MSFL 20. 2031 12600.1660 MSFL 17.8281 12500.1660 MSFL 12.7266 12400. 1660 MSFL 14. 5313 12300.1660 MSFL 21.5156 12200. 1660 MSFL 8. ~,297 12100.1660 MSFL 0.3682 1 2067. 5000 MSFL O. 3066 LVP OIO.H02 VERIFICATiCN LISTING PAGE 12 :~.,- FiLE TR~ILER FILE NAME :EDIT .002 SERVICE N.~ME : VERSION ~ : DATE : MAXIMUM LENGTH : I024 FILE TYPE : NEXT FILE NAME : ~":-* FILE HEADER FILE NAME :EDIT SERVICE NAME : VERSION ~ : DATE : MAXIMUM LENGTH : FILE TYPE : PREVIOUS FILE : .003 1024 ,,-"'""-.- DATA FORMAT RECORD ""~-,. ENTRY BLOCKS TYPE SiZE REPR COOE 2 i 66 4 1 66 $ 4 73 9 4 65 16 I 66 0 1 65 DATUM SPECIFICATION BLOCKS qNEM SERVICE SERVICE UNIT ID 3ROER~ ]EPT FT -~TEN DLL LS 4TEN LOT L8 ffTEN NGT L5 '~TEN SOT L5 qTEN CSG L8 13076.9570 HTEN -999.2500 HTEN ]EFT '~TEN 13000.2910 HTEN 722.0000 HTEN ]EPT ~TEN 12900.2910 HTEN 736.5000 HTEN ]:mT,... ~TEN &Pi AP1 AP1 ~PI FiLE LOG TYP~ CLASS MOS O0 OOO O0 0 O0 000 O0 0 0 O0 000 O0 0 0 O0 000 O0 0 O0 000 O0 0 O0 000 O0 0 0 -177.8750 HTEN -999.2500 126~.0000 ~TEN -99~.2500 1293.0000 HTEN -999.Z500 ENTRY 0 1 .liN 1 0 SIZE SPL REPR CODE 4 i 6,8 4 i ~8 I 68 4 ! 68 4 I 68 I 68 -177.87~:0 rtTEN !2e4.0000 ~TEN i293.0000 MTEN PROCESS (CCT~L) 00000000000000 00000000000000 00000000000000 00000000000000 O0000000000000 00000000000000 -177.8750 1264.0000 1293.0000 LVP OlO.H02 VERIFICATION LISTING PAGE 13 DEPT 12800.2910 HTEN HTEN 520.5000 HTEN DEPT 12700,2910 HTEN HTEN 526.5000 HTEN OEPT 12600,2910 mTEN HTEN 622,0000 HTEN OEPT 12500,29t0 HTEN HTEN 555.0000 HTEN OEPT 12400,2910 HTEN HTEN 615.5000 HTEN DEPT 12300-2910 HTEN HTEN 682,0000 HTEN DEPT 12200,2910 HTEN ~'TEN 735.0000 HTEN DEPT 12100,2910 HTEN 5TEN 587.0000 HTEN 2EPT 12000.2988 HTEN qTEN -999,2500 HTEN ]EPT 11900.2734 H'TEN iTEN -999.2500 HTEN ]EPT 1I$00.289i HTEN !TEN -999,2.500 HTEN ]EPT 11724.4512 HTEN iTEN -999.2500 HTEN 915.0000 -999,2500 944.0000 -999,2500 977.0625 -999.2500 942.0000 --99~.2500 1090,0000 -999.,2500 !219,0000 -999,2500 1160,0000 -999.2500 1159.5000 407.5000 -999.2500 40'7.7500 -999,2500 407.5000 -999.2500 413.5000 -999.2500 -999.2500 HTEN HTEN HTEN HTEN H'T EN HTEN H TEN HTEN HTEN HTEN HTSN FILE TRAILER ** :ILE NAME :EDIT ~ERVICE NAME : tERSION m : ]~TE : 4.&XIMUM LENGTH : 1024 :ZLE TYPE : ~EXT FILE NAME : .... T~P~ TRAILER ..... ~ERViCE NAMc~ :E~IT~ ;ATE :87/01/28 ]RIGIN :7217 rAPE NAME : 944.0000 97'7.0625 942.0000 1090,0000 121~,0000 1150,0000 1159.5000 -999.2500 -999.2500 -999.2500 -999.2500 HTEN HT£N HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN HTEN 915.0000 94~,0000 977,0625 942,0000 1090.0000 1219.0000 1160.0000 1159.5000 -999.2500 -999.2500 .-999.2500 -999.2500 ,VP OlO.HOZ VERIFICATION LISTING PAGE ~ONTINUATION ~ :01 iEXT TAPE NAME : ;OMMENTS :LIS TAPE,' STANOARD ENDICOTT N-29., 4PI 50'-029-216T8 REEL TRAILER ~ ;ERVICE NAME :EDI'T )ATE :87/01/28 ~RIGIN : IEEL NAME :'72170 iON'T'INUATiON ~ :O1 IEXT REEL NAME : iOMMENTS :LIS TAPE~ STANDARD ENDICOTT N-Z9, API 50-029-21678 CCCCCCCCCC CCCCCCCCCC CCCCCCCCCC 8888 8838 9898 8888 38888888888888 8~ 8888 88888888 8882 8888 88888888 88888888 88888888 888888 888888888888 88 88888888 888688888888888888888898 Oigit~l Equipment Corporation - VAX/VMS Version V4.5 888888888888888888888888 888888 8~ 8888 9888,98 888898 98 8888 8~8~88 98 8~88~888888888 888888 8888888888888888888888888888888888888888888888 CCCCC£CCCC CCCCCCCCCC CCCCCCCCCC EEEEE N N EEEEE RRRR GGGG " ~ N E R R G E ~N N E R R G EEEE h N N EEEE RRRR G E N NN E R R G GGG E ~ N E R R G G EEEEE N N EEEEE R R 6GG Y Y Y Y Y Y Y Y Y Y PPPPP~>PP PPPPPPPP PP PP PP P~ PP FP PP FP PPPPPPPP PPPPPPPP PP PP PP PP PP EEEEEEEEEE SSSSSSSS DODODDE}D ; ;;; 888888 EEE EEEEEEE SSSSSSSS OOOODDOD ;;;; 888888 DO OD ',,,J 88 88 EE SS OD DO ;;;; 88 88 EE S~ DO O0 88 88 EE SS DO DO 88 88 EEEEEEEE SSSSSS DO DO ;;;; 888888 EEEEE-EEE SSSSSS DO OD ;;;; 888888 EE SS DO OD JJJJ 88 88 EE SS DO OD ;;;_; 88 88 EE SS DD DO ;; 88 88 EE SS OD DO ;; 88 88 EEEEEEEEEE SSSSSSSS DDDDOOOD ;; 888888 EEEEEEEEEE SSSSSSSS DDDODOOD ;; 888888 File _OUA1-'EES.USEROSFRINI.ESE;8 (12168,:18,0 [ENERGY], The record.: ere variable length m Job PRINT (100) queued to LPAO on 24-FEB-zg8 printer _LPAO: on 24-FEB-1987 !O:lT from que CCCCCC CCCC 88 888888 88~3~ 8888 3888888888 8888 CCCCCCCCCC 8888888~88868888 88 8838~8 Dig/ CCCCCCCCCC 88883888 383~ 8~88 8888 98:88888888 ), last revised on 24-F88-1987 10:14, is a 9 block sequential file o~ned i~h impl£ed (CR) carriage control. The longest record is 127 bytes. 7 i0:14 by user ENERGY, UIC EENFRGYlt under account VMS at priority lOOt ue L~AO. $688888888888888888888 88888888888888888888888888888888888888888888888888,88 t;l EquipRent Corporation - VAX/V~$ Version V4.5 888888888888888888888888 8898888898888888888888 8888888888888888888888:888888888888888888888888888888 by UIC started on CCCCCCCCCC CCCCCCCCCC CCCCCCCCCC ENERGY S¥STEPS T~CHNCLgS¥, INC. STANDARC INSTALLATIEN SYSTEM -.-*'".,- REEL HEADER '"'"-,-.,- SERVICE NAME :ESLIS DATE : 87/02/24 ORIGIN :EST Cr, NTIhUATTON ~ : PREVIOUS REEL : C~MMENTS : =~ TAPE HEADER SERVICE NAME :ESLIS DaTE :87/02/24 ORIGIN :,EST TAPE hAME : 6 C~NTINUATION a : PREVIGUS TAPE COMMENTS :TAK556 *~ INFORMATION RECORE ~:-~ MN EM CONTENT S ESWN: TAKS56 f~PER: STANDARD ALASKa PR~DUCIIGN CO. WN : 3-1/N-29 FN : ENCICgTT SDI COUN: NORTH SLDP~ ST, : ALASK~ ~L : CTRY: U. S. A. ELEV: -999.250 R1 : DATA FRO~ TELECO ~iLFIELD CN : SW LITH: SAND USRI: 0.500 MOEP: 12160°000 DINC: 0.500 STEM: 70.000 DREF: 3150.000 NfJMT: 8. 000 FLGS: %EEEEEE *'"-,-~- FILr-~ HEADER -,-'~'~'-,- FILE kAME :ESLIS SERVICE NAME : .001 3569 S. ~U~QN ST. UNIT SERVICES. 0 0 150 SUITE 202 ENGLEWDOO, CE 80110 FULL LISTING T~PE CAT. SIZE CDOE 0 0 lZ 65 0 O 30 65 0 0 30 65 0 0 30 65 0 0 30 65 0 0 30 6'5 0 0 30 65 0 0 30 65 0 0 30 65 0 0 4 68 65 0 0 2 65 0 0 4 65 0 0 4 68 0 0 4 68 0 0 4 68 0 0 ¢ 68 0 0 4 68 0 0 4 68 0 0 ~ 65 *~* L.I.S. T~PE VERIFICATION ""-.-.- 2C-FEB-87 10:11 PAGE: I C ENERGY SYSTEPS TECHNr'LDGI', THC,. STANDARi~ TNSTALLATICN SYSTEM VE RSIC~N ~ : DATE :97/0£/24 MaXIMbM LENGTk :1024 FILE TYPE PR EVI~US FILE : ~** COMMENTS DaTA FROM TELECG OTLFIELD SERVIC ES ~, M.W.D. 3669 S,,, HUmaN ST., SUITE 202 ENGLEWDDEt CE FULL LISTING 80110 ** L.I.S. TAPE VERIFICATION 24-FEB-g7 10:11 PAGE: ** DAIUM SPECIFICATION NUMBER DIRECTION LOGGED : DOWN 'C H NEH I D DEPTH GR SN : ' ...... RDP WDB RPM UNIT PRaCESS FT CNTS OH'tq'~r'' .............. : ........ ~ ...... ' ...... F'TtH ~L8S -~* FILE TRAILER FILE NAME :ESLiS .0§1 SERVICE NAME : VERSIEN ) : DATE :87/0Z/24 MAXIMUM LENGTh. :1024 FILE TYPE : NEXT FILE DEPTHS FOR DAIUM SPECIFIC~TIgN BLOCK I STARTING DEPT~ : 3150.~00 ENDING DEPTH : 12136.500 ¢ ¢ ENERGY SYSTEMS TECHNELOGY, INC. STANOARG INSTALLAI Ir.N -,-.,- TAPE TRAILER.,.~.'"'" SERVICE NAME :ESLIS D~TE :87/02/24 DRIGII~ =EST TAPE kAME CDNTI~UATION PREVIOUS TAPE : Cr~MMEI~TS :TAK5$6 S. HUE3N ST. SUITE 202 E NGLEWrlOO, FULL LISTING 80110 L.I.So TAPE 2~-FEB-87 VERIFICATIDN 10:11 PAGE: 777777777777777777777777TT777777T77777777777777777777r!rTtTilirlrllIfiillrlTfl~Tf11711fltlf17777 f7717~77 7777?7777777777777777777 Digital EquipJent Corpor'at£on- VAX/VN$ Version V4o5 7~111i71~I~7~7~1f17777 77777777777777777777~7717~77~r171f71TT?777777777fli7 il t7 ! l il l~ r71"~ ~''~ l~l ll ~ r i ~ l l ~? f r ?711! l ? t rT ~ r ~7 7 r l17777 EEEE~ ~ N EEEEE RRRR GGGG ~1' y ~ I~ N ~ R R G lr v : i~N N E R R G ¥ 11' EEEE I~ N N EEE, E RRRR G ¥ ~ !~ NN E R R G GGG Y ~ !~ N EE R R G G* Y EE~EE I~ N EEEEE R R GGG Y ~ PPPPPPPP RRRRRRRR IIIII! lilN N ti~illlTll' ! BBBSBBB~BB BBBEBBBBB8 EEEEEEEEEE EEEEEEEEEE EE EE EEEEEEEE EEEEEEEE EE EE EE EEEEEEEEEE EEEEEEEEEE ssSSSrSSS DD~DDDOD: SSSSSSS~ DOODODDD ss ....... / .... o'U SS ~ DO DD SS ~ OD DD SS ' DD DO $SSSSS OD OD SSSSSS DO DO SS DO OD SS DO OD SS DD DD SS DO DO SSSSSSSS DDDDDDDD SSSSS,SSS DDDDDDDO TT TT TT !.! MICRO.EILMED TT DS~ ---~/'~/~"_ ... tl?llrll 77 77 ;~;; 77 ;;;; 77 ;;;; 77 ;;;; 77 ;; 77 ;; 77 ;; 77 ;; 77 File _DUAi:£ES.USERO]F2INI.ES£~? (185~3,76,0), las [ENERGY]. The records ere vmri~ble length $iih im Job PRINT (gg) queue,~ to LPAO on 24-FEB-lg37 10:09 printer _LPAO:~ on 2¢-F::~.~-.1987 10:09 from queue t revisea, on :24-FE~B-1987 lO:Og', :is a 301 block sequential file aened by UIC plied (CR) carriage control. The longest record is 132 bytes. by user ENEqGY, UIC [ENERGY], under account VMS at oriority 100, started on Oo BE BBBBe, B,SB 7777777777777777 777777777777777~7777 777?77777777?777?7777777 Oigitz 1 Ec 7777777~ 7777 7~77 77 777777777777 777777 777777777777777777777777fTfT/Trt/TtTiIt777777177tllTf1711itlTrllT177 7777777777777777 f~717iTITt 71 ~lt}; 77 BBBEBBBBBB BBBBBBBBBB BBBBBBBB~B ENERGY SYSTEI~S TECHNI~LEGY TABULAR TRACE WELL NUMB 6R T~K556 COMPANY STANDARD ALASKA PREDUCTZON CO. ~ ~c~J~ s~ --- COUNTRY U. S. A. PROJECT Well: TAK556 Depth GR SN REP WEB RPM F CNTS OH M/M2 FT/HR KL B$ RPM 3150.00 3155.00 3160.00 3165.00 3170.00 3175.00 31(~0. O0 3185.00 3190.00 3195.00 3200.00 3205.00 3210.00 3215.00 3220.00 3225.00 3230.00 3235.00 3240.00 3245.00 3255.00 326 O. O0 3265.00 3270.00 3275.00 32'80~ 0'0 3285.00 32c;0.00 3295.00 3300.00 3305.00 3310.00 3315.00 3320.00 3325.00 3330.00 3335.00 3340.00 3345.00 3350.00 3355.00 3360.00 33,,65.00 3370.00 3375.00 3360.00 3365.00 3350.00 3395.00 34(;0.00 3405.00 3410.00 3415.00 44. 47. 43. 43. 41,. 43. 42. 40. 4'0, 39. 49. 62. 58. 97. 94. 89. 106. 124. 91. 102. 101. 93. 91. 94. 93. 3.97 3.53 2.85 1.52 !.49 1.50 1.50 1,52 1.59 1.59 1.51 1.63 '1.64 i.79 1.15 0.50 0.64 O. 74 2.23 1.61 1.28 1.56 1.5~, 1.56 1.36 1.49 3150.5 3155.5 3160.5 3165.5 3170.5 3175.5 3180.5 3185.5 3190.5 3195.5 847.2 19.9 3200.5 789.2 23.8 3205.5 933.3 21.4 3210.5 832.9 34.3 3215.5 734.4 42.1 32'20.5 750.1 49.~ 3225.5 908.9 61.1 3230.5 990.1 64.7 3235.5 856.2 71.3 3240.5 9'93.8 69.7,' ~ 3245.5 720.0 65.5 3255.5 97-3,0 62'.2 3260.5 705.0 68.9 3265.5 1005.9 67.0 3270.5 855.0 63.0 3275.5,~ 1016.6 66.0 3285.5 3'10,9 64.9 3290.5 196.2 69.2 3295.5 114.1 6!.1 3300.5 370.o 74.4 3305.5 582.8 68.0 3310.5 270.7 65.4 3315.5 428.9 59.5 3320.5 16.9 56.6 3325.5 207.8 56.0 3330.5 3t4.6 52.5 3335.5 30.7 53.3 3340.5 151.4 43.5 3345.5 176.0 60.4 3350.5 421.7 56.6 3355.5 533.7 57.2 3360.5 272,6 6t. 3 3365o 5 277. 2 62.8 3370.5 392.6 60.3 3375.5 567.9 59.1 3380.5 623.9 55.9 3385.5 577.3 55.5 3390.5 531.7 62.2 3395.5 545,0 63.6 34,30.5 321.6 59.I 3405.5 135.1 63.3 3410.5 325.4 63.1 3415.5 Eepth F 3150.00 3155.00 3160.00 3165.00 31 TO.O0 3175.00 3180.00 3t85.00 3190.00 3195.00 32 3205.00 3210o00 3215.0.0 3220.00 3225.00 3'23'0. O0 3235.00 3240.00 32.45.00 32~ 3160.00 3265.00 3270.00 3275.00 3280.00 3285.00 3290.00 3295.00 3300.00 3305.0,0 3310.00 3315.00 3320.00 3325.00 3330.00 3335.00 3340.00 3345.00 3350.00 3355.00 3360.00 3365~,00 3370"00 3375.00 3380.00 3385.00 3390.00 3395.00 3400.00 3405.00 3410.00 3415.00 Page 1 24-FEB-87 10:07 3~+20o00 234.9 3420.5 3420.00 ( ¢ ( ( ( ( ( ( ( Well: TAK556 Oe~th F GR CNTS Sk gMM/M2 3425.00 3430.00 3435.00 3440.00 3¢45.00 3450.00 3455.00 3460°00 3465.00 34?0°00 343'5.00 3480.00 3485.00 3490.00 3455.00 3500.00 35{35-00 3510.00 3515.00 35.20,00 3525,00 3530.00 3535.00 3540,00 3545.00 3550,00 3555'~'00 3560.00 3565.00 35'/0.00 3575.00 3580.00 3585.00 3500.00 3595.00 3600.00 36t~5.00 3610.00 3615.00 3620.00 3625.00 3630.00 3635.00 3640,0(} 3645.00 3650.00 3655.00 3660.00 3665.00 36'/0.0{3 36i'5.00 3680.00 3685.00 3650.00 88. 98. 109. ill. 111. 99. 110. 115. 70, 71. 121. 100. 71. 67. 100. 102. 132. 123. i23. 121. 122. 113. 99. 92. 121. 122. 120. 115. 110. 111. 113. 116. 122. 12!. 122. 109. 109. 10{3. lO0. $1. 91. 86. i02. 100. 1t9. 62. 65. 60. 55. 6.5. 94. 1.54 1.61 1.72 i.81 1.86. 1.71 1.lB 1.26 1.98 1.85 1.22 1.38 1.81 2.05 2.37 2.42 2.47 2.44 2.49 2.52 2.45 2.45 2 2.42 2.37 2.30 2.17 2.30 2.31 2.27 2.28 2.29 2.29 2,25 1.94 i.86 1.88 1.94 2.37 2.32 1.22 1.04 0.-~7 0.97 i.0~ 1.4S RDP FT/HR 477.7 534.4 441.8 447.3 239.5 552.0 342,7 365.4 465.9 452.2 531.4 369.0 222.1 220.0 153.0 30.6 38.8 45.6 124.3 107.6 117.3 127.6 149.1 145.0 56,8 0,1 0. ! 0.1 0.1 0.1 0,1 0.1 0,3. 0,1 0,1 0,1 0,1 WI: B KL BS 51.4 57.9 56.1 56.4 58.0 58.8 56.0 55 .g 60.6 64.0 62.8 60.2 61.1 60,5 65.0 61.2 55.0 54.8 55.4 5,6.0 49.9 22.5 20.7 19.0 17.8 20.6 15.4 13.0 19.0 11.4 11.9 11.9 11.1 12.6 17.7 15.5 17.3 ?.2,0 19.2 17,6 21.3 18.2 14.5 15.4 16.1 18.4 18.1 9.2 8.6 10.2 RPN Depth RPM F 34Z5.$ 3425.00 3430.5 3430.00 3435.5 3435.00 3440.5 3440.00 3445.5 3445.00 3450.5 3450.00 3455.5 3455.00 3460.5 3460.00 3465.5 3465.00 3470.5 3470.00 3475.5 3475.00 3480.5 3480,00 3485.5 3485.00 3490.5 3490.00 3495.5 3495.00 3500,5 3500,00 3505,5 3505,00 3510.5 3510.00 3515.5 3515,00 3520,5 3520.00 3530-5 3530,00 3535~5 3535.00 3540.5 3540.00 3545.5 3545.00 3550,5 3550.00 3SS'S-; 5 0 35,50.5 3560.00 3565.5 3565.00 3570.5 3570.00 3575.5 3575.00 3580.5 3580.00 3585.5 3585.00 3590,5 3590.00 3595.5 3595.00 3600.5 3600.00 3605.5 3605.00 3610.5 3610.00 3615.5 3615.00 3620.5 3620.0'0 3625.5 3625,00 3630.5 3630.00 3635.5 3635.00 3640.5 3640.00 3645,5 3645.00 3650.5 3650.00 3655.5 3655.00 3660.5 3660.00 3665.5 3665.00 3670.5 3670.00 3675.5 36'75.00 3680.5 3680.00 36~J5--':; 3685,00 3690.5 3690.00 24-FEB-87 Page 2 10:07 3695.~ 3695.00 Del: th 5R SN RCP W£ 5 RPM F CNTS gl- M/~2 =T/~ ~ KL qS RRM 37C0.0C 94. 1.56 3700.5 37G5.0C 97. 1.69 ~705.5 ~710.00 75. 1,47 3710.5 3715.0G 9=`. i.4~ 3715.5 3720.00 95. 1.41 3720.5 3725.00 97. 1.5C 3725.5 3730.00 69. !. 6--= 3'730.5 373 5. O0 74. i. 75 3735.5 3740.00 94. i.~1 3740.5 3745.00 1.54 3745.5 3750.00 1.44 3750.5 3755.00 7~. 1.~.4 3755.~ 376 O. 00 76. I. 4.~ 3760.5 3765.00 48. 1.23 3765.,5 37-/0.00 6~. 1.02 3770.5 37'/5. O0 6 5. O. 96 3775.5 3780.00 6'9. t.08 46.6 32.9 3780.5 3785.00 74. 1.1£ 61.3 38.6 3755.g 3750.00 88. 1.17 97.3 39.4 3790.5 3795°00 60. 1.14 156.6 42.7 3795.5 3810.90 121.9 ~3.2 3810.5 3815.00 107.~ 37.6 351~.5 3820.00 11t.6 36.3 3820.5 382~o00 93.4 43.4 3825.5 3830.00 I73.~ 35.7 38'30.5 3835.00 ~7. 105.7 42.~ 3~35.5 3840°00 $~o 134.~ 43.3 3840.5 3~45.00 ~54. 159o0 43.1 3845.5 3850.00 ~1. 106.8 44.8 3~50.5 3855.00 ~4. 3~.5 39.3 3855.5 38~0.00 7~. 95.3 ,40.5 3850.5 3865.00 75. '36r . 8 44.0 3865°5 3870.00 ~3. 76.6 43.5 3870.5 38'; 5000 79. 90.,4 ~2.0 3875.5 3880.00 45. 191.3 42.r~ 3890.5 3885.00 45. 269.6 ~7.0 3890.00 ~. 231./~ 36.:..~ 3890.5 38c~5.00 72. 90.7 ~,2.7 3895.5 39G0.00 79. 109.8 4~.! 3900.5 3~C5.00 ~3. 151 .O 42.0 3905.5 3910.00 57. _105.2 3915. O0 59. 77.6 43.5 3915.5 3920. O0 59. ~1.9 44.4 39Z0 .5 3925.00 ~4. 76.3 42.~ 3925.5 3930.00 63. 75.3 %2 .7 3930.5 3935.00 7~. 7( .9 &O.~ 3935.5 3'940.0C :33. 5 &O.& 3940.5 3 ~45. O0 55.9 25.9 3945.5 Oep'th F 1.33 1.23 1.53 1.05 0.96 1.32 1.35 2.31 1.04 3"/00.00 3705.00 3710.00 3715.00 3720.00 3725.00 3730.00 3735.00 3740.00 3745.00 3750.00 3755.00 3760.00 3765.00 3770.00 3775 3780.00 3785.00 3790.00 3795.00 3800,00 3805.00 3810.00 3815.00 3520.00 3825.00 3830.00 3635.00 3540.00 3845.00 3850.00 3855.00 3860.00 3865,00 3870.00 3875.00 3880.00 3885.00 3890.00 3895.00 3900.00 3905.00 3910.00 3515.00 39Z0.00 3925.00 3930°00 3935.00 ~40.00 39.4.5.00 Pag~ 3 24-F ~_-87 10:07 3970.00 58. 1.00 59.8 32.3 3970.5 C 3970°00 Well: TAK556 Depth GR SN RoP F CNTS (]}.M/M2 FT/HR 3975.00 96. 0.90 36.0 398 O. O0 71. .t. 05 a3.5 3985.00 63. 0.90 87.2 3990.00 43. 0.85 107.1 3995.00 58. 0.81 102.7 4000.00 68. 0.38 119.8 4005.00 69. 1.06 137.3 40~0.00 62. 1.2~ 183.8 4015.00 55. 0.81 128.2 4020.00 69. 0.86 88.8 4025. O0 60. O. 88 102.0 4030.00 58. 0.85 90.5 4035.00 62. O. 87 ~7.5 ~040. O0 61. 0.90 ~5.:3 4045.00 74. 0.89 95.1 4050.00 53. 1 15.2 4055.00 54. 105.1 40~0.00 60. 176.9 ~065.00 66. O. 37 82.3 40~ 0.00 72. 1.04 90.7 · 080. O0 70. Z. 08 97.7 408500.O 7 ~.. ~09 83.9 4090.00 7'3. 1.09 74.2 4095. O0 76. 1.10 108.4 4100~ O0 80. 1. il 9,0.9 '~lgS-O0 6 ~;' I;1':6 9.3'.7 4110.00 69. 1.37 56,9 4115.00 80. 1.74 ~120.00 92. 1.74 4125.00 91. 1.68 41-3 0.. O0 9~. 1.57 4135.00 90. 1.45 41'40. O0 83. 1.34 4145.00 83. 1.44 4150.00 89. 1.46 4155.00 89. 1.32 4L60.00 9~. 1.18 523.6 41~5,00 84. ~.10 488.3 41~0.00 71. 1. i0 466.4 4175.00 79. 1.1~ 445.9 4180.00 85. !.Z1 372.4 4185.00 82. 1.Z1 399.5 41~.00 88. I.. 25 349.7 4195.00 88. 1.36 6~0.9 42~0,00 89. 1.77 4205'~ O0 92. 1.91 304.9 42~0.00 83. 1.59 &90.7 4215.00 87. 1.19 328.7 4220.00 1.10 371.0 4225. O0 1.04 423 · 1 4230.00 76. 0.98 476.9 4235.00 58. 0.97 394.3 WEB RPM KLBS RPM 38.8 3975.5 37.9 3980.5 37.5 3985.5 37.3 3990.5 36.2 3995.5 36.0 4000.5 38.6 4005.5 39.2 4010,5 38.7 4015.5 38.8 4020.5 36.4 4025.5 28.3 4030.5 30.5 4035.5 30.0 4040.5 33,.4 4045.5 33.5 4050.5 28.7 4055.5 24.9 4060.5 26.3 4065.5 19,2 40~0.5 ,~qT¶, ~ _ 2'6.2 4080.5 24.7 4085.5 25.2 4090.5 24.9 4095.5 I4'.9= ..... 4t05,5 18.6 4110.5 4115.5 4120.5 4125.5 4130.5 4135.5 4140.5 4145.5 4150.5 4155.5 50.5 ~160.5 53.7 4165.5 48.9 4170.5 49.6 4175.5 51.6 4180.5 52.8 4135.5 49.8- 4190.5 ¢7.0 4195.5 48.9 4200.5 48.3 4205.5 47.2 4210.5 49.6 ~215.5 46.7 4220.5 45.1 4225.5 46.5 4230.5 45.7 4235.5 45.2 4240.5 Depth F 3975.00 3980.00 3985.00 3990.00 3995.00 4000.00 4005.00 4010.00 4015.00 4020.00 4025,,00 4030°00 4035.00 4040 .gO 4045.00 4050.00 4055.00 4060.00 4065.00 4070.0.0 4080,.00 4085.00 4090.00 4095.0'0 41 00.00 4110.00 4115.00 4120.00 4125.00 4130.00 4135.00 4140+00 4145.00 4150.00 .4155.00 41 60. O0 416~.00 4170.00 4175.00 4180.00 4185.00 4i 90.00 4195.00 4200.00 4205.00 4210.00 4215.00 4220.00 4225.00 4230.00 4235.00 4240.00 Page 4 24-F EB-87 10:07 4245.00 96. 1 .$1 153.7 4R.O 4245.5 4245.00 Well: TAK555 Depth F GR CNTS 4250.00 4255.00 4260.oe 4265.00 427o.o0 4275.o0 4280.00 4285.00 4290.00 4295.00 4300.00 4305.00 4.310.00 4315.00 4320.00 4325.00 4330.00 4335.00 4340.00 4345.00 4355.00 4360.00 4365.00 4370.00 4375.00 ~380900 4385.00 4390.00 4395.00 4400.00 4405°00 4410.00 4415.00 4420.00 4425.00 4430.00 4435.00 444 O. O0 4445.00 4450.00 4455.00 4460.00 4465.00 4475.00 4480.00 4485.00 4490.00 4455.00 4500.00 45(~5.0O 4510.00 4515.00 DhM/M2 77. 73. 84. 61. 82. 59. BO. 84. 74. ]'6. 79. 78. 77. 75. 78. 83. 74. 76. 82. 86. 76. 69. 71. 78. 79. 90. 96. 95. 118. 103. 79. 72. 11Io 125. 122. 116. 113. 121. 124. 12~. 124. 122. i28. 120. 131. 107. 137. 1 1.12 1.16 1.18 1.28 1.31 1.29 1.1i 1.04 1.08 1.08 1.09 1.09 1.06 1.04 1.13 1.ZT 1 1.52 1.54 1.68 1.62 1.34 1.11 1.12 :1..22 1.23 1.50 1.58 1.56 t.79 1.69 1.57 1.4.4 1.45 2.33 2.22 2.14 2.i6 2.12 1.99 2.05 2.02 1.9~ t.98 1.94 !.99 2.14 RDP FT/H~ 354.1 452..9 238.4 290.2 347.7 351.2 196.1 5.:)1.9 2~4.0 363.0 350.3 259.3 133,9.6 166.2 125.7 262.8 287.7 281.5 139.7 254.4 260.3 529.7 386.3 409.t 298 .'~ 304.1 290.8 233.B 265.5 194.5 143.3 322.7 268.3 155.~ 98.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0,6 KLBS RPM Depth RPM F 14.4 4250.5 4250.00 7.5 4255.5 4255.00 32.6 4260.5 4260.00 39.3 4265.5 4265.00 39.8 4270.5 4270.00 39.8 4275.5 4275.00 42.6 4230.5 4280.00 43.0 4285.5 4285.00 43.2 4290.5 4290.00 43.2 4295.5 4295.00 48.8 4300.5 4300.00 49.';. 4305.5 4305.00 52.5 4310.5 4310.00 47.2 4315.5 4315.00 49.5 4320.5 4320.00 51.6 4325.5 4325.00 49.4 4330.5 4330.00 47.5 4335.5 4335.00 49.6 4340.5 4340.00 40.9 4345.5 4345.00 54.7 4355.5 4355.00 4'2.8 4360.5 4360.00 50.6 4365.5 4365.00 53.0 4370.5 4370.00 55.3 4375.5 4375.00 ~6.'~ ~:380.5 ' '4380.00 53.9 4385.5 4385.00 45.5 4390=5 4390.00 41.4 4395.5 4395.00 52.6 4400.5 4400.00 ~7.5 4405.5 4405.00 55.6 4410.5 4410.00 56.1 4415.5 4415.00 55.1 4420.5 4420.00 38.1 ~425.5 4425.00 58.2 4430.5 4430.00 45.3 4435.5 4435.00 41.5 4440.5 4440.00 46.1 4445.5 4445.00 49.8 4450.5 4450.00 48.5 4455.5 4455.00 47.5 4480.5 4460.00 51.0 4465.5 4465.00 49.8 4470.5 4470=00 47.2 ¢475.5 4475.00 51.0 44.90.5 4480.00 48.6 44~5.5 4485.00 47.~ 4490.5 4490.00 50.4 4495.5 4495.00 51.2 4500.5 ~4500.00 51.8 4 -~0~ 5 4505.00 49.0 4510.5 4510.00 49.5 4515.5 4515.00 24-F EB-87 Page 5 10:07 4520.00 50.3 4520.5 4520.00 C well: TAK555 De~th 4525.00 4530.00 4535.00 4540.00 4545.00 4550.00 4555.00 4560.00 4565.00 4570.00 4575.00 4580.00 4585.00 .4590o00 4595.. O0 4600.00 4605.00 4610.00 4615.00 4620. 00 GR CNTS OPM/M2 115. 2.25 139. 2.2g 132. 2.22 122. 2.15 115. 2.17 113. 2.14 116. 120. 2.17 132. 2.30 131. 2.22 120. 2.41 103. 2.20 136. 2.41 t32. z.4o 127. 2.50 100. 2.44 9g. 2,3g 107. 2.50 110. 2.41 133. 4630,00 130. 1.79 4 63 5 ' 00' 12 3- 1.63 4640.00 141. 1.40 4645.00 133. 1.36 4650.00 127. 1.70 465'5.00 1'26', .... '2.86 4660.00 127. 2.96 ~665.00 133. 2.89 ~670.00 1~0. 3.02 4675.00 143. 2.77 4680.00 126. 2.90 4685.00 156. 2.56 ~690.00 12~. 4695.00 1~7. 4700.00 ~33. 2.32 4705.00 132. 2.~6 ~710.00 136. 3.27 4715.00 141. 2.87 4720.00 155. 1.16 4725.00 141. 1.73 4730.00 1~4. 4735.00 147. 4740.00 161. 2.92 4745.00 2.64 4750.00 4755.~0 4760.00 4765.00 ilO. 4770.00 135. 2.37 4775.00 132. 2.36 4780.00 141. Z.O0 4785.00 108. 47S0.00 i00. ROP FT/HR KL 85 106.7 50.7 106.7 52.6 106.7 48.9 106.7 47.9 106.7 48.6 t06.7 49.4 106.7 46.5 106.7 43.8 106.7 43.8 RPN 4525.5 4530.5 4535.5 4540.5 4545.5 4550.5 4555.5 4560.5 4565.5 4570.5 4575.5 45B0.5 4585.5 4590.5 4595.5 4600.5 4605.5 4610.5 4615.5 46:20.5 Depth F 4525.00 4530.00 4535.00 4540.00 4545.00 4550.0O 4555.00 4560.00 4565.00 4570.00 4575°00 4580.00 4585.00 4590.00 4595o00 4600°00 4605.00 4610.00 4615.00 46~0_00 4630.5 4-630*00 .................. 4635.5 130.0 50.0 4640.5 4640,00 140.0 55.0 4645.5 464'5,00 160.0 50.0 4650.5 4650.00 23:8.,4 50.6 4660.5 46.60,,00 2t0.0 59.9 4665.5 4665.00 139.2 56.~ 4670.5 4670.00 110.0 55.0 ~75.5 4675.00 112,.0 53.0 4680.5 4680.00 108,5 50.0 4685.5 4685.00 110.0 52.0 4690.5 4690.0.0 8.3 45.1 .4695.5 4695.00 15.0 71.9 4700.5 4700.00 t4.1 65.1 4705.5 4705.00 83.1 30.4 4710.5 4710.00 84.1 33.8 4715.5 4715.00 87.9 36.3 4720.5 4720.00 98.3 34.1 4725.5 4725.00 113.0 2.6.4 4730.5 4730°00 1.17.5 36.8 4735.5 4735.00 4740.5 4740.00 4745.5 4.745.00 4750.5 4'/50.00 4755.5 4755.00 139.3 34.5 ~760.5 4760.00 1~+0.7 36.0 ¢765.5 4765.00 146.3 33.0 4770.5 4770.00 120.2 3~.7 4775.5 4775.00 119.9 35.3 4780.5 4780.00 13~.2 34.2 4785.5 4785.00 27~.7 29.5 4790.5 4790.00 Page 6 24-F EB-87 10:07 ~+7c25., O0 92° 3.2'/ 2.2.6 4795.5 4795°00 (- Depth GR SN RaP wcB RPM F CNTS gPM/M2 FT/HR KLB$ RPM 4800.00 74. 3.$1 211.9 25.0 4800.5 4805.00 102. 4.04 2~4.0 15.1 4805°5 4810.00 66. 3.2~ 159.4 14.5 4810.5 4811.00 73. 1.62 571.0 16.7 4815.5 4820.00 77. 1.45 103.0 20.0 4820.5 4825.00 107. 1.26 103.0 20.0 4825.5 ~830o00 120. 2.a0 103.0 20.0 4830.5 4835.00 120. 1.73 103.0 20.0 ~835.5 4840.00 109. 2.07 103.0 20.0 48~0.5 4845.00 9~. 2.34 196.6 21.2 4845.5 ~850.00 128. 3.28 91.7 15.5 4850.5 4855.00 114. 2.9~ 79.9 22.3 4855.5 1860.00 117. 2.~1 120.7 21.1 4860.5 4865.00 127. 3.26 120.7 24°2 4865.5 4870.00 124. 3.3E 86.0 27°8 4870.5 4875.00 113. 2.31 49.0 28.9 ¢875°5 4880.00 110. 2.37 148.7 18.4 48'80.5 4885.00 105. 2.54 96.5 20.6 4885.5 4890.00 126. 2.63 92.4 23.3 4890.5 4895.00 121. 2.78 62.9 lg.6 4895.5 4905.00 121. 3.07 71.3 25.4 4905.5 491.0.00 105. 3.24 65°9 2'3.9 4910.5 4915.00 132. 3.2~ 63.1 27.0 4915.5 4920.00 114. 2.84 73.5 2~.1 4920.5 4925.00 130. 2.62 162o6 22.2 4925.5 '~930.00 110. 3,'06 ~-i-L4 22.i 4935.00 119. 3.2C 81.0 20.7 4935.5 4940.00 127. 3.2~ 88.6 22.5 4940.5 4945.00 116. 3.~6 70.6 22.4 4945.5 4950.00 136. 3.30 79.5 24.0 ~950.5 4955.00 136. 3.2~ $3.7 23.6 4955.5 4960.00 133. 3.25 79.7 24.3 4960.5 4965.00 125. 3.17 74.2 RO.7 4965.5 4970.00 127. 2.92 117.6 23.2 4970,5 ~925.00 1~3. 2.9t 79.5 23.9 4975.5 4980.00 132. 2.84 95.8 20.2 4980.5 4985.00 109. 2.92, 75.1 20.1 4985.5 49~0.00 12~o 3.00 8~.9 20.3 4990.5 4995.00 137. 2.92 85.] 21.5 4995.5 5000.00 136. 2.32 79.3 22.5 5000.5 50C5o00 142. 3.01 78.7 ~3.$ 5005.5 5010.00 I27. 3.06 70.7 22.5 5010.5 5015.00 122. 3.09 72.9 19.3 5015.5 5020.00 1~8. 2.95 77.8 20.0 5020.5 5025.00 124. 2.8. 112.9 24.5 5025.5 5030.00 11'7. 2o7~ 119.3 21.1 5030.5 5035.00 13~. 3.25 136.7 23.9 5035.5 5040.00 1SD. 3.60 70.~ Z2.7 5040.5 5045.00 $4.~ 26.8 5045.5 5050.00 65.0 22.2 5050.5 5055.00 76,5 22.9 5055.5 50~0.00 12~. 1.70 199.~ 19.9 5060.5 50~5.00 112. 2.2~ !30.6 21.0 5065.5 Oepth F 4800.00 4805.00 4810.00 4815.00 4820.00 4825.00 4830.00 ~835.00 4840.00 4845.00 4850.00 4855.00 4860.00 486500,0 4870.00 4875.00 4880.00 4885.00 4890.00 489~.00 "~ 00~0 4905.00 4910.00 4915.00 4920.00 4925.00 4930.5 4930.00 4935.00 4940.00 4945.00 4950.00 4555.00 4960.00 4965.00 4970.00 4975.00 4980.00 4985.00 4990.00 4995.00 5000.00 5005.00 5010~.00 5015.00 5020.00 5025.00 5030.00 5035.00 5040.00 5045.00 5650.00 5055.0O 5060.00 5065.00 Pac_e 7 24-F EB-87 10:07 5070.00 122. 2°22 21~o6 20°8 5070.5 5070,,00 C C Well: TAK556 Oe~th F 5075.00 5080.00 5085.00 5090.00 50g5.00 5100.00 5105.00 5110.00 5115.00 5120.00 5125-00 5130.00 5135.00 5140.00 5145.00 5150.00 5155.00 5160.00 5165.00 51].0.00. 519 5185.00 5190.00 5195.0,0 5200.00 5 o5 oo 5210.00 5215.00 5220.00 5225.00 5230.00 5235.0,0 5240.00 5245.00 5250.00 5255.00 5260.00 5265.00 5270.00 5275.00 5280.00 5285.00 5290.00 52g5.00 5300.00 5305.00 5310.00 5315.00 5320.00 5325.00 5330.00 5335.00 5340.0O GR CNTS 105. 117. 126. 112. 120. 113. 114. 106. 128. 127. 128. 126. 131. 116. 123. 139. 132. -1-21. 126. 137. 142. 106. 100. 153. 153. 153. 1.53. 141. 121. i21. 126. 126. 113. 95. 85. 87. 100. i00. 83. 95. 100. 105. 133. I1B. II4. 111. 9'i'. 96. SH RDP W~ 'OHH/N2 PT/HR KL 2.12 182.5 2.36 160.5 2.56 119.8 2.77 120.8 2.83 97.4 2.94 lOB.O 2.92 70.6 2.96 129.5 2.96 115.3 3.02 I17.8 3.07 110.0 3.08 95.6 3.05 107.7 3.07 96.4 3.06 96.9 3.05 86.6 2.96 104.0 2.91 118.1 2.98 92.8 3.01 96.8 3'03 3.18 82,7 3.24 79.5 127.2 116.6 3 %9 1T, i.. 9 3.54 127,3 3.54 129.5 3.53 200.3 3*53 196.9 3.49 127.2 3.42 104.3 3.52 113.5 3.67 194.7 3.83 364.0 3.14 244.9 2.11 317.6 2.41 12.7 5.26 464.9 2,.90 503.1 2.02 559.1 2.05 422.5 2.09 350.0 2.13 165.7 2.04 436.2 2. Ol 462.3 1.53 212.2 l. ZO 263.2 1.89 370.0 2.64 107.3 2.29 3~+7. I 2.33 184.9 2.,~ 264.4 B RPN Depth BS RPN F 20.6 5075.5 5075.00 21.2 5080.5 5080.00 21.2 5085.5 5085.00 24.6 5090.5 5090.00 22.3 5095.5 5095.00 26.2 5100.5 5100.00 25.7 5105.5 5105.00 23.7 5110.5 5110.00 22.3 5115.5 5115.00 22.4 5120.5 5120.00 28.1 5125,5 5125.00 27.1 5130.5 5130.00 27.2 5135.5 5135.00 27.7 5140.5 5!4,0,~. O0 28.6 5145.5 51,45.00 27.5 5150.5 5150.00 28.7 5155.5 5155.00 26.7 5160.5 5160.00 27.0 5165.5 5165.00 21.5 51.70,5 5170.00 22.0 5180.5 5180,00 Z 3.6 5185.5,, 51, &'Sa%0 23.5 5190.5 5190.00 20.8 5195.5 5195.00 Z1.2 5200.5 .5200..0 0 3'5.3 5205.5 F2~'S', O0 37.8 5210.5 5210.00 35.7 5215.5 5215.00 32.8 5220.5 5220.00 33.6 5225.5 5225.00 37.6 5230.5 5230.00 36.5 5235.5 5235.00 37.7 5240.5 5240.00 34.3 5245.5 5245.00 22.3 5250.5 5250.00 25.0 5255.5 5255.00 27.7 5260.5 5260.00 61.3 5265.5 5265.00 50.2 5270.5 5270.00 44.5 5275.5 5275.00 39.6 5280.5 5280.00 41.8 5285.5 5285.00 42.5 5290-.5 5290.00 30.4 5295.5 5295.00 33.5 5300.5 5300.00 42.2 5305.5 5305.00 41.7 5310.5 5310.00 40.0 5315.5 5315.00 41.0 5320.5 5320.00 45.1 5325.5 5325.00 45.5 5330.5 5330.00 45.8 5335.5 5335.00 4~.~ 5340.5 5340.00 Page 8 24-F EB-B 7 10:07 5345.00 117o 3.3-; 63.~ 50.8 5345.5 5345.00 C C well: TAK556 Page 9 24-F :'8-87 10:07 Depth GR SH ROP F CNT$ O~M/M2 =T/HR 5350.00 105. 3.39 170.5 5355.00 122. 3.,62 149.6 5360.00 120. 3.80 127.7 5365.00 121. 3.55 99.7 5370.00 107. 3.35 194.1 5375.00 107. 2.70 219.0 5380.00 129. Z.d5 193.4 5385.00 109. 3.35 168.6 5390.00 109. 3.95 88.8 5395.00 128. 3.91 131.1 5400.00 122. 3.90 154.0 5405.00 112. 3.90 1Z9.4 5410.00 125. 3.85 134.7 5415.00 134. 4.35 142.8 5420.00 126. 4.43 134.2 5425.00 146. 4.56 10.8.2 5430.00 137. 4.60 115.2 5435.00 105. 4.32 124.7 5440.00 128. 3.23 125.5 5445...00 * 144. - · '3.14 116.~ 140,, 3.99 119.7 5460.00 3~, 19 1 5465.00 1.98 119.0 54.?0.00 2.03 126.2 5475.0:0 121. Z. 77 117 5~'80~' 0~0 ~1'~1 8. 2. B g 123'. 0 5485.00 122. 4.36 113,1 5~g0. O0 107. 3.72 5500.00 99. 3.08 195 55G5.00 106. 3.03 213.6 5510.00 105. 2.98 200.0 5515.00 102. 2.92 2Z5.4 5520.00 2.30 381.2 5525.00 2.17 357.7 55~0.00 2.15 359.2 5535. O0 100. 2.15 311.2 5540.00 113. 2.38 355.t 5545.00 118. 2.8t 237.8 5550.00 1OZ. 3.00 196.5 5555.00 103. 2.69 353.1 5560.00 103. 2.~7 305.2 5565.0,0 104. 2.52 314.5 5525.00 2.16 330.1 5580.00 89. 2.23 386.8 55%~.00 90. 2.05 314.7 55g0.00 Z.OG 401.1 5595.00 Z.O~ 404.5 56fl0.00 106. Z.45 ~gl 5605.00 113. 3.0~ 250.9 5610.00 1il. 3.63 5615.00 3.0~ 195.I WEB RPN Depth KLB$ RPN F 50.2 5350.5 5350.00 46.3 5355.5 5355.00 41.2 5360.5 5360.00 39.0 5365.5 5365.00 36.8 5370.5 5370°00 34.8 5375.5 5375.00 33.3 5380.5 5380.00 37.1 5385.5 5385.00 31.8 5390.5 5390.00 46.8 5395.5 5395.00 47.9 5400.5 5400.00 48.5 5405.5. 5405.00 49.6 5410.5 5410.00 4804 5415.5 5415000 56.3 5420.5 5420.00 56.1 5425.5 5425-00 54.7 5430.5 5430.00 55.2 543505 5435.00 56.3 544.0.5 5440.00 55~.7 544.5.5 5445.00 54.7 5455.5 53~0.~: 5460.5 54.0 5465.5 5465.00 56.2 5470.5 547'0*00 56.5 5475.5 5475.00 36.5 5485.5 5485.00 47.8 5490.5 5490.00 48.9 5495.5 5495.00 47.2 5500.5 5500.00 47.5 5505.5 5505.00 48.5 5510,,5 5510.00 49.0 5515.5 5515.00 41.7 5520.5 5520.00 34.9 5525.5 5525.00 27.7 5530.5 5530.00 32.4 5535.5 5535.00 37.1 5540~5 5540.00 45.2 5545.5 5545.00 4,6.8 5550.5 5550.00 44.0 5555.5 5555.00 40.4 5560.5 5560.00 38.8 5565.5 ~.5565.00 35.8 5570.5 5570.00 32.0 5575.5 5575.00 18.3 5580.5 5580.00 24.0 ~5~5.5 5585.00 g~.l 5590.5 5590.00 32.6 5595.5 5595.00 33.7 5600.5 5600.00 53,9 5605.5 5605.00 55.2 5610.5 5610.00 52.I 5615.5 5615.00 ¢ ¢ ( ( ( ( ( -( 5620o00 5620.5 5~0o00 W~ll: TAIC3S 6 Del: "ch G R $ N 20 P W£ B R P Iq D e p'th F CNT $ OH M/,,12 FT/H R KL _n $ RPM F 5625.00 85. 2.14 2.35 3.10 3.40 2.88 2.58 2.77 2.12 2.09 1.96 2.4,6 3.15 3.56 3.42 2°95 2.63 2.95 3.32 3.69 4.51 3.42 3.02 3.26 3.21 3.27 3.34 3.0~' 3.30 3.49 3.55 3.95 4.2% 3.~3 2.81 2.03 2.14 · 4.9~ 2.98 3.86 7.17 ~,.97 3,20 3.35 3.55 3.50 3.~6 3.75 5630.00 5635.00 5640.00 5645.00 5650.00 5655.00 5660.00 5665.00 5670.00 56'/5.00 5680.00 5685.00 5650.00 5655.00 5700.00 5705.00 5710.00 5715.00 5720.00 5725.00 5735.00 5740.00 5745.00 5750.00 5755.00 576 O. O0 57~5.00 5770.00 5775. O0 5780.00 5785.00 5750.00 5795.00 5800.00 58l]5.00 5810. O0 5815-0'0 5820.00 5a25.oo 5830.00 5835.00 5840.00 5845.00 5850.00 5855.00 58~0.00 58~5.00 .5870.00 5880.00 5890.06 84. 85. 95. 121. 108 · 88. 91. 78. 89. 98. 100. 106. 105. 102. 104. 80. 107. 110. 118. 87. 105. · 106.' 121. 115. 11~. 101. 105. 103. 102. 105 o 72. 70. 69. 87. 77. 89. 58. 103. 106. t05. 97. 103. 130. 129. 379.5 377.6 373.4 201.4 213.8 327.0 264.1 310.1 353.5 354.7 299.1 373.1 175.4 179.5 163.5 216.1 368.8 247.3 220.5 198.5 168.4 lOS.1 132.9 315.8 212.4 285.4 226.8 173.8 332.9 159.3 232.4 165.9 197.6 112.9 86.4 116.9 330.4 297.5 255.7 248.2 12.4 330.7 257.4 193.1 ~.4 261.3 2~2.7 176.7 149.7 133.4 i40.3 144.5 41.2 31.8 36.7 43.9 51.1 49.3 47.8 49.3 35.2 33.1 12.4 28.7 52.3 53.9 56.1 54.6 45.6 42.6 51.3 53.6 54.1 54.8 49.8 51.2 51.4 53.1 47.5 32.4 32.2 35.1 33.7 38.1 37.1 33.4 30.4 30.1 33.5 29.3 40.8 39.4 28.3 37.1 46.1 52.1 49.3 49.8 37.~ 42.7 44.2 44.4 46.1 5625.5 5630.5 5635.5 5640.5 5645.5 5650.5 5655.5 5660.5 5665.5 5670.5 5675.5 5680.5 5685.5 5690.5 5695.5 5700.5 5705.5 5710.5 5715.5 5720.5 5730.5 5735.5 5740.5 5745.5 5750.5 575'5.5~ 5760.5 5765.5 5770.5 5775.5 5780.5 5785.5 5790.5 5795.5 5800.5 5805.5 5810.5 5815.5 5820.5 5825.5 5830.5 5835.5 5840.5 5845.5 5850.5 5855.5 5860.5 5865.5 5870.5 5875.5 5880.5 5885.5 5890.5 5625.00 5630.00 5635.00 5640.00 5645.00 5650.00 5655.00 5660.00 5665.00 5670.00 567:5.00 5680.00 5685.00 5690.00 5695. O0 5700.00 5705.00 5710.00 5715.00 57~0.00 57~0.0o 57..%5.00. 5740.00 5745.00 5750.00 5 I~55.00 5760.00 5765.00 5770.00 5775.00 5780.00 5785.00 5"/90~00 5795.00 5800.00 5805.00 5810.00 5e: 5.oo 5830.00 5835.00 ~0,.00 ~45,oo ~50.00 . 55.oo ~65.00 ~870.00 ~875.00 t880. O0 $85.00 890.00 Page 10 24-FEB-87 10:07 5855°00 113. 91.4 45.9 5895.5 5895°00 C Well: 7AK556 De~th F 5960.00 5905.00 5910.00 5915.00 5920.00 5925.00 5930.00 5935.00 5940.00 5945.00 5950.00 5955.00 5960.00 5965.00 59'/0.00 5975000 5980.00 5985,00 5990.00 5995, 6010..00 6015000 6020.00 60250,00 6035.00 604,00 O0 6045.00 6050.00 6.055.00 6060.00 6065°00 6070.00 6075.00 6080.00 6085.00 60gO. Q0 6095. O0 6100.00 6105.00 6110.00 6115,06 6120:00 6125.00 6'13 O. 00 6135.00 6140.00 6145.00 6150.00 6155.00 6160.00 6165.00 GR CNTS 111. 120. 119. 131. 112o 102. 133. 136. 115. 108. 113. 120. 127. 130. 144.,,, 125. 149. 126. 139. 126,. 130. 95. 145. 116. 'I'32'; 137. I47. 132. 155. 153. 146. 131. 120. 128. 133. 135. 116. 98. 104. 93. 92o 97. 103. 1(]9. lC)2. 120. 106. 94. 123. SN RDP WEB DP N/M2 FT/HR KLBS 3.88 12.5.1 46.4 4.07 88.9r 46.6 4.32 74.8 46.4 4.52 ?6.4 50.9 4.24 110.1 50.5 3.96 133.4 47.2 4.32 99.3 ~8.1 4.41 89.9 50.1 4.46 95.3 50.8 4.30 75.~ 52.0 4007 103,6 47'.5 4.13 88.1 46.9 4.41 66.6 /*2.8 ~4.38 B4.1 43.3 4.50 56.5 45.6 4.4'7 68.4 47.9 4.27 62.0 49-1 ~.41 85.9 46.8 ..4.,.~0 6.2 . 5 47.6 40.i 60-4 ~,.1G 143.9 ~4.2 4.76 55.3 45'.2 4.1,5 134.9 44.6 ~'~"~3 92;-6 ~T~;' I ' 4.69 57.3 41.3 4.63 56.4 42.6 Z.B9 45.0 42 3.70 82.6 50.0 3.50 59.3 51.8 3.79 59.6 52.0 3.88 57.4 57.0 3.70 50.6 59.2 4.57 49.3 58.7 4.28 43..1 51 4.85 47.4 59'6 3.34 ~Z5.8 57.0 2.29 3t7.5 47-,. 9 2.~6 246.4 44.3 2.94 266 .9 53.5 2.60 258.9 52.1 2.39 262.6 2.77 237.5 50.8 3.Z4 151.6 57.1 2.57 273.5 47.4 3.70 125.7 55.7 2.61 243.2 48.1 2.0~ 424.3 2.1~ 374.9 40.4 Z.7~ 294.3 46.8 RPM RPN 5900.5 5905.5 ., 91o.5 5915.5 5920.5 ~925.5 930.5 935,5 940.5 945.5 950.5 955.5 960.5 o5 5 7-5.. 5 5 ,85.5 5.5 O. 5 5.5 5 5.5 60 i.5 60 5 60~ i.5 60 5 60 i.5 60 .5 60 60 t.5 609 5 610 5 610 5 611( 61~( 5 61 5 6130 5 6135 5 6140.5 6145~-5 6150.5 6155.5 6160.5 5165.5 Depth F 5900.00 5905000 5910.00 5915.00 5920.00 5925.00 5930°00 5935000 5940.00 5945.00 5950.00 5955.00 5960.00 596~5.00 ~:9 irS',,, 0 0 5975~00 5980.00 5985.00 5990.00 60 ~O O0 60 tS,O0 60ZO. O0 602~5.00 6035.00 6040.00 6045.00 6050.00 60 55. O0 6060.00 6065000 6070.00~ 6075.00 6080.00 6085.00 6090.00 6095.00 6100.00 6105.00 6110.00 61 6120.00 6125.00 6130.00 6135.00 6140.00 6145.00 6150.00 6155.00 6160.00 6165.00 Page 11 24-FEB-B 7 10:07 ( ( ¢ ( ( ( C 6170.0~ 110. 3.17 135.~ ~5.1 6170.$ 6170o00 Well: TAKD56 6175.00 6180.00 6190.00 6195.00 6200.00 6205.00 6210.00 6215.00 6220.00 6225.00 6230.00 6235.00 6240.00 6245.00 6250.00 6255.00 626o.oo 6Z65.0G 6270.00 62] 5. 00 6255.00 6250.00 6295. O0 6300.0,0 O0 6310-00 6,31 So O0 6320.00 6325.00 6330.00 6335.00 6340.00 6345.00 6350.00 6355.00 6360.00 63(55.00 632 O. O0 6375.00 6380.00 6385.00 63c. 0.00 63cj5. O0 6400.00 6405.00 6410.00 6415.00 6420.00 6425.00 6430.00 6435.00 6440.00 Depth GR SN F CNTS Or, M/M2 ROP DT/H~ WEB KL)S 111. 3.15 22~.6 54.0 92. 3.25 155.4 56.1 100. Z.73 234.4 54.8 102. 2.79 329.0 51.7 120. 3.80 229.8 53.6 117. q..lO 102.6 57.5 133. 3.65 175.2 ~5.2 97. 3.32 101.1 56.3 107. 4.02 94.7 56.0 103. 3.90 12&.1 56.0 108. 3.7~ 93.0 60.5 113. 3.85 81.9 54.5 118. 3.94 88.9 55.4 121. 4.36 76.0 56.5 135. 4.38 67.0 45.4 142. 4.41 69.3 46.0 121. 4.44 68e0 46.2 131. 4.47 66.5 46.1 ~1. 4.4~ 67.1 50.2 146. 4~, 63 59.3 4,6.5 141. 4.72 109.1 46.2 120. ,%. 51 56.3 42 130. 4.4~ 63.0 44.0 121. ~.52 59.4 45.5 i21. ~.45 71.9 45.2 133, · "- * 4,29 '6'4',6 ~7'~.1' 129. 4.36 64.4 46.1 116. 4.35 58.0 46.4 137. 4.3~ 62.1 45.3 123. 4.4~ 57.2 44.8 123. 4.47 65.8 44.5 132. 4.20 57.5 45.7 121. 4.27 46.5 14.1 138. 4.41 212.9 42.1 121. 4.54 137.5 45.0 141. 4.57 94.3 41.2 131. 4.55 154.4 45.6 135. 4.50 143.7 47.2 134. 4.49 151.4 45.2 124. 4.34 !54.4 45.4 127. 4.35 !44.8 45.6 i21. 4.12 147.$ 45.2 125. z+.Oa 234.7 44.5 126. ~+.51 149.8 45.6 124. 4.55 138.2 45.3 144. 4.67 139.1 50.0 157. 4.15 121.9 f2.2 151. 3.56 101.5 50.8 143. 3.60 89.3 109. ~.~7 158.9 51.2 120. 4.27 162.0 44.2 117. ~.!~ 141~. 6 46.9 121. :~. 17 13°. .O ~7. C RPM Depth RPM F 6175.5 6175.00 6180.5 6180.00 6185.5 6185.00 6190.5 6190.00 6195.5 6195.00 6200.5 6200.00 6205.5 6205.00 6210.5 6210.00 5215.5 6215.00 6220.5 6220.00 6225.5 6225.00 6230.5 6230.00 6235.5 6235.00 6240.5 6'240.00 6245.5 6245.00 6250.5 6250.00 6255.5 6255.00 6260.5 6260.00 6265.5 6265.00 62 70 ~5 62 70. O0 6280.5 6280.00 6285.,5 6285.00 6290.5 6290.00 6295.5 6295.00 6300.5 6300.00 6305.5 6305.00 6310.5 6310.00 6315.5 6315.00 6320.5 6320.00 6325.5 6325.00 6330.5 6330.00 6335.5 6335.00 6340.5 6340.00 6345.5 6345.00 6350.5 6350.00 6355.5 6355.00 6360.5 6360.00 6365.5 6365.00 6BTO.5 6370.00 6375.5 6375.00 6380.5 6380.00 6385.5 6385.00 6390.5 6390.00 6395.5 6395.00 6~'00- 5 6400.00 6405,5 6405.00 6410.5 6410.00 6415.5 6415.00 6420.5 6420.00 6425.5 6425.00 5430.5 6430.00 6435.5 6435.00 6440.5 6440.00 Page 12 24-F EB-87 10:07 6t~/, 5. O0 120. a'-37 23~+- e ~+5.0 64~5.5 644.5.00 ¢ ¢ ¢ ¢ ( ¢' ¢ ( ( C ( ¢ ( ( Well: TAK556 Oe~th GE SN F CNTS OH 6450.00 122. 6455.00 127. 6400.00 119. 6465.00 122. 6470.00 124. 6475°00 126. 6480.00 131. 6485.00 103. 6490.00 128. 6495.00 120. 6500.00 120. 65(;5.00 1.~4. 6510.00 130. 651,5.00 127. 6520.00 133. 6525.00 132. 6530.00 118. 6535.00 131. 6540.00 123. 6545.00 117. 655 O. 00 ,i.1.9 6~'55.00 lO'?. 6560.00 123. 6565.00 136. 6570.00 129. 65'/5.00 108. 6580,~0'0 t17. 6585.00 121. 6590.00 I1 3. 6595.00 II2. 6600.00 133. 6605.00 118. 6610.00 118. 6615.00 124. 6620.00 132. 6625.0(; 130. 6630.00 111. 6635,00 116. 6640. O0 122. 6645.00 129. 6650.00 129. 6655.00 119. 6660.0(; 6~. 6665.00 69, 6670.00 60. 6675. O0 70. 6680.00 69. 6685.00 77. 6690.00 86. 6695.00 67(;0.00 129. 6705.00 139. 6710.00 163. 6715.00 142. M/M2 4.49 4.52 4.53 4.41 4.38 4.35 6.51 4.02 4.07 3.83 4.16 4.15 4.10 4.10 4.35 4.23 4.20 3.68 3.88 3.94 4.11 4'a18 4.75 4.09 4.14 3.9'6 3.81 3.68 3.73 3.96 4.02 4.10 4.~3 2.3.6 1.4C 1.26 1.36 1.4c, i 1.76 2.75 2.85 3.95 4.02 RDP FT/HR 137.7 137.5 140.9 144.0 145.5 135.4 129.9 139.4 106.4 217.8 163.7 219.7 156.7 163,,0 142.3 97,3 80.9 80.8 75.1 84.2 105.5 95.5 70.8 74.0 76,3 7'6 .t 50.1 72.8 69.0 73.9 60.5 82.3 83..2 86.2 93.8 99.8 75.9 90.4 71.6 ~1,6 60.8 209.1 31r6.3 363.2 363,7 352.2 30~.9 192.,1 130.1 114.7 ~.0.6 47,8 WI28 RPM Depth KLBS RPM F 45.9 6450.5 46.2 6455.5 46.6 6460.5 44.7 6465.5 46.6 6470.5 45.5 6475.5 43.6 $480.5 46.7 6485.5 51,.1 6490.5 43.7 6495.5 46.6 6500.5 45.g 6505.5 46°0 6510.5 44.3 6515.5 51.8 6520.5 20,3 6525.5 25.1 6530.5 26.8 6535.5 26.0 6540.5 24.5 6545 23.0 6555.5 26.0 6 S60a 5 25.4 6565.5 26.2 6570.5 1'8.2 6575.5 19.7 6585.5 19.6 6590.5 28.5 6595.5 24.9 6600.5 19.5 6605.5 21.9 6610.5 26.8 6615.5 28.4 6620.5 23..3 6625,.5 24.6 6630.5 ~6.5 6635.5 25.0 6640.5 26.0 6645.5 26.8 6650.5 29.0 6655.5 23,5 6660.5 19,7 6665.5 15-3 6670.5 17.8 6675.5 17.9 6680.5 23.3 66~5.5 29.6 6690.5 19.6 6695.5 31.1 6700.5 31.7 6705,5 30,3 6710,5 29,! 6715.5 6450.00 6455.00 6460.00 6465.00 6470.00 6475.00 6480.00 6485.00 6490.00 6495.00 6500.00 6505.00 6510.00 6515.00 6520°00 6525.00 6530.00 6535.00 6540.00 6545.00 6555.00 6560.00 6565.00 6570.00 6575.00 6580.00 6585.00 6590.00 6595.00 6600.00 66 05.00 6610.00 6615.00 6.620.00 6625.00 6630.00 6635.00 66~.0.00 6645.00 6650.00 6655.00 6660.00 6665.00 6670.00 6675.00 6680.00 6685.00 6690.00 6695.00 6700.00 6705.00 6710,00 6715.00 Page 13 24-F E8-87 10:07 67~0o00 125. 4o£? 7Go6 28.6 67~0.5 6720°00 weII: TAK556 De~th F 6725.{30 4.17 51.6 6730.00 3.83 56.8 6735.00 3.91 63.7 6740.00 ¢,30 32,7 6745,00 4.62 44,.0 6750.00 4.33 40.0 6755.00 3.97 55.2 6760.00 3.85 53.5 6765.00 3.89 53.1 672'0.00 3.49 179.3 672'5.00 2.85 93.8 6780.00 3.65 92.6 6785.00 4.14 39.4 6790,00 4.60 43.4 6795.00 4.~+5 60.4 68{30.00 4..31 79.4, 6805.00 4.28 78.5 6810,00 4.07 82.4 6815.00 3.41 72.5 682 Oo O0 2.88 3,53 . 3 683,0.00 2.60 434.8 23.3 6830.5 6835.00 3.61 '42-6,6 i5.1 6.835.5 6840.00 2.66 418.0 14.5 6840.5 6845.00 1.t8 413.6 15.9 6845.5 685,0,00 1.1.2 397.3 16.0 6850.5 6860.00 65. 1o15 397,6 14.3 6860.5 6865.00 64. 1.26 408.6 13.2 6865.5 6870.00 78. Z.37 42.0.3 14.8 6870.5 6875.00 76. 1.58 275.6 23.5 6875.5 6880,00 90. 1.80 283.9 22.0 6880.5 6885,00 71. 2.06 261.4 24.9 6885.5 6890.00 82. 1.74 112.4 8.7 6890.5 6895.00 79. t.18 320,1 21.1 6895,5 6900.00 61. 1.!6 457.7 27.0 6900.5 6905.00 73. 1.~,2 216.5 11.9 6905.5 6910~00 65. 1.51 418.0 13.5 6910.5 6915.00 67. 2.-03 299.5 22.0 6915.5 6920.00 107. 2.45 142.2 27.5 6920.5 6925.00 123. 2.96 140.4 29.9 6925.5 6930.00 126. 3.19 73.5 31.5 6930.5 6935.00 i10. 2.32 309.9 31.8 6935.5 69,40, 00 88. 2..38 194,6 2_8.7 6940.5 6945.0'0 98. 2.95 95.0 30.4 6945.5 6950.00 110. 3.16 102.3 29.3 6950.5 6955.00 125. 3.34 93.9 29.3 6955.5 6960.00 11'9. 3.5{) 64.6 31.9 6960.5 69~5.00 97. 3.~8 137.4 2~,2 6955,5 69]0.00 82. 3.01 336.9 20.7 6970.5 69]5.00 76. 2..25 137.~ 30.0 6975.5 6980.00 62. 1.77 193.7 28.1 69~0.5 69~5.00 55. 1.5~ 209,0 19.5 69~5.5 C 6990.00 65. 1.~4 91,.2 2'9.9 6990.5 GR CNTS 131. 153. 155. 137. 148. 141. 148. 143. 166. 134. 109. 111. 140. 126. 108. 91. 117. 83. 76. 68. OFM/M2 FT/HR W£ KL B RPM ~S RPM 32.1 6725.5 30,7 6730.5 37.2 6740.5 36.9 6745.5 33.7 6750.5 34.3 6755.5 36.1 6760.5 34.0 6765.5 33.8 6770.5 23.0 6775.5 21.1 6780.5 28.9 6785.5 36.1 6790.5 31.9 6795.5 33.7 6800.5 33.0 6805.5 29.0 6810.5 30.0 6815.5 25.5 6820.5 Depth F 6725.00 6730.00 6735.00 6740.00 6745.00 6750.00 6755.00 6760.00 6765.00 6770.00 6775.00 6780.00 6785.00 6790.00 6795.00 6800.00 6805.00 6810.00 6815.00 6820.00 6830.00 6835.00 6840.00 6845.00 6850.00 6855.00 6860.00 6865.00 6870.00 6875.00 6880.00 6885.00 6890.00 6895.00 6900.00 6905.00 6910.00 6915.00 6920.00 6925.00 6930,00 6935.00 6940.00 6945.00 6950.00 6955,00 $960.00 6965.00 6970.00 6975.00 6980.00 6985.00 6990.00 Page 14 24-F EE-8 7 1t~ :07 67., i.$~ 34Z.~ 21.5 6995.5 6995.00 Well: TAK556 Del;th F 7000.00 7005.00 7010.00 7015.00 7020.00 7025.00 7030.00 7035.00 7040.00 7045.00 7050'00 7055.00 7060.00 706:5.00 7070.00 7075.00 7080.00 7085.00 7050.00 7095.00 7100 O0 7110.00 7115.00 7120.00 7125.00 7-.130. O0 71:35.00 7140.00 7145.00 7150.00 7155.00 7160.00 7165.00 7170.00 7175.00 7180.00 7185.00 7190.00 71~5.00 72t)0.00 72C$.00 7210.00 7215.00 7220.00 7225.00 7230.00 7235.00, 7240.00 7245.06 7250.00 7255.00 72e0.00 72e5.0C GR CNTS 60. 51. 49. 50o 62. 66. 73. 70. 65. 51. 89. 91. 75. 87. 111. 106. 119. 126. 13i. 142. 128. 117. 148. 12'9. 115. 126. 128. 125. 118. 1§9. 110o 8.0. 89. 107. 91. 83. 86. 77. ?2. 88. 93. !09. OPM/M2 1.22 1.33 1.32 1=17 1.25 1.21 1.20 1.19 1.41 1.45 1.62 1.92 1.78 1.67 1.67 3.11 3.21 3.53 3.61 3.66 3.92 3.91 4.01 3.96 3.77' 3.31 2.36 2.23 2.77 3.73 4.02 4.15 3.40 3.85 3.5f 3.33 2.71 t.58 t .43 1.51 1.85 3.65 2.85 1.82 1.49 i.~+~ 1.45 2.49 2.2C 2.0~ 2.1~ RDP WI:3 RPM FT/ftR KL3S RPM 368.1 45.8 7000.5 435.2 16.8 7005.5 3,74.6 20.6 7010.5 356.2 24.5 7015.5 363.8 24.7 7020.5 348.7 20.3 7025.5 217.7 21.2 7030.5 2a7.1 19.0 7035.5 277.6 22.0 7040.5 311.2 21.9 704,5.5 310.0 22.8 7050.5 228.0 24.8 7055.5 307.2 24.0 7060.5 169.6 20.2 7065.,5 384.7 20.9 7070.5 237.6 21.1 7075.5 49.2 26.0 7080.5 99.8 23.6 7085.5 35.1 27.5 70:)0.5 32.0 27.8 7095.5 70-8 29.0 7105.5 5'3'. 6 ~;,-6 7'110.~5 57.7 27.6 7115.5 60.9 28.5 7120.5 65.1 35.7 71Z5.5 67'29 .... 38~,6 7130.5 62.5 41.8 7135.5 238.2 37.4 7140.5 156.4 39.4 7145.5 89.4 42.4 7150.5 53.7 42.5 7155.5 71.5 36.7 7160.5 63.1 36.8 7165.5 71.4 36.5 7170.5 94.0 36.1 7175.5 91.1 .36.6 7180.5 50.9 38.5 7185.5 99.8 22.7 7190.5 279.0 16.7 7195.5 318.0 20.8 7200.5 386.9 23.7 7205.5 363.6 32.0 7210.5 60.6 35.5 7215.5 117.2 34.9 7220.5 167.1 32.3 7225.5 350.7 29.1 7230.5 229.9 27.9 7235.5 331.6 22.6 7240.5 154.5 32.1 7245.5 159.9 33.8 7250.5 126.1 37.8 7255.5 105.2 34.6 7260.5 125.5 32.9 7255.5 Oep*th F 7000.00 7005.00 7010.00 7015.00 7020.O0 7025.00 7030.00 7035.00 7040.00 7045.00 7050.00 7055.00 7060.00 70 65 7070.00 7075.00 7080.00 7085.O0 7090.00 7095.00 7105o00 7110.00 7115.00 7120.00 7125.00 7130. o o 7135.00 7140.00 7145.00 7150.00 7155.00 7160.00 7165.00 7170.00 7175.00 7180.00 7185.00 7190.00 7195.00 7200.00 7205,.00 7210.00 7215.00 7220.00 7225.00 7230.00 7235.00 7240.00 7245.00 7250.00 7255.00 7260.00 7265.00 24-F EB-87 Page 15 10:07 721/0.00 277.9 32.3 7270.5 7270°00 (. (_ ( ( ( Well: ?AK556 De~th GR $~ ROP F CNTS OhH/H2 PT/HR 7275.00 92. 2.52 72E0.00 96. 1.8~ 7285.00 85. 1.88 7290o00 81. 1.~0 7295.00 78. 1.82 7300.00 81. 1.53 73C5.00 77. t.51 73-10.00 86. 1.7e 7315.00 101. 1.99 7320.00 100. 2.14 7325. O0 110. 2.4~ 7330.00 116. 2.65 7335.00 94. 1.ge 7340.00 96. 1.40 7345.00 113. 1.46 7350.00 111. 1.45 7355.00 101. 1.63 7360.00 ~9. ~.76 7365.00 96. 2.28 732,0. O0 ~09. 1.96 7375.00 110. r e'o: z §'204 7385.00 1os. 7390.00 118. 2.68 7395.00 131. 3.11 74C0..00 140. 3.24 .~05...00 1.15 .... 7410.00 129. 4.02 7415.00 I14. 4.75 7420.00 124. 5.0~ 7425.00 144. 4.59 7430.00 111. 3.~3 7435.00 99. 7440.00 113. 2.87 7445.00 116. 3.05 7450.00 i19. 7455.00 109. 7440.00 157. 4.64 7465.00 160. 2.96 7470.00 125. 1.99 7475.00 89. 1.44 7480.00 61. 1.~7 74~5.00 g7. i.62 7450.00 102. 1=68 7495.00 96. 1.85 7500.00 92. 2.10 7505.00 108. 1.87 7510.00 137. 2.22 7515.00 125. 7520.00 122. 3.15 7525.00 i01. 7530.00 100. 1.93 7535.00 117. ~.61 7540.00 106. i.~ KLBS 193.0 33.0 232.9 33.1 167.2 31.5 314.9 24.1 213.7 14.4 56.5 11.6 264.9 16.8 250.1 17.3 79.4 17.4 90.7 24.6 129.1 24.2 105.2 25.8 249.3 21.4 250.0 19.7 261.6 19. I 224.3 19.1 224.4 21.1 238.3 24.9 116.8 24.7 222.1 19.7 145.7 27.5 200.8 20.5 216.9 17.3 52.5 24.3 61,6 23.4 40.9 25.5 69.0 25.1 28.8 25.8 63.5 28.7 94.9 33.3 153.8 2g.7 239.:2 30.7 107.3 31.7 41.7 30.~ 140.5 34.7 26.4 36.1 194o4 253.9 19.4 363.2 16.5 3~9.2 15.4 411.2 19.1 21~.9 20.3 3'53.0 19.0 349.! 24.1 151.7 42.5 27.1 1~1.0 25.6 174.7 22.9 361.8 23.6 372.7 16.2 3t.1 321.0 11.3 RPN RPN 7275.5 7280.5 7285.5 7290.5 7295.5 7300.5 7305.5 7310.5 7315.5 7320.5 7325.5 7330.5 7335.5 7340.5 7345.5 7350.5 7355.5 7360.5 7365.5 7370.5 7380.5 7345.,5 7390.5 7395.5 74.00.5 7410.5 7415.5 7420.5 7425.5 7430.5 ?435.5 7440.5 7445.5 7450.5 7455.5 7460.5 7455.5 74'70.5 74-75.5 74~0.5 7485.5 7490.5 7495.5 7500.5 7505.5 7510.5 7515.5 7520.5 7525.5 7530.5 7535.5 7540.5 Depth F 7275.00 7280.00 7285.00 7290.00 7295.00 7300.00 7305.00 7310.00 7315.00 7320.00 7325°00 7330°00 7335.00 7340000 7345.00 7350.00 7355.00 7360.00 7365.00 7370.00 7380.00 73'05. e~ 7390.00 7395.00 74 00. O0 7405.00 ' 7410.00 7415,00 7420.00 7425.00 7430.00 7435.00 7440.00 7445.00 7450.00 7455.00 74 60.00 7465.00 7470.00 7475.00 7480.00 7485.00 7490.00 7495.00 7500.00 7505.00 7510.00 7515.00 7520.00 7525.00 7530.00 7535.00 7540.00 P~ge 1~ 24-F EB-87 10:07 7545°00 1.50o ,:..'~ '~ 7-5o2 24.£ 75~,5.c;. 7545°00 C ~1e11: TAK556 Depth F 7550.00 7555.00 75~0.00 7565.00 7570.00 7575. O0 7580.00 75~5o00 7590.00 7595.00 7600.00 7605.00 7610o00 7615.00 7620°00 7625.00 7630.00 7635.00 7640°00 764 S o O0 7655.00 7660000 7665.00 7670.00 7675.00 7'6'8'0 7685.00 7690.00 7695.00 7700o00 7705.00 7710.00 7715.00 7720.00 7725.00 7730.00 7735.00 7740.00 7'74 5. O0 7750.00 7755.00 7760.00 7765.00 7770.00 7775.00 7780.00 7785.00 7750°00 7795.00 7800.00 7805.00 7810.00 7815.00 GR SN RnP CNTS DHM/M2 FT/HR 107. 2.50 185.9 116. 2.08 406.4 116. 1.72 559.1 131. 3.34 53.4 95. 2.13 315.9 128. Z.74 43.0 142. 3.46 139.6 149. 3.47 33.8 129. 2.85 120.9 126. 3.29 63.0 140. 3.16 95. 2.06 99.5 93. 1.78 213.7 106. 1.83 189.5 I10. 1.89 52.3 114. 1.99 144.7 119. 2.12 39.3 125. 2.85 86.5 78. 1.72 348.6 770 i. 82 233'.'0 104. 2.44 120.2 88'. 2 o 25 -2't5 122. 3.03 20.9 111. 2.77 72.0 107. 2.16 182.9 109. 2.90 585.1 t04. 3.04 327.8 110. 3.10 415.2 t00. 3.12 34.4 98. 2.87 37.0 98. 2.63 259.8 90. 2.59 121.5 106. 3.86 13.4 100. 4.09 42.3 96. 4.0! 88. 2.67 10.4 102. ~.36 401.2 100. 2.39 406.2 97. 2.3~ 390.8 94. 2.42 386.2 79. 2.55 367.9 101. 2.70 31~5.1 98. 2.72 130. 2.77 258.4 110. 2,.$6 29,7 102. 2.52 155.2 77. 2.26 132.2 96. 2.91 105.9 122. 4.63 130. 5°23 30.1 127. 3.53 47.6 119. 3.30 130.~ we8 RPM Depth KLBS RPM F 26.2 7550.5 7550.00 16.3 7555.5 7555.00 15.4 7560.5 7560.00 24.5 7565.5 7565.00 22.3 7570.5 7570.00 17.2 7575.5 7575.00 20.9 7580.5 7580.00 28.1 7585.5 7585.00 25.2 7590.5 7590.00 29.4 7595.5 7595.00 28.2 7600.5 7600.00 24.1 7605.5 7605.00 20.9 7610.5 7610.00 19.9 7615.5 7615,000 24.5 7620.5 7620.00 13.5 7625.5 7625.00 22.2 7630.5 7630.00 18.1 7635.5 7635.00 15.4 7640.5 7640.00 12,9 7645.5 7645~0.0 25.9 7655,5 7655.00 17~5 76'6~'~5 28.4 7665.5 7665.00 22.2 7670.5 7670,00 15.7 767. S. 5 7.6 ~5:~ 0 15.9 7690.5 7680.00 23.2 7685.5 7685.00 31.1 7690.5 7690.00 32.9 7695.5 7695.00 35.6 7700.5 7700.00 29.5 7705.5 7705.00 27.4 7710.5 7710.00 41.8 7715.5 7715.00 39.9 7720.5 7720.00 36.4 7725.5 7725.00 42.1 7730.5 7730.00 39.7 7735.5 7735.00 31.3 7740.5 7740.00 29.0 7745.5 7745.00 30.6 7750.5 7750.00 29.8 7755.5 7755.00 33.7 7760.5 7760.00 34.3 7765.5 7765.00 45.2 7770.5 7770.00 35.9 7775.5 7775.00 52.6 7780.5 7780.00 47.5 7785.5 7785.00 48.9 7790.5 77'90.00 36.9 7795.5 7795.00 41.0 7800,5 7800.00 39.5 7805.5 7805.00 38.7 7810.5 7810.00 44.2 7815.5 7815.00 Page 17 24-FE8-87 10:07 7820.30 112. 7820.5 7820°00 well: TAK556 Depth F 7825°00 7830.00 7835.00 7840.00 7845.00 7850.00 7855.00 7860.00 7865.00 7870.00 7875.00 7880.00 7885.00 7890.00 7895.00 7900.00 7905.00 7910.00 7915,00 79; 793..o,9p 7935.0,0 7 94 O. O0 7945.00 7955.00 7960.00 7965.00 7970,00 7975.00 7980.0.0 7985.00 7990,00 7995.00 8000000 8005.00 8010.00 8015.00 8020.00 8025.00 8030.00 8035.00 8040.00 80~5.00 8050.00 8055.00 8060.00 8065.00 8070.00 8075,,,06 8080.00 8085.00 80':JO. O0 GR CNTS 107. 123. 103. 115. 128. llZ. lll. 119. 124. 122. 126. 116. 132. 137. 130. 129. 122. 108. 111. 1Q4. 104, 100, 85. 102. 112. 100. 91. 99. 87. 87.. 82. 78., 92. 90. 123. 191. 131. 175. 95. 97. 83. 51. cj4. 94. -37. I16. Ili. 127. 124. 118. 132. Sk 3.00 3.07 3.04 2.68 2.36 2.18 3.01 2.61 3.00 3.03 3.14 3.17 3.19 3.35 3-53 3.44 3.45 3.50 3.51 3.33 3.48 3.31 Z. 90 2.63 2.83 2-49 2.44 2.51 2.38 2.22 2.92 7.47 2.62 2.3~ 2.2~ 2.55 2.51 2.09 ~. 34 2.72' Z.SC 2.81 3.04 3.72 R{3P WEB FT/HR KLBS 100.7 38.8 105.9 39.2 15.3 42.3 14.7 5'2,3 26.1 47.8 15.2 53.7 27.3 53.5 48.1 41.6 87.8 24.4 73.5 36.7 49.7 38.7 58.8 39.6 55.2 38.4 60.0 40.1 60 .T 44.0 61.0 39,3 55. t 3-9.8 192.0 39.3 94,5 25.5 61.3 40.3 91.1 40.1 18.7 32.0 70.8 40,7 118.0 34.8 49.4 48-~9 .... 31.9 41,8 60.0 36.7 21-.4 46.9 461.8 23.1 574.1 18.1 22.8 7.7 404.2 15.7 586.5 21.4 584.7 20..7 550.0 22.7 17.7 50.4 271.6 36.5 350.0 27.5 28.1 11.4 98.1 26.2 237.2 23.3 346.7 33.5 410.0 27.8 151.8 23.8 496.5 23.8 267.5 30.2 137.6 44.1 157.7 31.0 222.2 49.3 24.7 56.7 38.7 54.2 124.5 45.7 RPN Depth RPM F 7825.5 7825.00 7830.5 7830°00 7835.5 7835.00 7840.5 7840.00 7845.5 7845.00 7850.5 7850.00 7855.5 7855.00 7860.5 78&0.00 7865.5 7865,00 7870.5 7870.00 7875.5 7875.00 7880.5 7880.00 7885.5 7885.00 7890.5 7890.00 7895.5 7895.00 7900.5 7900.00 7905.5 7905.00 7910.5 7910000 7915.5 7915,00 7920.5 79Z0.00 -*/~Z~d~' ~j~:~,'.d 0 7930.5 7930.00 79~. 5 7935. 7940.5 7940,00 7945.5 7945.00 7950 ...5 7955.5 7955.00 7960.5 7960.00 7965.5 7965.00 7970.5 7970.00 79'75.5 7975.00 7980.5 7980.00 7985.5 7985°00 7990.5 7990.00 7995.5 7995.00 8000.5 8000.00 8005.5 8005.00 8010,5 8010.00 8015.5 8015.00 8020.5 8020.00 8025.5 8025.00 8030.5 8030.00 8035.5 8035.00 8040.5 8040,00 8045.5 8045.00 8050.5 8050.00 8055.5 8055.00 8050.5 8060.00 8065.5 8065.00 8070.5 8070.00 8075.5 8075.00 8080.5 8080.00 8085.5 9085.00 8090.5 8090.00 Page 18 24-F EE-87 10:07 8095.00 90. 3. ;"4 116.5 53.7 8095°OO ( ~ell: TAK$56 811;0.00 8105.00 8110.00 8115.oo 8120.00 8125.00 8130.00 8135.00 8140.00 8145.00 8150. O0 8155.00 8160.00 8t65.00 81:70. O0 81'*/5.00 818 O- O0 8185.00 8190.00 8195.00 .¢ C Depth GR SI~ F CNTS ~]PM/M2 f::T/HR KLBS 8210,00 821.5.00 8220.00 822 5.,00 92. 96. 89. 92. 98. 83. 96. 162. 116. 125. 13 3. 75. 90. 113. 86. 109. 86,, 70. 81,, 114-,. i39. 109. 1,10. 3.42 3.69 3.60 3.01 3.16 .3.16 3.09 2.89. 3.98 3.09 2.28 2.5(; 2.72 3.91 2..73 2.98 2.85 3.I6 2.47 2.41 3.03 3.2.1, 8235.00 92. 8240.00 102. 3.53 8245.00 71. 2.56 8250.00 72. 2.57 8255.00 92. 2.70 8260-00 89. 8265.00 115. 2.66 8270.00 102~ 4.1~ 8275.00 101. 3.6~ 8280.00 96. 3.56 8285.00 8.1. 3.81 8290.00 98. 3.88 8295.00 125. ~,10 83~0.00 130. 4,03 83~$.00 123. 3.94 8310.00 i16. 3.83 8315.00 126. 3.89 8'320*00 130. 3.99 8325.00 101. 4.06 8330.00 104. 4.01 8335.00 112. 4.32 8340.00 116. 5.39 8345.00 124. 4.04 83~0.0G 115. 4.21 8355.00 123. 4.06 83~0.00 120. ~.I0 83~5.0§ 11i. RPM Depth RPM F 97.2 34.4 8100.5 8100.00 108.6 45.9 8105.5 8105.00 134.2 39.7 8110.5 8110.00 60.5 49.5 8115.5 8115.00 204.0 46.3 8120.5 8120.00 189.6 48.1 8125.5 8125.00 83.5 39.4 8130.5 8130.00 21-8.3 49.2 8135.5 8135.00 66.1 ~4.3 8140.5 8140.00 53.8 49.2 8145.5 8145.00 49.2" 53.2 8150.5 8150.00 61.5 17.9 8155.5 8155.00 74.4 15.8 8160.5 8160.00 72.0 16.9 8165.5 8165~00 15.8 44.8 8170.5 8170.00 82.8 22.8 8175.5 8175.0'0 83.9 24.8 8180.5 8180.00 159.8 21.2 8185.5 8185.00 44.8 22.0 8190.5 8190.00 5~3.0-- 22,.-9 8195 . 5 8 X 95 . 00 78.5 1':?.7 8205.5 8205.00 68..0 13.6 82-t0.5 82-10.00 89.1 8.8 8'215.5 8215.00 58.7 5.1 8220.5 8220.00 39.2 ¢0.7 8225.5 8225.00 · 9~'~ 28'./ 82~0.5 8230~00' 45.8 25.5 823.5.5 8235.00 38.5 27.5 82¢0.5 8240.00 82.3 15.8 8245.5 8245.00 62.9 22.3 8250.5 8250.00 108.8 18.4 8255.5 8255.0.0 6'2.0 25.2 8260.5 8260.00 79,4 21.9 8265.5 8265.00 49.6 ~4.5 8270.5 8270.00 52.8 54.4 8275.5 8275.00 25.2 16.5 8250.5 8280.00 48.3 28.7 8285.5 8285.00 26.0 29.4 8290.5 8290.00 27.6 30.2 8295.5 8295.00 29.3 32.4 8300.5 8300.00 36.6 39.1 8305.5 8305.00 ~2.5 50.6 8310.5 8310.00 35.1 - ~'5', 9 - 8315,5 8315.00 21.9 45.3 8320.5 8320.00 40.3 49.7 8325.5 8325.00 53.7 47.4 8330.5 8330.00 26.8 52.4 8335.5 8335.00 I!.1 54.6 8340.5 8340.00 ~4.4 51.1 8345.5 8345.00 3G.5 37.2 8350.5 8350.00 37.1 49.6 9355.5 8355.00 25.7 51.9 8360.5 8360.00 29.7 47.1 8365.5 83'65.00 Page 19 24-FE8-87 10:07 Well: TAK556 De~th GR SN F CNTS g~ M/M2 83./5.00 83e0.00 8385.00 8390.00 8395.00 84G0.00 84O5.00 8410.00 8415.00 8420.00 8425.00 8430.00 8435.00 8440.00 8445.00 8450.00 8455.00 8460.00 8465.00 84]'0.00 8480.00 8485.00 8490.00 8495.00 85G0.00 '" 85e S.'O0 8510.00 8515.00 8520.00 8525.00 8530.00 8535.00 8540.00 854 5.00 8550.00 8555.00 8560.00 8565.00 85'/0.00 8575.00 8580.00 8585.00 8550.00 8595.00 8600.00 8605.00 8610.00 $615.00 8620.00 8625.00 8630.00 8635.00 86~0.00 SS. 63. 64. 57. 8I. 114. 99. 113. 100. 120. 130. 112. 102. 124. 113. 93. 97. 87. '/2. 108. 117. 103. 102. 103. 89. I25. 106. 105. 66. 87. 87. ST. 116. 100. 61. 72. 79. 59. 75. 113. 92. 79. ?5. 72. 59. 72. 65. 66. 75. 112. t09. 2.99 2.91 2.64 2.75 3.45 3.52 4.41 5.82 4. W7 4.44 4.14 4.15 4.02 3.88 3.75 3.21 3.0~ 4.09 3.99 4.30 4.40 4.3~ 4.35 ' 4.30 4.22 4.tE 3.03 3.11 2.98 3.44 4.05 4.05 3.66 .4.79 2.63 2.72 2.60 3.36 4,LO 3.55 3.11 2.16 3.09 2.6~ ;'.53 2.75 2.56 3.28 8.72 4.17 RaP KLBS 82.7 60.8 110.5 110.6 117.5 34.7 111.8 8.9 22.3 18.1 19.9 29.6 ~6.3 50.7 19.6 19.6 19.6 19.6 19.6 19.6 42.7 64.3 50.6 47.4 48.2 49 40.1 44.6 134.5 144.7 133.2 128.7 85.2 62.9 1'75.4 141.9 143.3 163.7 140.8 110.1 34 .I 153.6 110.4 125.1 106.0 114.9 108.3 i30.2 130.5 $2.8 15.2 35.5 41.0 48.2 43.7 43.9 46.0 26.5 44.0 50.9 50.2 49.7 4,7.6 53.2 57.0 60.1 36.5 48.4 50.1 45.0 44.4 46.9 50.0 45.0 44.4 43.5 50.7 45.9 49.6 55.3 46.8 41.8 43.0 46.6 46.9 49.4 43.5 44.5 47.9 46.8 51.4 54,6 55.1 54.e 46.4 41.4 51.2 46.4 35.5 37.2 36.9 46.1 48.5 45.0 45.3 RPM RPM 8375.5 8380.5 8385.5 8390.5 8395.5 8400.5 8405.5 8410.5 8415.5 8420.5 8425.5 8430.5 8435.5 8440.5 8445.5 8450.5 8455.5 8460.5 8465.5 8470.5 8480.S 8485.5 8490.5 8495.5 8500.5 8'5'05,5 8510.5 8515.5 8520.5 8525.5 8530.5 85.35.5 8540.5 8545.5 8550.5 8555.5 8560.5 8565~5 8570.5 8575.5 8580.5 8585.5 8590.5 8595.5 8600.5 8605.5 8610.5 8615.5 8620.5 8625.5 ~J630.5 8635.5 8640.5 Repth F 8375.00 8380.00 8385.00 8390.00 8395.00 8400.00 8405.00 8410.00 8415.00 8420.00 8425.00 8430.00 8435.00 8440.00 8445.00 8450.00 8455.00 8460°00 8465.00 8470.00 'a*T'::O0 8480.00 8485.0'0 8490.00 8495.00 8500.00 8505;0O 8510.00 8515.00 8520.00 8525.00 8530.00 8535.00 8540.00 8545.00 8550.00 8555.00 8560.00 8565.00 8570.00 8575.00 3580.00 8585.00 8590.00 8595.00 8600.00 8605.00 8610.00 8615.00 8620.00 8625.00 8630.00 8635.00 8640.00 PaGe 20 24-F E9-87 10:07 8645°00 32..2 B645.5 $645.00 Well: TAK556 Oe~th F 8650.00 8655.00 8660.00 866 5. O0 8670.00 8675.00 8680.00 8685.00 8690.00 8655.00 8700~00 87G5.00 8710.00 8715.00 8720.00 8725.0.0 8730.00 8735.00 8740.00 8745.00 8755.00 8760~00 8765.00 8770.00 8715,.00 "8786..0-6 8785.00 8750.00 8755.00 8800.00 8805.00 8810.00 8815.00 8820.00 8825.00 88~0.00 8835.00 8840.00 8845.00 8850.00 8855.00 8860.00 8865.00 8870,00 8875.00 8880.00 8885.00 8880.00 8895.00 89~0.00 8905.00 8910.00 8915.0G GR CNTS 103. 123. 86. 116' 107. lll· ?1. 72. 55. 77. 89. 68. 76.. 91. 121. 105. 103. 118, 117, 107. 106. 117. 110. 113. 133. 10,3. t07. 118, 96. 129. 114. 133. 108. 117. 1'00. I34. 123. 135. 141. 115. 119. 141. 1t9. 126. 136. 115. 12.7. 112. 120. OHM/M2 ROP 4.02 38.0 4.27 24.3 4.44 36.0 4.15 30.0 4.25 77.2 4.27 41.6 2.16 75.0 1.68 104.0 1.69 128.9 1.9~ 77.9 · 2.57 77.9 2.72 162.3 2.53 152.5 3.51 139.6 12.99 14.0 4.63 50.0 4.27 40.7 4.13 37.4 4.15 40.2 4.14 33.5 4.27 3'7.1 4.10 40.8 ~.Z4 36.9 4=07 35=7 ~.07 - 4.07 35.3 4.13 34.3 3=99 33.3 4.17 30.5 4.~0 34.9 4.38 45.3 5.15 21.9 4.41 32.0 4.41 26.2 4.41 27,1 4.44 26.1 4.63 33.2 4.66 30.1 4.66 25.9 3.58 26.6 3.74 26.8 3. 9-t .... 2:5.4 3.98 29.7 3.63 28.6 3.35 27.1 3.42 27.2 3.69 2~.9 ~,41 20.0 4.49 23.5 ~.25 26.0 4.38 21.3 ~.0~ 21.6 W£8 KL BS 41.8 47.8 43.2 47.3 50.2 54.0 46.3 33.3 36.8 34.6 34.9 31.6 39y6 51,0 45.0 48.7 50.0 56.7 49 ~4 51':~ 9 53.0 41.5 42.9 44.0 ~'1.2 44.3 42.6 48.8 52.4 49.7 52.5 52.7 52.4 52.3 49.1 53.7 51.0 52.9 53.7 81.9 73.0 69.0 65.8 58.8 56.8 58.1 60.2 58.9 54 .O 53.0 54.3 RPM 8650.5 8655.5 8660.5 8665.5 8670.5 8675.5 8680.5 8685.5 8690.5 8695.5 8700.5 8705.5 8710.5 8715.5 8720.5 8725.5 8730.5 8735.5 8740.5 ,87.45.5 8755.5 8760.~5 8765.5 8770.5 8775.5 6785.5 8790.5 8795.5 8800.5 8805.5 8810.5 8815.5 8820.5 8825.5 8830.5 8835.5 8840.5 8845.5 8850.5 8855.5 8860.5 8865.5 8870.5 8875.5 8880.5 88~5.5 8890.5 8895.5 8905.5 ~910.5 3915.5 Depth F 8650.00 8655.00 8660.00 8665.00 8670.00 8675.00 6680.00 8685.00 8690.00 8695.00 8700.00 8705.00 8710.00 8715,00 8720.00 8725.00 8730.00 8735.00 8740.00 8'/4,5.00 8755.00 8'7 8765.00 8770.00 8775.00 8785.00 8790.00 8795.00 8800.00 8805.00 8810.00 8815.00 8820.00 8825.00 8830.00 8935.00 8840.00 8845.00 8850.00 8855.00 8860.00 8,865.00 887'0.00 8875.00 8880.00 8885.00 8890.00 8895.00 8900.00 8905.00 8910.00 8915.00 PaGe 21 24-F EB-87 10:07 3.51 8920.5 B920.00 Well: YAK556 De~th GR F CNTS 8925.00 80. 6930.00 89. 8935.00 69. 8940.00 92. 8945.00 115. 8950.00 95. 8955.00 65. 8960.00 84. 8965.00 71. 8970.00 106. 8975.00 111. 8980.00 8985.00 8990.00 102. 8995.00 107. 9000.00 111. 9005.00 103. 9010.00 102. 9015.00 103. 9020.00 107. 9030.00 107,, 9035.00 138. 9040.00 126. 9045.00 115. 9050.00 109. 9055. O0 '1'12. 9060.00 126. 9065.00 124. 9070.00 142. 9075.00 111. 9080.00 112. 9085.00 112. 9090.00 111 9095.00 117. 9100.00 110. 9105.00 136. 9110.00 115. 9115.00 112. 9120.00 116. 9125.00 116. 9130.00 128. 9135.00 145. 9140.00 123. 9145.00 118. 9150.00 104. 9155.00 114. 9160.0G 124. 9i65.00 137. 9170.00 127. 9175.00 IlO, 9180.00 115. 91~5.0C 101o 9190.00 log. 3.77 4.38 4.44 4.50 4.38 3.6~ 3.67 3.36 4.72 5.04 4.56 4.i5 4.30 4.2.1 4.27 4.44 4.5C 4.4,1 ~,~ 3,0 4.35 4.33 4,.13 4.47 4.27 4.30 4o30 4.30 4.24 4.21 4.18 4.30 4.Z5 4.24 4.Z7 4.33 4.31 4.35 4.44 4.41 4.44 4.47 4.34 4.50 4.50 4.50 82.8 61.7 19.5 48.2 42.4 63.1 103.6 48.5 83.8 22.6 42.9 49.9 46.9 38.9 39.5 33.5 36.0 30.9 32.2 29.6 31.9 27.9 27.3 21.7 26,5' 22.3 23.2 23.5 23.6 25.8 27.1 21.3 22.7 23.3 2t.6 22.0 37.7 49.7 39.0 45.2 47.8 42.2 45.4 43.2 ~ .! 25.~ 22.5 33.8 43.1 37.6 KL 9 8S 47.6 51.5 53.5 48.1 54.6 52.5 42.4 47.2 42.5 54.5 52.5 50.8 51.9 52.7 52.1 55.2 52.9 48 .g 51.7 51.4 47.6 55.1 54.2 59.9 50.2 53; 5 53.8 54.8 52.2 51.8- 53.8 51.3 48.8 50.4 46.2 48.1 50.8 49:.9 26.7 34.~ 41.0 45.6 43.8 45.8 43.3 42.8 44.7 38.7 45.5 27.9 42.2 3~ .2 ~i .4 RPM RPM 8925.5 8930.5 8935.5 8940.5 8945.5 8950.5 9955.5 8960.5 8965.5 8970.5 8975.5 8980.5 8985.5 8990.5 8995.5 9000.5 9005.5 9010.5 9015.5 9020.5 9030.5 9035.'5 9040.5 9045.5 9050.5 90'55.5 9060.5 9065.5 9070.5 9075.5 9080.5 9085.5 9090.5 9095.5 9100.5 9105.5 9110.5 9115.5 9120.5 912'5.5 9130.5 9135.5 9t40.5 9145.5 9150.5 9155.5 9160.5 9155.5 9170.5 9175.5 9180.5 9185.5 9190.5 I~ epth F 8925.00 8930.00 8935.00 8940.00 8945.00 8950.00 9955.00 8960.00 8965.00 8970.00 8975.00 8980.00 8985.00 8990.00 8995.00 9000.00 9005.00 9010.00 9015.00 9020.00 9030.00 90:35. O0 9040.00 9045.00 9050.00 9055,00 9060.00 9065.00 9070.00 9075.00 90 80.0 0 9085.00 9090.00 9095.00 9100.00 9105.00 9110o00 9115.00 9120.00 9125.00 9130.00 9135.00 9140.00 9145.00 9150.00 9155.00 9160.00 9165 9170.00 9175.00 9180.00 9185.00 9190.00 Page 22 24-F EB-87 10:07 ( Well: De~th F GR CNTS 9200.00 9205.00 9210.00 9215.00 9220.00 9225.00 9230.00 9235.00 9240.00 9245.00 9250.00 9255.00 9260.00 9265.00 9270.00 92?5.00 9280.00 9285.00 92S0.00 9295.00 9305.00 931 O- O0 9315o00 9320.00 9325.00 9330,'00 9335'00 9340.00 9345.00 9350.00 9355.00 9360.00 9365. O0 9370.00 9375.00 9380.00 9385.00 9350.00 9395.00 9400.00 94C5.00 9410.00 9415o00 9420.00 9425.00 9430.00 9435.00 9440.00 9445.00 9650.00 9455.00 94~0.00 9465.00 120. 122. 131. 135. 127. 119. 122. 130. 119. 109. 127. 101. 113. 133. 114. 117. 119. 135. 126. 121. 118. 122. 118. 136. 125. 131. 138. 130. 128. I22. 115. 123. S~ D~, M! M2 4.52 4.69 4.66 4.60 4.79 4.B5 4.82 4.66 4.88 5.09 5.23 5.55 5.30 4.7i 4.82 4.68 4.68 a.47 4.50 4.49 4.57 4.46 4.57 4.33 4.27 4.50 4.43 4.57 4.44 4.53 RDP WEB RPM VT/HR KLSS RPM 3~.8 48.3 9200.5 43.5 41.0 9205.5 40.1 44.2 9210.5 40.6 41.5 9215.5 37.0 44.4 9220.5 37.2 44.9 9225.5 41.3 39.6 9230.5 39.2 40.4 9235.5 40.5 43.1 9240.5 38.3 41.1 9245,5 37.6 44.6 9250.5 38.2 43.0 9255.5 36.6 43.0 9260.5 31.9 39.7 9265-5 37.9 41.1 9270.5 30.7 32.7 9275.5 35.3 48.7 9280.5 36-2 43.1 9285.5 37-0 45.9 9290.5 .6!:,-~ 37:.5 9295.5 35'8 36.5 9305.5 3~;.2 37.4 9-3't.0.5 38.0 38.~ 9~15'5 75.0 44.3 9320.5 44.4 43.8 932'5.5 32.1 44,5 9335.5 35,2 43.4 9340.5 29.4 45.2 9345.5 38.1 42.8 9350.5 33.5 49.6 9355.5 36.1 46.4 9360,5 41.7 48.1 9365.5 39.3 48.9 9370.5 32.9 4~.4 9375.5 25°2 33.4 9380.5 17.5 25.3 93~5.5 26.0 32.2 939.0.5 27'9 31.2 9395.5 30.1 24.9 9400.5 28.4 30.5 9405.5 31.2 30.4 9410.5 32,1 30.7 9415.5 51.8 39.4 9420.5 43.0 40,8 9425.5 ~3.7 45.0 9430.5 ~1.6 46.3 9435.5 41.1 39.7 9440.5 40.3 38.8 9445.5 41.? 41.1 9450.5 39,4 41.6 9455.5 38.5 42.7 9460.5 38.7 33.6 9465.5 Depth F 9200.00 9205.00 9210.00 9215.00 9220.00 9225.00 9230.00 9235.00 9240.00 9245.00 9250.00 9255.00 9260.00 9265.00 9270°00 9275°00 9280°00 9285.00 9290.00 9295.00 9305.00 93'10. O0 9315.00 9320.00 9325.00 9330. O0 : ' 9335.00 9340.00 9345.00 9350.00 9355.00 9360.00 9365.00 9370.00 9375.00 9380.00 9385.00 9390.00 9395. O0 9400.00 9405.00 9410.00 9415.00 9420.00 9425.00 9430.00 9435.00 9440.00 9445.00 9450.00 9455.00 9460.00 9465.00 Pacje 23 24-F EB-87 10:07 94'/0.00 34.2 4.4.3 9470°5 9470,.00 Well: TAK556 Del:th GR SN ROP Wr..B F CNTS DPM/M2 f:T/HR KLBS 9475.00 18.5 9480.00 30.5 9485.00 29.3 9490.00 27.9 9495.00 114. 4.69 28.7 9500.00 132. 4.5~ 29.8 9505.00 128. ~.55 28.8 9510.00 122. 4.47 30 9515.00 4.38 30.4 9520.00 31.9 9525.00 ' 29,5 9530.00 31.5 9535.00 32.2 9540.00 , 30.9 9545.00 3200 9550.00 3.91 9555.00 3.89 38,9 9560.00 41.8 9565.00 36.5 957,0.,00 12 O. 3-. al 9580. O0 129. 3094 34.0 9585. O0 127 a 4'a 33 9590.00 124o 4.33 30°0 9595.00 114. 4.66 32.5 9600.00 119. 4.73 29.8 9605.00 15'6, 4.6'~6 .... 9610.00 110. 4.79 30.1 9615.00 123. 4.85 31.4 9620.00 116. 4.92 29'00 9625.00 96. 4.85 2906 9630o00 136. 4.72 27.9 9635.00 114, 4.4'/ 28.7 9640.00 137' 4.41 28.2 96450 O0 i18. 4.50 33 9650.00 130. 4,33 13.6 9655.00 132. 4.07 14.3 9660.00 117. 4.15 13.9 96~,5.00 119. 4.i0 14.7 96'/0.00 109o 4.i5 10.1 9675.00 100. 4.85 14 9680.00 i30. 4.41 14.1 96t~5.00 115. 4,35 12.8 9690.00 127. 4.25 13.5 9695.00 135. 4.38 14.6 97t]0. O0 124. 4.38 17.4 9705.00 I00. 4.44 16.1 9710.00 127. 4.3E 15.7 9715.00 119. 4.35 16.3 9720.00 115. 4.50 16.9 9725.00 108. 4.6~ 17.1 9730.00 123. 4.57 16,7 9735.00 113. 5.95 15.5 9740.00 12'*. 5,~A 14.4 40.0 47.1 45.4 47.5 37.9 39.2 38.2 38.8 36.6 38.8 38.0 40.4 39,5 40,,1 41.8 48.0 41.8 44.2 49.9 48.3 51.4 60.6 56°5 54.7 52.7 54.5 57°3 49.6 49.3 54.0 54.5 49.5 50.2 50.1 42.3 57.9 55.6 52.6 50.2 50.8 55.8 50.7 52.7 56.6 60.0 57.3 54.9 56.1 55.3 54,5 54.1 52,6 RPM I~ep'l:h RPM F 9475.5 9475.00 9480.5 9480000 9485.5 9485.00 9490.5 9490.00 949505 9495.00 9500.5 9500.00 9505.5 9505.00 9510-5 9510.00 9515.5 9515.00 9520.5 9520.00 9525.5 9525.0,0 9530.5 9530.00 9535,5 9535.00 9540.5 9540.00 9545.5 9545.00 9550.5 9550.00 9555.5 9555.00 9560.5 9560.00 9565.5 9565.00 9570.5 9570.00 9580.5 9580.00 95 85.' 5 '9 5 85~ OO 9590.5 9590.00 9595.5 9595.00 9600.5 9600.00 9605.5 ' 9'~'0'5.0'0 9610.5 9610.00 9615.5 9615.00 9620.5 9620.00 9625.5 9625.00 9630.5 9630.00 9635.5 9635.00 9640.5 9640.00 9645.5 9645.00 9650.5 9650.00 9655.5 9655.00 9660.5 9660.00 9665.5 9665.00 9670.5 9670.00 9675.5 9675.00 9680.5 9680.00 9685.5 9685.00 ~,9690.5 9690000 9695.5 9695.00 9700.5 9700000 9705.5 9705.00 9710.5 9710.00 9715.5 9715.00 9720.5 97~0.00 9725.5 9725.00 9730.5 9730.00 9735.5 9735.00 9740.5 9740.00 PaGe 24 24-FEB-87 10:07 .¢ 9?45°00 105. 5.59 1~.? 52.4 9?45°5 9745.00 ~ell: T~K556 Del: 'th GR SI~ RI2P ii[ B RPM Depth F CNTS OI"M/M2 FT/HR KL"JS RPM F ( 1 1 9750,,,00 9755,.00 9760.00 9765.00 9770.,00 9775.00 9?8 OD O0 9785.00 9790.00 9795.00 980.0.00 9805.00 9810.00 9815.00 9820.00 9825.00 9830.00 9835.00 9840.00 9845° O0 9855.00 9860~00 9865.00 9870.00 9875.00 9~'a o, O0 9885.00 9890.00 98S5.00 9900.00 9905.00 9910o00 9915.00 9920,.00 9925.00 9930.00 9935.00 9940.00 9945.00 9950.00 9955.00 9960.00 9965.00 9970.00 9975.00 9980.00 9985.00 9990.00 9995.00 0000.0O 0005.00 0010.00 0015.00 116. 86. 87. 90. 76. 104. 89. 110. 118. 114. 109. 105. 102. 120. 97. lO0. 52. 80° lOl. 130. 113. 123. 12!. 120~ 124. 135. 127. 135. 124. 121. 117 · 129. 113. 116. 119. 111. 117. 117. 111. 134. 110. 112. 139. 103. 134. 145. 134. 121 · 127. 136. 105. 5.6d 6.31 5.62 5.57 5.90 6.045 6.02 5.82 5.90 5.74 5.63 5.55 5.70 6.02 6.24 6.54 5.63 5.15 5.59 6.62 0.57 4.72 4,47 4.38 4.18 4.38 ~.14 4.04 3.99 4.10 3.96 3.70 3.49 3.46 3.45 3.32 3.26 3.35 3.13 3oll 3.07 2.83 2.545 3.70 4.0~ 4.25 4.4C 4. '78 4.57 43.7 34.4 49.3 32.0 26.2 26.2 27.4 24.5 Zl.O 15.2 15.0 10.~ 18.9 20.1 23.2 24.0 26.9 132.1 51.7 74.5 44.4 14.3 12.5 9.7 2i.2 25,7 24.2 23.1 23.2 22.6 23.8 24.5 24.2 25.1 25.7 26.9 25.3 27.8 25.5 19.7 24.0 24.2 23.9 76.0 22.1 25.1 33.3 28.0 21.1 21.3 22.3 43.5 47.0 45.0 50.4 49.7 50.5 45.6 51.2 54.4 51.7 55.5 42.6 43.4 45.5 45.0 45.7 53.2 44.0 43.5 46'~0 40.0 49~'8 47.2 46.4 45.3 40.6 44.8 47.5 43.5 47.1 47.5 46.4 47.1 4F.8 50,3 49.6 47.1 53,7 50.7 66.6 64.3 58.5 61.0 55.7 60.3 51.3 61,3 60.2 59.0 60.2 63.1 56.9 57,5 9750.5 9750.00 9755.5 9755.00 9760.5 9760.00 9765.5 9765.00 9770.5 9770.00 9775.5 9775.00 9780.5 9780.00 9785.5 9785.00 9790.5 9790.00 9795.5 9795.00 9800.5 9800.00 9805.5 9805.00 9810.5 9810.00 9815.5 9815.00 9820.5 9820.00 9825.5 9825.00 9830.5 9830.00 9835.5 9835.00 9840.5 98~0.00 9845.5 9845.00 9855.5 9855.00 9'8:50.5 9'8 60. O0 9865.5 9865.00 9870.5 9870.00 9875.5 9875.00 9880.~ ' 9880.00 9885.5 9885.00 98'90.5 9890.00 9895.5 9895.00 9900.5 9900.00 9905.5 9905.00 9910.5 9910.00 9915,5 9915.00 992}0.5 9920.00 9925.5 9925.00 9930.5 9930.00 9935.5 9935.00 9940.5 9940.00 9945.5 9945.00 9950.5 9950.00 9955.5 9955.00 99S0.5 9960.00 9965.5 9965.00 9970.5 9970.00 9975.5 9975.00 9980.5 9980.00 9985.5 9985.00 9990.5 9990.00 9995.5 99'95.00 10000.5 10000.00 10005.5 10005.00 10010.5 10010.00 10015.5 10015.00 Page 25 24-FE8-87 10:07 10020.00 143. $5.5 10020.5 10020.00 well: TAK556 F GR CNTS SN 0~ M/M2 R~qP WIS ~ RPM Oep'th FT/HR KLBS RPM F 10025.00 10030.00 10035.00 10040.00 10045.00 10050.00 10055.00 10060.00 10065.00 loo7o.oo 10075.00 10080.00 10085.00 lOOgO.O0 100g5.00 10100.00 10105.00 10110.00 10115.00 10120.,00 iODo.oo 10135.00 10140.00 10145.00 10150.00 Io:iss~oo 1o16o.oo 10165.00 10170.00 10175.00 10180.00 10185.'00 10190.00 10195.00 10200.00 10105.00 10210.00 10215.00 10220.00 10225.00 10230.0C 10240.00 10245.00 zoz5o.oo 10255.00 10260.00 1016~.00 I0270.00 10275.00 io2~o.oo 10265.00 10290.00 132. 131. 134. 124. 129. 121. lO'g. 109. 110. 106. 120. 119. 116. 117. 97. 120. 129. 135. 114. 133. 132. 1-33. 124. 128. 12'4. 129. 123. 124. 123. 120. 119. 120. 106. 12<3. t24. 132. 124. 135. ll3. 132. 129. 118. 100. li~. 105. 127o 138. 117. 129. 12;~ · 4.42 4.50 4.53 4.63 4.50 4.44 ~.50 4.41 4.41 4.61 4.60 4.$3 4.53 4.50 4.3~ 4.72 4.92 ~.53 4.57 4.60 4.63 4.60 ~..60 4.66 ~.85 4.33 3.8~ 4.3~ 4.69 ~.50 4.53 4.69 4.75 4.69 4.50 4.66 4.82 4.$3 4.95 5.0~ 4.55 4.75 4.59 4.56 21.0 19.5 15.8 20.3 23.7 22.4 23.3 23.7 23.2 24.1 22,2 23.8 23.0 24.6 23.2 24.9 22.8 23.3 22.7 ......... 2~ 9 22.6 2t .9 22.0 23.5 22.8 23,0 23.2 21.3 21.0 22.6 22.3 21 Zl .3 21.5 Z1.5 25.3 22.0 21.1 21.9 21.4 22.0 22.1 21.2 Zl .5 I~.? 20.6 24.0 17.9 23.0 22.4 21.9 22.4 52.7 62.0 55.0 59.3 57.9 58.2 54.8 64.0 63.7 58.1 66.4 65.8 57.9 57.6 50.0 57.2 64.8 66.1 61.6 66.9 57.9 61.,8 56.0 52.2 59.6 61.0 60.1 54.4 55.5 59.9 61.0 55.2 53.7 61.1 53.2 57.5 57.3 56.8 34.6 60.1 60.3 66.6 62.0 59.4 61.4 62.2 55.7 61.5 61.1 60.B 61.6 59.5 61.7 10025.5 10025.00 10030.5 10030.00 10035.5 10035.00 10040.5 10040.00 10045.5 10045.00 10050.5 10050.00 10055.5 10055.00 10060.5 10060.00 10065.5 10065.00 10070.5 10070.00 10075.5 10075.00 10080.5 10080.00 10085.5 10085.00 10090.5 10090.00 10095.5 10095.00 10100.5 10100.00 10105.5 10105.00 10110.5 lOllO.O0 10115.5 10115.00 10120.5 10120.00 10130.5 1'0130.00 1.0135.:5 10135.00 10140.5 10140.00 10145.5 10145.00 10150.5 10150.00 10155.5 10155.00 10160.5 10160.00 10165.5 10165.00 10170.5 10170°00 10175.5 10175.00 10180.5 10180.00 10185.5 10185.00 10190.5 10190.00 10195.5 10195.00 10200.5 10200.00 10205.5 10205.00 10210.5 10210.00 10215.5 10215.00 10220.5 10220.00 10225.5 10225.00 10230.5 10230.00 10235.5 10235.00 10240.5 10240.00 10245.5 10245.00 10250.5 10250.00 10255.5 10255.00 10250.5 10260.00 10265.5 10265.00 10270.5 10270.00 10275.5 10275.00 10280.5 10280.00 10285.5 10285.00 10290.5 10290.00 Page 26 24-F EB-87 lC:07 ( ¢ ( 102~$.00 10295.5 1029S.00 ¢ ¢ ¢ ( ¢ ( ( ( ( ( ( ( ( ¢ ( ( ¢ Well: TAK~56 Oep th GR S N R DP t~E $ RPN ,Depth F CNTS OHN/H2 !:T/HR KLBS RPN F Page 27 24-F EB-87 10:07 10300.00 10305.00 10310.00 10315.00 10320.00 10325.00 10330.00 10335.00 1034 Oo O0 10345.00 10350.00 10355.00 1036,0.00 10365.00 103T0,00 10.375.00 10380.00 10385.00 10350.00 1 10415,00 10420.:00 10!425.00 :t 0._3~0. O0 1:0435.00 1044 O. O0 1044 5.00 10450.00 10455.00 1046.0.00 10465.00 104'/0o00 10475.00 10480. OO 10485.00 10490.00 10495..00 10500. O0 10505.O0 10510.00 t0515,. O0 10520.00 10525.00 10530.00 10535.00 10540.00 10545,.00 10550.00 IOSSS.O0 10560.00 105~55.00 119. 124. 122. 119. 124- 105. 126. 129. 129. 115. 131, 108. 121. 103. 119. 113. 132. 144. 131. 131o 11 116. 126. 10 9. 113o 115o 124. 123. 130. 105- 124-. 130. 122. 130. 107. 126. 123. 147. 117. 114. 140. 131. 121. 131. 130. 120. 149. 124. 151 o 133. 131. 4.63 4..66 4.57 4.62 4.66, 4.82 4.79 4.63 4.44 4.50' 4.30 4.44 4.53 4.27 4.57 4.88 4.95 4.81 4.69 4.47 4.47 4~I'3 4.04 4.02 3.96 3.91 3,, 78 3.28 4.1'5 4.02 3.94 3.91 3.94 3.99 4.24 3.9~ 4.57, 4.50 4.50 4,35 4.45 4.75 4.75 4.85 4.75' 4.88 ~.75 20.7 21.2 20.5 23.5 22,9 22.8 22.8 23.3 22.5 22.7 23. 4 21.2 21.8 20.9 22.9 1.4.9 24.7 22.4 22°0 20.8 21.5 2I .4 20,,7 20.7 23.3 25.5 22.7 22:.0 22.3 2'1.7 22.6 20.8 21.1 21.5 19.9 23.5 2.2.5 23.5 23.6 23.4 23.4 2-5.3 23.5 23.3 22.1 21.7 22.1 22.2 22.7 62.7 10300.5 61.0 10305.-5 63.2 10310.5 61.1 10!315.5 67'0 10320-5 61.8 10325.5 61.4 10330.5 62.0 103.35.5 64.0 10340.5 65.2 10345,5 65.4 , 10350.5 63.8 10355.5 64.7 10360.5 64.0 10~65~ 5 63.1 10370~5- 45,3 10375.5 69.1 10380.5 69.8 10385.5 69.1 10390.5 10300.00 103 0~. O0 10310,00 10315.00 I03~0,00 10325.00 10330.00 103 3 S. 00 10340.00 lO345.oo 10355.00 10360.00 103&5~00 103'70-,00 10375°00 103 80'. 00 103 95,00 10390.00 66. I 58.1 1 o~x'~. 5 104 I5 .oo 62.0 10420.5 10420-00 61 ~ 9 I 0.4~25. S 104 25 - 80 61~9 ~1D~30~S,~ *~0430a00 67.8 10435.5 I0435.00 64.9 10440.5 10440.00 56.2 10445.5 10445.00 63.4 10450'5 10450.00 59.8 10455.5 10455.00 51.1 10~60.5 10460.00 71.3 10465.5 10465.00 60.T 10470.5 10470.00 64.2 10475.5 10475.00 68.1 10480.5 10480000 59~.8 10485.5 10485.00 65.5 10490.5 10490.00 66.5 10495.5 10495.00 63.2 10500.5 10500.00 62.8 10505.5 10505.00 64.0 losio.5 2osxo.oo ~.~ 2o52o.5 xoszo.oo 62.1 10525.5 10525.00 65.2 10530.5 10530.00 ~7.7 ~o535.~ ~o~3~.oo 64.9 10540.5 ~3.~ 2o5~5.~ ~o545.oo 6~.7 2o5~o.5 ~o55o.oo 51.2 10555.S 10555.00 ~.~ lo5~o.~ ~o~6o.oo e~.~ ~o5~.~ ~o~65.oo 105'/0.00 133. 23.3 10570.5 10570.00 Depth F CNT.S OHM,,*H2 FT/HR 10575.00 152. 4072 Z1.4 10580000 123. 4.69 21 10585.00 140. 4.38 16.5 10590.00 138. 4~50 18.9 10595. O0 108, 6.13 2I. 2 10600.00 130. 4.50 22.6 10605.00 123. 10610. OO 13 ~. 4.41 22.2 10615.00 142. ~.63 21.1 t062'5:. O0 1 10630000 109. ~-88 21.8 10635.00 149. 4.63 21.3 10640,. 00 116. ~.7'5 27.2 10645.00 123. ~.69 22,5 1065 O. O0 128. ~. 63 21.6 10660.00 laZ. ~.7S 23.0 10665,00 I19. ~.69 21.0 I0690.00 10695',00 '10~:100. O0 lO7OS..oo 10710.00 10720.00 10725000 1,07,3,o. 00 10735,00 1074,0o00 10745. O0 10750000 10755000 10760°00 10765.00 lo77o, oo 10775000 10780.00 10785. o0 107S0o00 10795. O0 10800°00 10805.00 10810000 10820.00 108'25.00 10830.00 10835.00 10840.00 146o 119. 130o 119, I03. 121. 118., 135. 12t. 122. 129. 116. 1~ 9. 118. 120. 115. 131. 129, 124. 114. 130. 144. 133. 134. 152. 133. 4.57 ZO-,. 2 4.33 Z2.1 4.38: 22.3 4.38 25.8 4.13 23.0 3.96 22 3o51 24.4 3.53 2606 3.86 24.4 3.63 24.6 3, 80 21.4 3.75 23,,7 3.60 23.7 3.05 24.0 3.13 23.1 3,47 -22.3 3.70 22.4 3.53 24.4 3.63 23.7 3.37 32.6 3oll 22.4 3.58 22.3 3.83 22.7 3.52 22.2 3.63 23.1 ~,.02 23.0 4.1~.. 23,,6 ~.50 22.8 4.82 2.3.0 ~+.32 Z3.8 14t:8 RPM Depth KLBS RPM F 60.6 10575.5 10575.00 62.8 10580,,5 10580.00 60.1 10585.5 10585.00 60.9 10590.5 10590.00 61,8 1059505 10595.00 63.3 1060005 10600.00 60.2 10605.5 10605.00 63.6 10610.5 10610.00 64.2 10615,5 10615.00 67ol 10620.5 %06~0 OO 60,8 10625,5 t0625~00 61.6 10630.5 10630000 60.6 10635.5 10635.00 61.4 106¢0..5 I0640..0 0 61.6 106i. 5-5 1061.5.00 61.0 10650,5 10650,00 6~,7 1065,~,. 5' 106 55. O0 63.3 10660.5 10660°00 62.6 10665.5 10665,00 64.3 10690.5 10690.00 62.7 10695.5 10695.00 ,&.7;_,6 10]OQ,AS,, LOT.QQ. QG 66.9 10705.5 i 0705,,0,0' 66,2 ' 10710.5 I0710o00 66.6 10715.5 10715.00 6.8, .'1 10720,5 10720.~00 65.4 10725.5 10725.00 67.2 .10730.5 65.-2 1,0735,,5 107.35~,,00 66,4 10740.5 10740,00 65.7 10745.5 10745.00 64.3 10750.5 10750.00 65.6 10755.5 10755,,00 65.6 10760.5 10760.00 64.4 10765.5 10765.00 64.0 10770.5 10770°00 65.8 10775.5 10775.00 62.9 10780.5 10780.00 68.4 10785.5 10785.00 62.5 1.0'790.5 64.3 1079505 10795.00 61.7 10800.5 10800.00 6~.1 10805.5 10805.00 63.1 10810.5 10810.00 62,9 10815.5 10815.00 62.9 I0820.5 10820.00 64.2 10825.5 10825,.00 64.0 10830.5 10830.00 61.6 20835.5 I0835.00 65.9 10840.5 10840.00 Pa_ce 28 24-FEB-87 10:07 10845o00 118o 5o-~5 24.1 62,.8 108~5.5 1084.5.00 C W~il: TAK~55 Depth GR Sh ROP F CNT$ OhM/M2 HT 10850.00 10855.00 10860.00 10865.00 10870.00 10875.00 10880.00 10885.00 10890.00 I08S5.00 10900.00 10905.00 10910.00 10915.00 10920.00 10925.00 10930.00 10935.00 10940.00 10945°00 10955.00 lO9~O,'OO 10965.00 10970.00 10.93.5.00 10980.00 10985.00 109~0.00 10995.00 11000.00 11005.00 11010.00 11015.00 11020.00 11025.00 11030.00 11035.00 11040.00 11045.00 11050.00 11055.00 11060.00 11065.00 11070.00 11075.00 11080.00 11085.00 110~0o00 11095.00 lllGO.O0 lll05.00 11110.00 llllS.00 137. 137. 142. 1AB. 148. 135. 133. 144. 143. 124. 120. 110. 111. 146. 130. 150. 140. 134. 117. 117. 122. 121. 125. 117. 12.3. 138. 119. 139. 131. 126. 139. 148. 122. 116. 152. 106. 144. 127. 137. 127. 128. 137. .126. 124. 129. 128. 125. 117. 109. 124. 122. lOZ. 142. 5.05 4.82 4.75 4.72 4.63 4.79 4.82 ~.66 4.60 4.85 5.05 4.79 5.15 5.05 5.30 4.82 5.02 5.15 5.44 5.30 5.02 ~.95 4.95 4.75 ~ 85 4.92 4.85 4.85 4.85 4.88 5.02 4.82 ~.79 4.82 5.05 4.79 4.85 4.85 ~.75 4.92 4.82. 4.75 4.65 4.53 3.78 3.5~ 3.6~ 3.78 3.6~ 3.~C /HR WCB RPM Depth KI. BS RPM F 22.7 23.0 23.8 22.4 22.7 22.5 21.4 20.7 21.5 21.5 25.1 25.9 22.3 2.3.7 23.5 22.5 22 .g 22.4 22..0 22.5 22.0 22.0 21.6 22.3 · 22.5 22.5 5.5 11.8 14.8 14.7 14.9 14.9 16.5 14.1 I5.2 12.5 12.3 12.3 12.7 12,.4 12.6 13.8 14.0 13.5- 14.7 1~ .1 14.0 12.8 13.1 12.8 65.6 10850.5 63.0 10855.5 63.9 10860.5 63.7 10865.5 61.4 10870.5 68.0 10875.5 64.2 10880.5 63.3 10885.5 61.9 10890.5 59.6 10895.5 63.2 10900.5 63.6 10905.5 63.2 I0910.5 63.9 1091,5.5 64.0 10920.5 67.2 10925.5 65.1 10930.5 64.9 10935.5 63.9 10940.5 64.5 10945.5 64.0 10955.5 69,2 10960.5 64.1 10965.5 63.0 10970.5 61.1 10975.5 61.6 10980.5 62.7 10985.5 42.7 10990.5 52.5 10995.5 55.1 11000.5 58.7 11005.5 59.8 11010.5 59.3 11015.5 59.5 11020.5 58.6 11025.5 59.0 11030.5 66.6 11035.5 65.0 11040.5 65.9 1104'5.5 58.4 11050.5 58.0 11055.5 60.1 11060.5 56.8 11065.5 56.9 11070.5 61.2 11075,5 55.9 11080.5 52.1 110~5.5 53.5 11090.5 54.0 11095.5 59.8 11100.5 59.7 11105.5 59.9 11110.5 59.6 11115.5 10850°00 10855.00 10860.00 10865.00 10870.00 10875.00 10880.00 10885.00 10890.00 10895.00 10900.00 10905°00 10910.00 t0915~00 10920.00 10925.00 10930.00 10935.00 10940.00 10945.00 109'55.00 1'0960~00 10965.00 10970.00 IOg~Z5..Q.Q_ 10980.00 10g 85.00 10990.00 10995.00 11000.00 11005.00 11010.00 11015.00 11020.00 11015.00 11030.00 11035.00 11040.00 110~5.00 11050.00 11055.00 11060.00 11065.00 11075.00 11080.00 11085.00 11090.00 11095.00 11100.00 11105.00 11110.00 11115.00 24-FEB-87 Page 29 10:07 11120.00 139. 3.7~ 11120.5 11120.00 Well: TA&556 F 11125.00 11130.00 11135.00 11140°00 11145.00 11150.00 11155.00 11160.00 11165.00 11170.00 11175.00 11180.00 11185.00 11190.00 lllgS.00 11200.00 11205o00 11210.00 11215.00 1122 Oo 00 11230.00 112.35.00 11240.00 11245°00 112.50.00 11255,00 11260,.00 11265.00 11270.00 11275.00 11280.00 llZBS.00 11290.00 11295.00 11300.00 11305.00 11310.00 11315.00 11320.00 11325.00 11330.00 11335.00 11340.00 11345.00 11350.00 11355.00 11360°00 113f5.00 11375.00 11385.00 ll3gO.O0 GR CNTS 137. 131. 127. 120. 130. I~4. 139. 153. 124. 141. 127. 211. 221. 242. 239. 227. 22Z. 205. 168. 163. 163. 1'/8. I7'7. 147. 196. 179. 200. 128. 206. 187. 179. 193. 19B. 174. 174. 2-14. 222. 187 · 200. 181. 186. 205. 179. 151. 2.15. 162. 207. 217. 3.58 3.30 3.44 3.50 3.78 3.85 3.8t 4.1~ 4.21 4.04 4.15 2.03 3.2~ 4.88 5.06 5.40 3.89 2.97 2.05 5.23 6.44 4.23 5J04 5.55 4.15 4.44 4.59 5.01 4.04 4.13 3.03 1.79 2.01 2.03 2.2g 1.93 1.~ 2°73 2.37 3.~ ~ 3.01 2.87 2.33 1. '92 2.42 ~T,,'H ~ 12.2 13.1 12.2 14.4 16.9 15.0 1,~.6 13.2 14.6 10.4 13.1 38.3 22.8 24.8 26.1 32.5 7! .0 36.0 ~6.0 24.1 30.2 35.? 27.7 28 .Z 26.6 I'B,Z 20.5 27.8 31.2 23.1 31.0 24.1 33.4 31.0 31.0 34.5 39.0 32.7 30.1 29.9 3~ .2 42.g 36°? 34.2 31.6 35.7 31.1 41.3 43.4 43.4 37.4 43.4 B RPM KLBS RPM 58.0 11125.5 57.4 11130.5 57.7 11135.5 58.7 11140.5 61.0 11145.5 63.1 11150.5 62.1 11155.5 66.1 11160.5 65.6 11165.5 59.0 11170.5 66.1 11175.5 48.3 11180.5 58.4 11185.5 58.1 11190.5 58.0 11195.5 58.6 11200.5 53.7 11205.5 58.8 11210.5 57.3 11215.5 64.7 11220.5 61.0 11230.5 58.1 11235.5 58.2 11240.5 56.5 11245'.5 59.8 11250.5 62.3 11260.5 48.7 11255.5 60.1 11270.5 58.1 11275.5 37.4 11280.5 62.2 112~5.5 63.5 11290.5 57.4 11295.5 61.9 11300.5 59.0 11305,5 60.4 11310.5 63.6 11315.5 64.~ 11320.5 65.! 11325.5 61.4 11330.5 64.~ 11335.5 60.8 11340.5 58.7 11345.5 55.5 11350.5 56.8 11355.5 53.9 11360.5 54.4 11365.5 57.7 11370.5 58.1 11375.5 55.0 11380.5 62.9 11385.5 61.4 11390.5 Cepth F 11125.00 11130.00 1113~o00 11140.00 11145.00 11150.00 11155.00 11160.00 11165.00 11170.00 11175.00 11180.00 11185.00 11190.00 11195.00 11200.00 11205.00 11210°00 11215.00 11,220°00 11230.00 1.1-2 ~5. O-O 112t0.00 11245.00 11250.00 112S'5.0'0 11260.00 11265.00 11270.00 11275.00 11280.00 11285.00 11290.00 11295.00 11300.00 11305.00 11310.00 11315.00 11320.00 11325.00 11330.00 11335.00 11340.00 11345.00 11350.00 11355.00 11350.00 11365.00 113'70.00 11375.00 11380.00 11385.00 11390.00 Page 30 24-F6B-87 10:07 1135~5. O0 153. 43.4 63.0 11395.5 11395.00 ~ ~ell: TAK556 Oe~th F 11400.00 11405.00 11410.00 11415.00 11420.00 11425.00 11410.00 11435.00 11440.00 11445.00 11450.00 11455.00 11460.00 t.1465.00 11470°00 11475°00 11480.00' 11485.00 114f0.00 1! 49 5o 00 - 1150 S.O0 11515.00 115i0.00 11525.00 11530';00 115~S.0.~ 11540.00 I1545.00 11550.00 11555°00 11560.00 llS6S,.oo 11570.00 11575°00 11580.00 11.585~00 11390°00 11595.00 11660°00 11665.00 11610.00 11615,00 11620.00 116~.00 11630.00 11635.00 11640.00 11645°00 11650.00 11655.00 11660.00 11665.00 GR CNTS 182. 147. 203. 24 5. 251. 203. I81. 163. 183. 183. 280. 207. 170. 200. 219. 217. 22 3. 207. 229. 210. 24,2, 22'5. 216. 199. 202. 189. 195. 211. 177. 181. 228. 238. 186. 206. 202. 22 6~ 204. 191. 155. 150. 150. 168. 164. 155. 150. 155. 166. 165. 175. 146. 164. Sh ROP OHM/Mi FT/HR 3.74 29.8 4.02 22.2 Z.44 30.6 4.24 24.4 2.43 35.9 3.47 30.9 3.63 18.7 2.56 18.2 3.07 30.6 4.57 29.2 3.24 20.6 3.1f 26.2 2.5S 34.8 2.63 38.2 2.49 3'0.3 2.37 19.0 3.63 24,9 2..77 20.7 3.53 18.8 3,.~,96 2 Go 8 5.05 22..3 5.09 19.8 4.92 20.3 4.50 18.6 4,'80 2I',5 6.14 21.1 4.30 19.4 4.21 19.6 4.10 2'4.4 4.33 17.2 5.51 20.7 5.40 19.2 ,4.16 19.7 5.66 22.5 6.57 23.4 6.98 22.0 5.32 Z6.2 3.7.0 36.7 2.91 26.9 2.54 30.8 3.07 25.2 4.07 36.3 3.75 28.4 2.63 33.4 4.44 30.6 4.24 27.0 ~.03 37.5. 3.99 40.0 4.95 40.2 W.5~ 37.4 4.79 34.1 6.7I 31.6 WCB KLBS 63.5 51.0 61.2 55.6 57.0 62.4 56.6 57.7 62.9 59.7 58.1 56.1 59.9 60.4 64.1 60.9 54.4 59.8 63.9 60.7 $7.2 65.1 63.9 63.2 61.0 61,5 57.5 58.0 56.8 59.7 63.6 57.7 62.5 61.9 62.9 64.2 62.3 63.1 59,1 60.9 56.9 59.3 57.4 59.0 57.2 57.8 57.6 56.9 58.0 58.7 58.9 58.0 ~7.6 RPN RPM 11400.5 11405.5 11410.5 11415.5 11420.5 11425.5 11430.5 11435.5 11440.5 11443.5 11,450.5 11455.5 11460.5 11470.5 11475.5 11480.5 11485.5 11490.5 1 ! 505..5 11520.5 1152~.5 11535.5 115t0.5 11545.5 11550.5 11555.5 11560.5 11'565.5 11570.5 11575.5 11580.5 11585.5 11590.5 11596.0 11601.0 11696.0 1i6ti.0 11616.0 11621.0 11626.0 11631.0 11636.0 11641.0 11646°0 11651.0 11656.0 11661.0 11666.0 Depth F 11400°00 11405.00 11410.00 11415.00 11420.00 11425.00 11430.00 11435.00 11440.00 114¢5.00 11450.00 11455.00 11460.00 11465.00 11170.00 11475.00 114 80.00 114 85.00 11490.00 1 t4 9. 5~..00 ..... 11505.00 11515.00 11520'.00 1-15~5.00 I1530.00 11535.00 11540.00 11545.00 11530.00 1.1555,,00 11560.00 I"1.565,00 11570.00 11575.00 11580.00 11585,00 11590.00 11595.00 11600..00 11605.00 11610.00 11615.00 11620.00 11625.0O 11630.00 11635.00 11640.00 11645.00 11650.00 11655.00 11660.00 11665.00 Page 31 24-F EB-87 10:07 11(~70.00 1~3. 7.$2 ¢ ¢ ¢ ¢ ¢ ( C ¢ ( C well: 1~K55~ Del;th GR S!%' RDP WE B RPM Depth F CNTS 0~ M/M2 FT/HR KL BS RPM F 11615.00 142. 11680.00 146. 11685.00 173. 11650.00 11695.00 161. 117{30.,00 140. 117{35.00 153. 11710.00 172. 11715.00 156. 11720.00 148. 11725.00 183. 11730.00 165. 11735.00 150. 11740.00 i47. 11745,00 154. 11750.00 127. 11755.00 142. 11760.00 116. 11765.00 125. 11770.00 151. 117.6o. oo 17o. 117.5.oo 179. 11790.00 188. 11795.00 170. 118{30.00 194. 11805-~00 18!. 11810.00 175. 11815.00 191. 11820.00 238. 11825.00 219. 11830. O0 219. 1183.5.00 244. 11840.00 209. 11845. O0 237. I1850.00 189. 11855.00 249. 11860.00 11865.00 198. 11870.00 241. 11875.00 227. 11880.00 344. 11805.00 256. 11890.00 2.43. 11855.00 11900.00 268. 11905.00 266. 11910.00 239. 11915.00 269. 11920.00 ZE2. 11925.043 276. 11930.00 228. 11935.00 !6~. 119~0.0~ 21:3. 5.3{3 5.44 5.44 ~+.15 4.37 4.85 '4.44 3.80 5.70 5.59 6.06 7.32 6.53 7.37 7.27 10.12 8.86 9.65 7.69 6.71 5.9{2 6.89 7.88 7.37 6.57 2.90 4.35 4.81 ~.15 4.66 4.57 5.09 4.50 4=30 5.15 5.29 5.12 ~.02 6. lC 5.37 5.6~ 5.23 5.$~ 5.63 5.i0 5.12 5.48 5.09 39.0 33.4 32.4 2.3.2 26.9 27.1 27.6 4O .6 2.6.5 34.6 24.3 29 .O 2-3.8 36.2 29.1 27.7 31.7 33.0 28.9 24.7 24 .B 27,7 33.9 30.9 35.3 21.9 18.9 22.4 27.0 32.0 21. Z 19.3 27.3 28.3 27.9 29.5 28.3 32.2 26.9 35.1 32 .'3 33.3 38 34.5 34.6 39.0 34.0 31.1 33.5 31.4 22.4 25.0 24.1 59.7 58.4 57.8 59.9 58.0 57.4 57.9 59.1 60.9 57.8 63.7 63.5 63.3 60.1 59.7 59.8 60.6 60.4 61.2 61.8 60.5 60.0 62.5 60.3 58.2 60.7 63.8 56.3 57.0 59.3 54.9 56.3 58.2 58.5 61.5 58.0 56.6 58.1 55.0 .53.4 54.9 53.8 55.5 55.3 54.7 54.6 55.2 55.7 58.1 52.4 56.8 55.9 11676.0 11675.00 11681.0 11680.00 11686.0 11685.00 11691.0 11690.00 11696.0 11695.00 11701.0 11700.00 11706.0 11705.00 11711.0 11710.00 11716.0 11715.00 11721.0 11720.00 11726.0 11725.00 11731.0 11730.00 11736.0 11735.00 11741.0 11740.00 11746.0 11745.00 11751.0 11750,00 11756.0 11755.00 11761.0 11760°00 11766.0 11765.00 11771.0 11770.00 11781.0 11780-00 11786.0 11785.00 11791.0 11790.00 11796.0 11795.00 11801.0 11800.00 11806.0 '11805.00 11811.0 11810.00 11816.0 11815.00 1182-1.0 11820.00 11826.0 11825.00 11831,0 11830.00 11836.0 11835.00 11841.0 11840.00 11846.0 11845.00 11851.0 11850.00 11856.0 11855.00 11861.0 11860.00 11866.0 11865.00 11871,0 11870,00 118'76.0 11875.00 11831.0 11880.00 11886.0 11885.00 11891.0 1t890.00 11996.0 11895.00 11901.0 11900.00 11906.0 11905.00 11911.0 11910.00 11916.0 11915.00 11921.0 11920.00 11926.0 11925.00 11931.0 11930.00 11936.0 11935.00 11941.0 11940.00 Page 32 24-F EB-87 10:07 11945.00 278° 56.3 11946.0 11945.00 ( (. ( Del=th F i1950o00 11955.00 11960°00 11965.00 11910,,00 11975.00 119~0o00 11985°00 11990°00 11995,.00 12000.00 12005.00 12010.00 12 015.00 12020.00 12025.00 12030.00 12035.00 12040.00 1204 5. O0 12055.00 t206 0"00 12065°00 12070.00 12075.00 12080.00 12085°OO 12090.00 12095°00 12100.00 12105.00 12110.00 12115.00 12120.00 I2125.00 12130.00 12135.00 GR CNTS OHM/M2 260. 5.09 271. 5.55 291. 5.70 226. 5.02 224. 5.09 260. 6.14 261. 5.52 205. ~+.50 240. 4.66 275. 4.41 352. 4.95 374. 3.51 334. 3.96 260. 4.55 209. 3.60 284. 4..30 181. 3.15 210. 3.17 206. 3.80 285. 6.27 RDP WI:5 RPM Depth ;T/HR KLBS RPM F 30.5 55.3 11951.0 11950.00 33.2 53.6 11956.0 11955.00 30.5 53.1 11961.0 11960.00 35.6 52.1 11966.0 11965.00 33.7 52.7 11971.0 11970.00 34,3 52.5 11976.0 11975.00 34.9 54.0 11981.0 11980.00 31.2 53.6 11986.0 11985.00 Z8.7 57.5 11991.0 11990.00 32.2 53.3 11996.0 11995.00 37,3 54.4 12001°0 12000.00 32.2 51.6 12006.0 12005.00 29.2 51.0 12011.0 12010,,00 31,,2 57.8 1201-6.0 1ZO1S.O0 28.5 53.3 12021.0 12020,00 Z8.1 54.6 1ZOZ6.0 12025.00 27.2 53,9 1203'1',0 12030,00 24.6 57.0 12036.0 12035.00 23.8 57.0 12041.0 12040.00 28- 8 54.6 ~ 20,46',:~. 0 1 22.6 52.3 la 05&-0 1Z0,55. O0 32-3 54.0 12066°0 12065.00 24.5 51,,2 12071.0 12'070.00 25.4 54.6 12076.0 1207S,.00 29 . 8 '}53 '~'~- 1208':~. 0 12018]I~' 0~0' 26.7 52.4 12086.0 12085.00 29.0 51.6 12091.0 12090.00 29.3 59.1 12096.0 12095.00 28.3 56.3 12101.0 12100,.00 22.4 51..9 12106.0 1Z105.00 23.1 54.0 12111.0 12110.00 21,2 53.6 12116.0 12115.00 20.5 51.9 12121.0 12120.00 ZO.l 56.9 12126.0 12125.00 24.1 52.9 12131.0 12130.00 12136.0 12135.00 Page 33 24-F E9-87 10:07
