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Home My WebLink About187-020MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, May 14, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC 3-35 DUCK IS UNIT SDI 3-35 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 05/14/2025 3-35 50-029-21701-00-00 187-020-0 W SPT 9686 1870200 2422 1975 1967 1954 1976 11 203 196 193 REQVAR P Josh Hunt 4/15/2025 2-Year MIT Required by AIO 1.011. Very solid test. 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 3-35 Inspection Date: Tubing OA Packer Depth 596 2660 2648 2641IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH250415160846 BBL Pumped:6.1 BBL Returned:5.3 Wednesday, May 14, 2025 Page 1 of 1 9 9 9 9 9 9 9 9 999 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.05.14 13:47:01 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, June 1, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC 3-35 DUCK IS UNIT SDI 3-35 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/01/2023 3-35 50-029-21701-00-00 187-020-0 W SPT 9686 1870200 2500 2062 2073 2084 2092 189 313 303 305 REQVAR P Guy Cook 4/28/2023 MIT-IA every two years to maximum injection pressure per AIO 1.011. Testing was completed with a Little Red Services pump truck and calibrated gauges. 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 3-35 Inspection Date: Tubing OA Packer Depth 1466 2699 2679 2674IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC230427141446 BBL Pumped:3.2 BBL Returned:3 Thursday, June 1, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 999 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2023.06.01 15:02:22 -08'00' MEMORANDUM TO: Jim Regg -�gt� 511g(z-,M, P.I. Supervisor FROM: Austin McLeod Petroleum Inspector Well Name DUCK IS UNIT SDI 3-35 Insp Num: mitSAM210504192648 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, May 13, 2021 SUBJECT: Mechanical Integrity Tests Hilcurp North Slope, LLC 3-35 DUCK IS UNIT SDI 3-35 Ste: Inspector Reviewed By: P.I. Supry Comm API Well Number 50-029-21701-00-00 Inspector Name: Austin McLeod Permit Number: 187-020-0 Inspection Date: 5/4/2021 Packer Well 335 --jTypelnj w -TVD .PTD 1970200 ".Type Test sir Test psi BBL Pumped: L9 BBL Returned: Interval. REQVAR P/F Notes: 2 year MIT -IA to MAIR A10 1.011 ✓ Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 9686 'Tubing 1 2140 - 2120 - 2120 - 2120 2500 IAT1888 2754 2750 - 2748 — 1.7 - OA 280 - 380 - 360 - 360 - P ✓ Thursday, May 13, 2021 Page I of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Rgg �e DATE: Wednesday, May 8, 2019 q/CG P.I. Supervisor SUBJECT: Mechanical Integrity Test sq HILCORP ALASKA LLC 3-35 FROM: Brian Bixby DUCK IS UNIT SDI 3.35 Petroleum Inspector See: Inspector Reviewed Bv: P.I. Supry - b r_ NON-CONFIDENTIAL Comm I Well Name DUCK IS UNIT SDI 3-35 IInsp Num: mitBDB190507123116 Rel Insp Num: API Well Number 50-029-21701-00-00 Inspector Name: Brian Bixby Permit Number: 187-020-0 Inspection Date: 5/6/2019 Packer Depth Well 3-35 Type Inj w ,TVD 96M, Tubing PTD L 1870200 Type Test SPT iTest psi soo j 1.4 BBL Pumped: 3 5 " BBL Returned: OA Interval REQvAR PY Notes: MIT -IA as per AIO 1.0 1 I. ✓ Pretest Initial 15 Min 30 Min 45 Min 60 Min 3(197 '101 2075 - 2109' II80 2750 2745 2740 200 352 347 347 Wednesday, May 8, 2019 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,May 11,2017 TO: Jim Regg .8elc `�((a(f 7 P.I.Supervisor ( I SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC 3-35 FROM: Jeff Jones DUCK IS UNIT SDI 3-35 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 2 NON-CONFIDENTIAL Comm Well Name DUCK IS UNIT SDI 3-35 API Well Number 50-029-21701-00-00 Inspector Name: Jeff Jones Permit Number: 187-020-0 Inspection Date: 5/6/2017 Insp Num: mitJJ170506181405 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3-35 ' Type Inj W TVD 9686 ' Tubing 1300 r 1300 " 1300 - 1300 - 1300 1300 PTD 1870200 Type Test SPT Test psi 2500 IA 508 2636 - 2634 .1 2628 , 2622 - 2617 • BBL Pumped: 5.1 - BBL Returned: 5.1 • OA 260 420 420 - 420 420 • 420 Interval REQVAR P/F P Notes: 2 year MIT per AA AIO 1.011;PWI only,max injection pressure 2500 psi.This test was extended to further demonstrate mechanical integrity. 1 well inspected,no exceptions noted. SCANNED J() Thursday,May 11,2017 Page 1 of 1 • . Post Office Box 244027 Anchorage,AK 99524-4027 Ji Hilcorp Alaska,LLC L 3 0 20h 3800 Centerpoint Drive Suite 100 AOG CC 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 D ©g-0 Anchorage, AK 99501 3_ 3Z � .DlO P o Re: Duck Island Unit Well Renaming Request �C11T'v 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 S Orig • New I API_WeliNo I PermitNumber' WellName I WeIlNumber I WeIlNumber 50029219460600 2032160 DUCK IS UNIT SDI 3-17F/K30 3-17F 50029224630000 1940490 DUCK IS UNIT SDI 3-19/R28 3-19 50029217140000 1870330 DUCK IS UNIT SDI 3-21/L34 3-21 50029217149500 1980190 DUCK IS UNIT SDI 3-21AK35XX 3-21AXX 50029216450000 1861550 DUCK IS UNIT SDI 3-23/N32 3-23 50029221250000 1901820 DUCK IS UNIT SDI 3-25/M27 3-25 50029221250100 2010200 DUCK IS UNIT SDI 3-25A/N24 3-25A 50029221250200 2030210 DUCK IS UNIT SDI 3-25B/L27 3-25B 50029215860000 1860830 DUCK IS UNIT SDI 3-27/M33 3-27 50029221060000 1901560 DUCK IS UNIT SDI 3-29/J32 3-29 50029228380000 1972270 DUCK IS UNIT SDI 3-31/K32 3-31 50029216680000 1861800 DUCK IS UNIT SDI 3-33/K37 3-33 50029216680100 2032150 DUCK IS UNIT SDI 3-33A/J35 3-33A 50029217010000 1870200 DUCK IS UNIT SDI 3-35/136 3-35 50029225540000 1950510 DUCK IS UNIT SDI 3-37/L35 3-37 50029217640000 1871160 DUCK IS UNIT SDI 3-39/J39 3-39 50029217640100 1970910 DUCK IS UNIT SDI 3-39A/I37 3-39A 50029218780000 1881260 DUCK IS UNIT SDI 3-41/K39 3-41 50029224160000 1931700 DUCK IS UNIT SDI 3-43/P36 3-43 50029218110000 1880510 DUCK IS UNIT SDI 3-45/M39 3-45 50029215690000 1860640 DUCK IS UNIT SDI 3-47/Q35 3-47 50029217350000 1870600 DUCK IS UNIT SDI 3-49/140 3-49 50029217350200 1970570 DUCK IS UNIT SDI 3-49A/M40 3-49A 50029217359500 1950350 DUCK IS UNIT SDI 3-49AJ40XX 3-49AXX 50029217890000 1880220 DUCK IS UNIT SDI 4-02/028 4-02 50029219680000 1890860 DUCK IS UNIT SDI 4-04/T26 4-04 50029219680100 2090190 DUCK IS UNIT SDI 4-04A/T30 4-04A 50029217230000 1870430 DUCK IS UNIT SDI 4-06/032 4-06 50029217230100 1961660 DUCK IS UNIT SDI 4-06A/Q30 4-06A 50029216920000 1870080 DUCK IS UNIT SDI 4-08/P27 4-08 50029224640000 1940500 DUCK IS UNIT SDI 4-10/M28 4-10 50029224640100 2022380 DUCK IS UNIT SDI 4-10A/L28 4-10A 50029218630000 1881040 DUCK IS UNIT SDI 4-14/R34 4-14 50029218630100 2080120 DUCK IS UNIT SDI 4-14A/S-37 4-14A 50029218960000 1881490 DUCK IS UNIT SDI 4-18/530 4-18 50029216400100 1861730 DUCK IS UNIT SDI 4-20/M35 4-20A 50029216400000 1861500 DUCK IS UNIT SDI 4-20/T34 4-20 50029218350000 1880720 DUCK IS UNIT SDI 4-26/034 4-26 50029218700000 1881110 DUCK IS UNIT SDI 4-28/N37 4-28 50029225590000 1950690 DUCK IS UNIT SDI 4-32/K38 4-32 50029227050000 1961550 DUCK IS UNIT SDI 4-34/038 4-34 50029224820000 1940740 DUCK IS UNIT SDI 4-38/K34 4-38 50029222650000 1920420 DUCK IS UNIT SDI 4-40/P43 4-40 50029217310000 1870560 DUCK IS UNIT SDI 4-42/P38 4-42 50029222540000 1920190 DUCK IS UNIT SDI 4-44/M44 4-44 50029222549500 1970470 DUCK IS UNIT SDI 4-44AM40XX 4-44AXX 50029219570000 1890690 DUCK IS UNIT SDI 4-46/N39 4-46 50029219720000 1890970 DUCK IS UNIT SDI 4-48/K43 4-48 50029219400000 1890440 DUCK IS UNIT SDI 4-50/K41 4-50 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Thursday,May 07,2015 P.I.Supervisor � ç/s 1f 1j SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC 3-35/L36 FROM: Johnnie Hill DUCK IS UNIT SDI 3-35/L36 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry Tie— NON-CONFIDENTIAL Comm Well Name DUCK IS UNIT SDI 3-35/L36 API Well Number 50-029-21701-00-00 Inspector Name: Johnnie Hill Permit Number: 187-020-0 Inspection Date: 4/28/2015 Insp Num: mitJWH150505105413 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3-35/L36 - 'Type Inj W-TVD T 9686 Tubing 2390 - 2390 1 2390 - 2390 PTD 1870200 . Type Test SPT Test psi 2500 IA 1542 2505 ' 2503 ' 2502 - Interval REQVAR P/F P ✓ OA 410 500 500 500 - Notes: this is an AA well max injection is 2500psi Ai0 bull me MAY 2 2 2015- Thursday, 0'15Thursday,May 07,2015 Page 1 of 1 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. ] ~ ~- ~) ~ b Well History File Identifier Organization ~one) RESCAN [] Color items: n Grayscale item s: [] Poor Quality Originals: [] Other: DIGITAL DATA [] Diskettes, No. [] Other, No/Type TOTAL PAGES: ~~ NOTES: ORGANIZED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: OVERSIZED (Scannable) r~ Maps: Other items scannable by large scanner OVERSIZED (Non-Scannable) Logs of various kinds Other IS/ Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl Scanned {done) PAGES: ~ 0 (at the time of scanning) SCANNED BY; fB~EVERL'~ BREN VINCENT SHERYL MARIA LOWELL ReScanned {done) RESCANNEDBY: BEVERLY BREN VINCENT SHERYI{ MARIA~ LOWELL DATE: Isl General Notes or Comments about this file: PAGES: Quality Checked (done) Rev 1NOTScanned.wl:)d MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 'R e e f. L 1 1 0 1 t l3 DATE: Tuesday,May 07,2013 P.I.Supervisor // SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC 3-35/L36 FROM: Jeff Turkington DUCK IS UNIT SDI 3-35/L36 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry f' NON-CONFIDENTIAL Comm Well Name DUCK IS UNIT SDI 3-35/L36 API Well Number 50-029-21701-00-00 Inspector Name: Jeff Turkington Permit Number: 187-020-0 Inspection Date: 5/2/2013 Insp Num: mitJAT130502063428 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 3-35/L36 - 2849 86 Type Inj 1 W lest 9686 ' ' IA 723 2858 — 2867 Well II �PTD 870200 , Type Test',SPT,Test psi l 2500 OA 196 399 370 369 Interval iIREQVAR �P/F P 2212 2201 Tubing 2197 2218 Notes: AA AlO 1.011;slow T x IA,PWI only,5.46 BBL to fill NEp FEB 2 4 2014 SCAl Tuesday,May 07,2013 Page 1 of 1 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 22, 2012 Mr. Jim Regg 0 (6. Alaska Oil and Gas Conservation Commission f l 1 333 West 7 Avenue 6--•° S ` � 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 0 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 END3-01 / 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 - pEND3 - / 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 DATE: Monday, May 09, 2011 TO: Jim Regg l P.I. Supervisor e1 j 5 1 l 7 Il SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 3- 35/L36 FROM: Lou Grimaldi DUCK IS UNIT SDI 3- 35/L36 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name: DUCK IS UNIT SDI 3- 35/L36 API Well Number: 50-029-21701-00-00 Inspector Name: Lou Grimaldi Insp Num: mitLGI 10507181705 Permit Number: 187 -020 -0 Inspection Date: 5/7/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Mm. 3- 35/L36 9686 , I A 465 3000 ' 3000 T 3000 - Well T yp e InJ_ TVD P.T.D 1 1870200 TypeTest 1 SPT Test psi 1 3000 - OA 10 210 195 195 Interval RE p/F P - Tubing] 1soo 1800 1800 � 1820 Notes: MIT for AA compliance. 6.2 Bbl's Meoh pumped, well fluid packed. Good test. AI-0 1,0L1 Monday, May 09, 2011 Page 1 of 1 • • Page 1 of 1 Regg, James B (DOA) '~ ~ ~'~~ ~ From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Friday, August 21, 2009 8:42 PM To: Regg, James B(DOA) ~P~~} d~Z~~i:`~ Subject: RE: Admin Approval Request - END 3-35 (PTD 1870200) ( Attachments: MIT END 3-35 09-22-08.xis; MIT END 3-35 05 28-Q9.xls Jim, I have attached the following MIT forms for END3-35 per your request. / Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator ~;,~°a''~~3~ ~l1 ~a .~4 ~'~ ~~'.D~~ i Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Thursday, August 20, 2009 10:45 AM To: NSU, ADW Well Integrity Engineer Subject: Admin Approval Request - END 3-35 (PTD 1870200) We do not have a record of MITs done 9/22/OS and 5/28/09; please forward Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 8/24/2009 • . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Endicott / Duck Island / END 05/28/09 ~ Torin Roschinger Packer Depth Pretest Initial 15 Min. 30 Min. Well END3-35 Type Inj. W TVD ~ 9,686' Tubing 920 920 920 920 Interval P.T.D. 1870200 ' T pe test M Test psi ~Z421.5 Casing 1,480 ~3,000 2,980 ~ 2,980 P/F P Notes: OA 400 520 520 520 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D = Driliing Waste G=Gas I = Industrial Wastewater N = Not Injecting W = Water TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R= Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test ~ INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in notes) MIT Report Form BFL 11/27/07 MIT END 3-35 05-28-09.x1s ~~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Endicott / Duck Island / END 09/22/08 ~ Torin Roschinger Packer Depth Pretest Initial 15 Min. 30 Min. Well END3-35 Type Inj. W ND 9,686' Tubing 800 850 850 850 Interval P.T.D. 1870200 ` Type test M Test psi ~2421.5 Casing 240 ~3,000 2,980 2,960 ~ P/F P Notes: OA 0 0 0 0 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubin Interval P.T.D. Type test Test psi Casin P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. T pe test Test si Casing P/F Notes: OA Well Type Inj. TVD Tubin Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R= Internal Radioactive Tracer Suroey A = Temperature Anomaly Survey D = Differential Temperature Test r INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in notes) MIT Report Form BFL 11/27/07 MIT END 3-35 09-22-OS.xls OPERABLE: Endicott 3-35/L-3fZ(PTD #1870200) Stable IA Pressure • Page 1 of 3 Schwartz, Guy (DOA sponsored) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Wednesday, June 17, 2009 9:31 PM /~~~' ~ ~ C3~ To: Schwartz, Guy L (DOA); Regg, James B (DOA) l~ Cc: NSU, ADW Well Integrity Engineer Subject: RE: OPERABLE: Endicott 3-35/L-36 (PTD #1870200) Stable IA Pressure Attachments: 3-35. pdf Guy, I have numbered my response below to correspond with each of your numbered questions. 1. The OA pressures are read from a gauge and manually entered daily. The gauge is likely a 3000 psi gauge which would explain a somewhat consistent OA pressure reading. 2. The IA and OA pressure increases on the TIO plot are observed right after the IA was liquid packed for compliance testing and the injection temperature was increased. It is very common for the OA to be liquid packed. 3. There is no recorded bleed on 05/23/09. However, the well was briefly shut-in and swapped from a warmer injection fluid (LoSal) to a cooler fluid (PWI). This would explain the reduction in the IA and OA pressures given both annuli are liquid packed. 4. The injection rate appears to have been increased starting 06/01/09. 5. The shut-in period on 05/14/09 was brief and was only to change injection fluids. We at that point; swapped to the warmer LoSal fluid. This explains the increased IA pressure. 6. The report only plots wells for a specified six month time frame. Each month when we send the report to your office we ensure the end of the previous month is the last data point plotted. So the report you received earlier this month only covers data through the end of May. The plot previously attached by Anna included the more recent data. ! am not sure what the question involving the difference in tubing pressure between the spreadsheet and plot is asking. The data in the right-hand columns is the same data used to develop the plot that Anna emailed you earlier. Each plot in the spreadsheet is developed by plotting the TIO/injection data in the columns directly below each plot. I have attached the wellbore schematic as requested. Please let me know if you have additional questions. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 A(~r ~ ~ ~a~~J .M1T wYY"'l/~~' cL From: Schwartz, Guy (DOA sponsored) [mailto:guy.schwartz@alaska.gov] Sent: Wednesday, June 17, 2009 2:05 PM To: Regg, James B (DOA); NSU, ADW Well Integrity Engineer Subject: RE: OPERABLE: Endicott 3-35/L-36 (PTD #1870200) Stable IA Pressure Anna/Andrea: I am having trouble understanding the sequence of events in SDI 3-35/L-36. Can you please clarify a few issues for me.? 6/18/2009 OPERABLE: Endicott 3-35/L-3f~(PTD #1870200) Stable IA Pressure • Page 2 of 3 1. Are OA pressures read from an analog gauge and entered manually? (they seem way too consistent to be wellhead pressure reading) 2. What is going on with the OA pressure?. It appears to be tracking the IA all of a sudden. 3. Was there another bleed done on about 5-23-09 ? IF not what caused the drop in pressure. 4. What is going on with the tubing pressure starting 6-1-09... was injection rate increased causing higher pressure? 5. The first initial IA pressure buildup on 5-14-09 happened during a brief shut in period. Any thoughts on why?? 6. What data is valid after 5-12-09?? Is this latest plot accurate thru 6-6-09??The monthly injection data spreadsheet has some strange outputs too. Tubing pressures do not match what is plotted. Hope these questions make sense... please feel free to call me if it would be helpful to have a dialog on the phone. Could you also resend a schematic also. Thanks in advance. Guy Schwartz AOGCC 907-793-1226 From: Regg, James B (DOA) Sent: Wednesday, June 17, 2009 9:35 AM To: Schwartz, Guy L (DOA) Subject: FW: OPERABLE: Endicott 3-35/L-36 (PTD #1870200) Stable IA Pressure Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Friday, June 12, 2009 3:51 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); END/BAD Area Manager; END, 0&M TL; END, Operations Lead Tech; END, Board Operator; END, Production Coordinator; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Soto, Jose A; Anderson, Robert L; Dahl, Norm; Grimes, Jeremy M (ASRC ENERGY SERVICES); Hernandez, Rogelio (ASRC ENERGY SERVICES); Houser, John (ASRC); Hume, Ky A; Hyland, Wilf (ASRC ENERGY SERVICES); McBride, Larry D. Cc: Quy, Tiffany; NSU, ADW Well Integrity Engineer Subject: OPERABLE: Endicott 3-35/L-36 (PTD #1870200) Stable IA Pressure All, Endicott well 3-35/L-36 (PTD #1870200) has not exhibited IA repressurization since the IA pressure was bled on 05/26/09 and again on 06/07/09. The well has been reclassified as Operable but will remain on the AOGCC Monthly Injection Report for continued monitoring. A recent TIO plot has been included for reference. «3-35-L-36 TIO Plot.doc» Please let us know if there are any questions. Thank you, Anna ~Du6e, ~'. E. 6/18/2009 OPERABLE: Endicott 3-35/L (PTD #1870200) Stable IA Pressure ~ Page 3 of 3 Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Wednesday, May 27, 2009 1:55 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; END/BAD Area Manager; END, 0&M TL; END, Operations Lead Tech; END, Board Operator; END, Production Coordinator; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Soto, Jose A Cc: NSU, ADW Well Integrity Engineer; Quy, Tiffany Subject: UNDER EVALUATION: END3-35/L-36 (PTD #1870200) IA Repressurization AI„ Well END3-35/L-36 (PTD #1870200) has been found to have possible IA repressurization. An IA bleed performed by the Well Tender on 05/26/09 resulted with the IA pressure building and equalizing with the tubing. The well has been placed on a 28-day clock and will remain on injection for further diagnostics. The plan forward for the well is as follows: 1. WT: Apply 1500 psi to the IA and monitor pressure fall off 2. F: MITIA to 3000 psi 3. WIC: Eval for shut-in or AA A TIO plot, injection plot and wellbore schematic have been included for reference. Please note that the automation system at Endicott was recently switched so my injection plot is incorrect beginning 05/12/09 as the link in my database was not updated; the well was not shut-in at that time. Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 6/18/2009 II TREE: 4-1/16" / 5000 psi 1~V WELLHEAD: 11" / 5000 psi /FMC RT. ELEV = 55.4' BF. ELEV = 16.2' MAX. DEV. = 50:03 10900' MD 13- 3/ 8" , 68#/ f t , 2 503' L- 80, BTRS. CSG. E N D3-35 SAFET MIN ID = 3.725" @ 11789' 4-112" XN NIPPLE NT80S XO TO 10,021' -~ NT95HS OP OF 11,737 ~ 7" 9-5/8", 47#/ft, 11,989' --/ NT95HS, SSSV LANDING 1516' NIPPLE (3.813" MIN. ID) 4-1/2", 12.6#/ft, L-80, NSCT TUBING L IFr MANnRFI S ICAM CO-M M GM SPM 1 TVD VLV LATC PORT DATE i 3659 DMY RK 0 11/27/07 l 5439 DMY RK 0 11/27/07 3 6785 DMY RK 0 10/01/07 I 7782 DMY RK 0 10/01/07 I 8368 DMY RK 0 10/01/07 6 8956 DMY RK 0 08/15/87 0 9542 DMY RK 0 08!01/05 OTIS "X" NIPPLE 11607' (3.813" MIN. ID) 3AKER LATCH ASSY 11667' 9-5/8" PACKER ' (BAKER SB-3) 11668 (3-31/32" I.D.) 4-1/2", 12.6 #/ft, L-80 NSCT TBG 4-1/2"'X' NIPPLE 11728' Baker (3.813" I. D.) 4-1/2"'XN' NIPPLE 11789' Baker (3.725" I. D.) 4-1/2" WLEG, ID = 11800' 3.958" ELMD = 11,800' PERFORATION SUMMARY REF LOG: CNL-GR (04!02/87) ANGLE AT TOP PERF: ? @ 1211! Note: Refer to Production DB for historical SIZE SPF INTERVAL 3-318" 6 12040 - 12060 SOZ 1 i 3-318" 6 12066 - 12076 SOZ 1 i 3-3/8" 6 12086 - 12096 SOZ 1 ~ 3-3/8" 6 12114 - 12146 SOZ 1 i 3-3/8" 6 12199 - 12229 SOZ 3-318' 6 12199 - 12238 O 1 5" 5 12229 - 12240 SOZ 5" 5 12250 - 12322 SOZ " KEY: O =OPEN / C =CLOSED / SQZ=S PBTD POST 12395' RWO PBTD 12548' 7" - 29 #/ft, SM-110, 12,640' BTRS Tbg Vol = 177 Bbis. Tailpipe Vol = 2 Bbls. Liner to Perf Vol = 12 Bbls. - 12261' 3.7" PILOT HOLE THRU CEMENT (10/30/07), ID = 3.70" :ap 12,191' ELMD POST SOZ PBTD 12,250' (TOP OF CEMENT) HOLE IN LINER 12,318' COLLAR 20' W D DATE REV BY COMMENTS DATE REV BY COMMENTS ENDICOTT UNfr 03/29/07 ORIGINAL 11/12/07 GS/SV GLV C/O (10/1 & 11/8) WELL: 3-35 / L-36 11119/93 RWO? 12/14/07 DAV/PJC GLV C/O (11/27/07) PERMfr No: ?? 09/06/07 SRB/PJC MILL 3-1/2" PILOT HOLE API No: 50-029-21701-00 10/06/07 RDB/TL CMT SOZ SEC T N R E 11/01/07 DMS/TL MILUPERF BP Exploration (Alaska) ~--~ _~ LO r ~~ N O ti r M J M c7 ~~ ~~ U_ C • • $' ¢oo c f-?oooo • ~ ~ ~~., ~y p ~! yQ ~ ~ m G t1' G UJ O 1 V O 07 G V O 1 V O o~ 0 N M 0 m 0 f`J 1 M T O v M d W O O O O V M N *- Injection History for 187-020-0 50-029-21 701-00-00 *If no Avg value exists for the record in tblUicMonitor, it is DUCK IS UNIT SDI 3-35/L36 calculated he re (VoUInjDays). Pool Injection Inj Gas *InjDly Inj Wtr *InjDly Inj Pool Name Code RptDate (MCF) AvgGas (BBL) AvgWtr Days ENDICOTT OIL 220100 12/1/2007 0 0 89535 4712 19 ENDICOTT OIL 220100 1/1/2008 0 0 201365 6944 29 ENDICOTT OIL 220100 2/1/2008 0 0 185198 6386 29 ENDICOTT OIL 220100 3/1/2008 0 0 202786 6541 31 ENDICOTT OIL 220100 4/1/2008 0 0 143622 5129 28 ENDICOTT OIL 220100 5/1/2008 0 0 164014 5291 31 ENDICOTT OIL 220100 6/1/2008 0 0 85143 3153 27 ENDICOTT OIL 220100 7/1/2008 0 0 153727 4959 31 ENDICOTT OIL 220100 8/1/2008 0 0 156348 5043 31 ENDICOTT OIL 220100 9/1/2008 0 0 66993 3722 18 ENDICOTT OIL 220100 10/1/2008 0 0 149566 4986 30 ENDICOTT OIL 220100 11/1/2008 0 0 152379 5079 30 ENDICOTT OIL 220100 12/1/2008 0 0 137229 4574 30 ENDICOTT OIL 220100 1/1/2009 0 0 153401 4948 31 ENDICOTT OIL 220100 2/1/2009 0 0 138553 4948 28 ENDICOTT OIL 220100 3/1/2009 0 0 149427 4820 31 ENDICOTT OIL 220100 4/1/2009 0 0 153047 5102 30 ENDICOTT OIL 220100 5/1/2009 0 0 126390 4861 26 Injection To tal 0 2,608,723 Gas (MCF) Wtr (BBL) Wednesday, June 77, 2009 Page 1 of 1 RE: UNDER EVALUATION: END3-35/L-36 (PTD #1870200) IA Repressurization Page 1 of 2 • Regg, James B (DOA) From: Regg, James B (DOA) " 1~~`"1 • Sent: Tuesday, October 07, 2008 8:24 AM To: 'NSU, ADW Well Integrity Engineer' Subject: RE: UNDER EVALUATION: END3-35/L-36 (PTD #1870200) IA Repressurization Based on passing MITIA and lack of repressurization, it is acceptable to hold off on submitting paperwork for admin approval. Let's monitor as you suggest and see what happens. Thank you for the update and your call yesterday. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 " Anchorage, AK 99501 907-793-1236 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Monday, October 06, 2008 1:01 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: Townsend, S. Eliot; NSU, ADW Well Integrity Engineer; Engel, Harry R Subject: RE: UNDER EVALUATION: END3-35/L-36 (PTD #1870200) IA Repressurization Hi Jim, Well END3-35/L-36 (PTD #1870200] was originally reported to the AOGCC due to IA repressurization. S"snce the MITIA that passed on 09/22!08, the IA pressure has remained stable as represented in the attached TIO plot. Wauld you rather a request for AA be submitted naw or do you agree with monitoring the well through the Monthly Injection Report until the IA repressurization is exhibited again? From: NSU, ADW Well Integrity Engineer Sent: Thursday, September 11, 2008 8:18 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; Rossberg, R Steven; Engel, Harry R; Daniel, Ryan; NSU, ADW Well Operations Supervisor; Garing, John D; Lau, John, Jack; Soto, Jose A; END/BAD Area Manager; END, 0&M TL; END, Operations Lead Tech; END, Production Coordinator; END, Board Operator Cc: NSU, ADW Well Integrity Engineer; Townsend, S. Eliot Subject: UNDER EVALUATION: END3-35/L-36 (PTD #1870200) IA Repressurization 10/7/2008 RE: UNDER EVALUATION: END3-35/L-36 (PTD #1870200) IA Repressurization Page 2 of 2 • • Jim and Tom, Well END3-35/L-36 (PTD #1870200) has been found to have IA repressurization. The well is a produced water injector currently being used for the LoSal injection project. Two bleed events earlier this month triggered a review of the TIO plot. The plot indicates slow repressurization over some time. The last AOGCC witnessed MIT- IA passed on 03/13/08. The bleed events are: > 09/02/08: Oper bled IAP from 1150 psi to 400 psi (online) > 09/10/08: Oper bled IAP from 2250 psi to 1000 psi (shut in) The plan forward for the well is as follows: 1. OPER: Bleed IAP -DONE 2. F: MIT-IA to 1.2 x max injection pressure once back on injection 3. WIC: Evaluate for an AA Our intention is to have the well on injection for diagnostics. A TIO plot, injection plot and wellbore schematic have been included for reference. Please call with any questions or concerns. Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 10/7/2008 ~~ , N i ~ F- ~ O O d C_ T ~ __ /- ___ ___~_.__ ~. ~v x g 11 ^^ U, . ~xx N` ~ ,: ~ I O I s ~ w ,I t ~ ~ O O ~ { r C O O ~i O O T Lj~ L 09/18/08 ~~~l~~U~i~~~r~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well .Inh 8 I .... r\.. ..a:.... 3' .__ _. N0.4887 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 M-04 11978480 MEM GRADIOMANOMETER LOG _ •~ 08/25/08 1 1 14-32 12031498 LDL - 07/29/08 1 1 H-20 11962621 USIT "°~ '~- L~ 08/28/08 1 1 3-35/L-36 11999039 INJECTION PROFILE ~ 09/04/08 1 1 3-37/L-35 11970845 FLUID LEVEL DETERMINATIONU ~ S I !} _ 09/07/08 1 1 3-37/L-35 11968960 PRODUCTION PROFILE G ~- 08/30/08 1 1 NK-38A 12017515 SBHP SURVEY ~~ _ ~ ~ 09/02/08 1 1 L-215 12031512 INJECTION PROFILE 5 ~' r 09/03/08 1 1 B-05B 12096914 MCNL 08/17/08 1 1 L-205L3 40016965 OH MWD/LWD EDIT 06/21/08 2 1 ~~ ~.~~ . BP Exploration (Alaska) Inc. 4 ~ i~ p , Petrotechnical Data Center LR2-1 900 E. Benson Blvd. [ Anchorage, Alaska 99508 ~.~~~mt.~ y <~ E~n%j Date Delivered: ~~ 7 a, Si.i ',.ii' ... ~'i:- ~ . Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2 8 ATTN: Beth ~ Received by: i~.i • MEMORANDUM To: Jim Regg n P.I. Supervisor ~ ~~ ~ ~ ~~~~ FROM: Chuck Scheve Petroleum Inspector State of Alaska . Alaska Oil and Gas Conservation Commission DATE: Tuesday, Apri108, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 3-35/L36 DliCK IS Ui~1IT SDI 3-3~/L36 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~- ~ ~'- Comm Well Name: DUCK IS UNIT SDI 3-35/L36 API Well Number: 50-02 9-2 1 70 1-00-00 Inspector Name• Chuck Scheve Insp Num: mitCS0803 1 5 1 40 5 33 Permit Number: 187-020-0 Inspection Date: 3/13/2008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well '~~ ~-ss2s6 ~~,Type Inj. ~ ~' ~~ TVD ~'~ 96fi8 ~ IA ~I ~ zso i, zooo ~ -- zooo 269o j ~ Ia~ozoo eTest ~ SPT 'Test si P.T. I ITYP I I P 'i -; Zan ''pA ~ so ~ zso ~ ! -~- zso aso -- Interval ~TAL P/F P i Tubing~ ?ooo ~ zooo ~~~ zooo ~ zooo NOteS' Well was recently converted from producer to injector. Tuesday. April 08, 2008 Page 1 of t o~ ', F~ECEIVED STATE OF ALASKA ALAS A OIL AND GAS CONSERVATION COM~f©N ~,QN ~ `~ ~QQ$ REPORT OF SUNDRY WELL OF~ERATIO~N~O6~, ~;, p. ,,__ „_ „ 1. Operations Abandon Repair Welf Plug Perforations S j ulate~ Other c f Performed: g ~ g~ ~ W Alter Casin Pull Tubin Perforate New Pool ~ aiver~ Time Extension ~- Change Approved Program ~ Operat. Shutdown'. Perforate [] ,I Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratofryy 187-0200 3. Address: P.O. Box 196612 ~ SfratlgraphlC $erVlCe ~ ~ 6. API Number: Anchorage, AK 99519-6612 I 50-029-21701-00-00 7. KB Elevation (ft): 9. Well Name~and Number: ~ 56 KB ~ 3-35/L-36 8. Property Designation: ~ 10. Field/Pogf(s): _ ADLO-047503 ' Endicott Field/ Endicott Oil Pool 11. Present Well Condition Summary: i\ Total Depth measured 12640 ~ feet PIugS (measured) 12250' true vertical 10411. feet Junk (measured) 20" wd on bottom ~_ ___ Effective Depth measured 12548 feet ~~~~ J~N ~ ~ 2~~~ true vertical 10340.3 feet Casing Length Size MD TVD Burst Collapse Conductor 123' 30" Surface - 161' Surface - 161' Surface 2464' 13-318" 68# L-80 Surface - 2503' Surface - 2501' 5020 2260 Intermediate 11951' 9-5/8" 47# NT80S Surface - 11989' Surface - 9915' 6870 4760 Liner 903' 7" 29# SM-110 11737' - 12640' 9734' - 10410' 11200 8510 Perforation depth: Measured depth: O 12040' - 12060' O 12066' - 12076' O 12086' - 12096' O 12114' - 12146' S 12199' - 12240' S 12250' - 12332' O 12199' - 12238' S 12301' - 12322' True Vertical depth: 9953' - 9968' 9972' - 9980' 9987' - 9994' 10008' - 10032' 10073' - 10104' 10112' - 10167' 10073' - 10103' 10151' - 10167' Tubing: (size, grade, and measured depth) 4-112" 12.6# L-80 Surface - i 1800' 0 0 - Packers and SSSV (type and measured depth} 9-5/8" BAKER SB-3 11668' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: i3. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 4 5 4127 384 Subsequent to operation: 4058 900 2034 14. Attachments: 15. Well Class after oroposed 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 ~' GINJ ~' WINJ ~ WDSPL a 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: "~~-~~ ~~- ,~~~ ~ =~ ~~~8 307-342 Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature ~ ~« Phone 564-4944 Date 1/21/2008 Form 10-404 RevisEsd 04/2006 /~~0'~W Submit Uriginaf Unly • • 3-35/L-36 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY SUMMARY 12/9/2007`"**WELL S/I ON ARRIVAL***(post pulse test) :PULLED 4.5 X-LOCK WJ FLOW THROUGH CARRIER & HES `GAUGES C 11680' SLM, BRUSHING SSSV NIPPLE W/ 4.5 BLB *"*CONTINUED ON WSR 12/10107**" 12/10/2007,`*'`CONTINUED FROM WSR 12/9/07*** (post-pulse-test) RAN 4.5 BLB TO SSSV NIPPLE BRUSHED FROM 1425'SLM-1500'SLM. 'SET 4.5 MCX SER. # NM-16 WITH X EQ. SUB. AND 1"BEAN @ 1,484' SLM. RUN CHECK SET TO 1,484' SLM. (sheared) 'PERFORM SUCCESSFUL CLOSURE TEST. "*WELL LEFT S/I'`*" WELL TENDER NOTIFIED. '' *'`* NOTE**" (THIS WELL HAS BEEN CONVERTED TO AN INJECTOR) STATE OF ALASI~ ALASKA OIL AND GAS CONSERVAI®N COMMISSION Mechanical Integrity Tst Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.alv~; Jim_Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: BP Exploration (Alaska), Inc. FIELD /UNIT /PAD: Endicott /Duck Island /SDI DATE: 12!01!07 OPERATOR REP: Jack Lau AOGCC REP: Witness declined ~ i +~ ~~~ ~{ (Z, S Z ~ T ~v ~~~ Packer Depth Pretd Initial 15 Min. 30 Min. Well 3-35/L-36 Type Inj. W ND !9686 Tubing 1i! 1650 1650 1650 Interval O P.T.D. 1870200 Type test P Test psi :12500 Casing t8 2500 2500 2500 P/F P Notes: MIT-IA prior to conversion to injector. OA 0 0 0 0 C. Scheve declined witness. Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Wetl Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPEfNJ Codes D =Drilling Waste G=Gas I =Industrial Wastewater N =Not Injecting W = Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T=Test during Workover O =Other (describe in notes) MIT Report Form BFL 9!1!05 MIT END 335'~t-07.xls 11 /21 /07 Schlamt~errer Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Jnh it ~~~~ ~~~ ~ ~ 2001 1 .,,. ne~~.l..r~..., - NO. 4509 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken ~~ ,,. ~ 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Milne Pt., Endicott n.,.., Z-10 11676974 GLS = ~ :), __ ' r ~- 11/11/07 -- _ 06-16 11686797 PPROF & RS ('` ,_ °"~` ~? 11/15/07 1 MPL-33 11661179 MEM INJECTION PROFILE (7 ~ (', y r.`. ~ • r .~ -~y -. "` 11/13/07 1 MPF-25 11846827 USIT [ ~1;'''"°.-•.°°ry <f e'., 11/10107 1 GNI-04 11846828 USIT ,-=!;_~'"::-)-.._ ~ '`l_ 11111107 1 OWDW-SW 11626128 RST d ~ ° ~~ • «z Y ._ Z "r,,--, °~ --~. ~ _~._ 10/10/07 1 1 3-35/L-36 11630502 RST ~ ~1"'~~- t^~ ~}-i_~•y ~'= ° :o~- ••a- j~~, 09/09/07 1 1 15-26B 11661165 MCNL ~;N =~<.~°.~ r~',"~- ~it f,ec; ..~ .,~~, 08/24/07 1 1 05-36A 10928638 MCNL ~"p ,~ /t~~i. r , `tl't r~~=:"- ? t ~•,~ ~ 06/11/05 1 1 07-16A 11216211 MCNL -~ - f~~-; ~-i'> •;'~.( 08/27/06 1 1 2-286/0-19 11638650 RST %)~~~~' -C?i~Q~ t,. - ~a- ~ .~ 07105/07 1 1 07-02A 11649983 MCNL '/~~ (~~;~~*' At ~~--~,?.:•;~ 08/07/07 1 1 N-27 40015763 OH MWD/LWD EDIT ?7 ':"t.,. ~r^t ; ~-•?x_a 09/11/07 2 1 ~~r.v~ r. v..,.v •~~~vv~ .~a.v a... . u 1 VIVIYIIYV /11YV f~G 1 VRI\IIYV VI\C..Vyr-1-=CHVn 1 V: BP Exploration (Alaska) Inc. _ Petrotechnical Data Center LR2-1 - 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: • _. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-283~~', ATTN: Beth ,, i ~ ~ r~ II a ~ n Received bY•4 ;'.~, ,~ i'.. _,_ . • • • • ,,. ~._._ ~- ~,~ ~ ~ C~J ~- ALASSA OIL AI~TD GAS CO1~T5ERQATI019T COMDIIS51O1~T George Derrick Production Engineer BP Exploration Alaska Inc. SARAH PAL/N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907);279-.1.433 FAX (907) 276-7542 PO Box 196612 Anchorage, Alaska 99519-6612 ~"~ ~' ~ ~~~ `~ ~ ~~~~ Re: Endicott Field, Endicott Oil Pool, 3-35/L-36 Sundry Number: 307-342 Dear Mr. Derrick: 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. DATED this day of November, 2007 Encl. /~~-c~a Sincerely, r ~~10 ~ STATE OF ALASKA ~ ~ ~~~ ~ 7' ~~~~ y G ALASKA OIL AND GAS CONSERVATION COMMISSION ~ 4~ APPLICATION FOR SUNDRY APPROVA1~i~a~:~ ~ ~~ f ~.~_~ !".~f1"*rnissien 20 AAC 25.280 ~.n -el 1. Type of Request: Abandon Suspend Operational shutdown Perforate Waiver ^ Othe ~ Alter casing^ Repair well ^ Plug Perforations^ Stimulate ^ Time Extension ^ CONVERT TO INJ Change approved program ^ Pull Tubing ^ Perforate New Pool^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Developmenl0 Exploratory ^ 187-0200 - 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-21701-00-00 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: 3-35/L-36 ~- Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ff): 11. Field/Pools(s): , ADLO-047503 ~ 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): 12640 ~ 10411 12548 10340.3 12250' 20" WD ON BOTTOM Casing Length Size MD TVD Burst Collapse Conductor 123' 30" Surface 161' Surface 161' Surface 2464' 13-3/8" 68# L-80 Surface 2503' Surface 2501' 5020 2260 Intermediate 11951' 9-5/8" 47# NT80S Surface 11989' Surface 9915' 6870 4760 Liner 903' 7" 29# SM-110 11737' 12640' 9734' 10410' 11200 8510 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): O 12040' - 12060' 9953' - 9968' 4-1/2" 12.6# L-80 Surface - 11800' O 12066' - 12076' 9972' - 9980' - O 12086' - 12096' 9987' - 9994' - O 12114' - 12146' 10008' - 10032' - S 12199' - 12240' 10073' - 10104' - S 12250' - 12332' 10112' - 10167' - O 12199' - 12238' 10073' - 10103' Packers and SSSV Type: 9-5/8" BAKER SB-3 Packers and SSSV MD (ft): 11668' 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: 11/21/2007 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 George Derrick Printed Name Ge a Derrick Title Production Engineer Signature °°-®--- Phone 564-5891 Date 11/7/2007 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~~ '~~2... Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ~ Location Clearance ^ Other: Subsequent Form Required: yOy ~~~ ~~~;~( _? ~ 70~~ APPROVED BY ~~//r~~ Approved by: I E THE COMMISSION Date: (~ orm - evise u mi in up icate s /~P'~~r~~T AA~~f~ ~ A/1 /Af7T\ V`I~f`/~ t VV~7Y VVV ~VL7 ~ © ~ ~ s~ C011~ANY STANDARD ALASKA PRODUCTION CO. ~ v 0 d WELL 3-35/L-36 SDI ~ FIELD ENDICOTT 8 J < U H LL ~ g BOROUC3H NORTH SLOPE STATE ALASKA .. ~ ~ w ~ ~ °~ ~ ~ AT SURFACE Otti« a.rWO~•: w < °' °° f CET ~ 2608' FNL, b 680' FEL ~~ _ ~ z v ~ a AP1 SERIAL NO SECT. TWP. RANGE ~cT W ~ ~ 5002921701 8 11N 17E o ~ ., Permanent Datum MSL Elev. 0.0 F Elev.iC~. 66.0 F LoQ Irieasured From RKB b8.0 F above Perm. Datum D.F. 66.0 F DrNNnO IiAeasured From RKB G.L. 14.5 F Date 02-APR-$7 Run NO. ONE depth DrNler 12bb8.0 F Depth Lo00er (Sohl.) 12649.0 F Btm. Loo Interval 12b38.0 F Top Loo interval 11800.0 F Caalnp-DrNier e o 0 0 Casing-LOgper E ~, Bit Size Type Fluid In Hole BRINE Dens. Viso. 9.80 LB/G pH Fld. Loss Source of 8ampe CIRCULATED Rm • Mean Temp. O O Rmf ~ Meaa. Temp. O O Rmo O Irteaa. Temp. O O 8curoe: Rmt Rmo LEAS. MEAS. Rm ~ BHT O O r+ Ciroulatlon Ended L oOpsr on Bottom f~tax. Rec. Temp. Equip. Looation 8381 PRUDHOE BAY Recorded By G. BARBER witnessed By R. SCHOCK • - • ~~`~-oaf I~C:iANIGAL INTEGRITY REPORT U D v =_ .~ : 3 ~ ~ -~~ OPER ~ FIELD .-~~ h ~ y ' ~~`C] ~ CSJ~ :.G r S~Sr Sy . ~::.I.L NUMBER ~-3~ ~ ~-= ~ ~o n * LL DAT ~ TD . ~a (O~~?~.. I0 ~1~~ TVD ; ?BTD . 1~S~t`6 ~ 1034() TVD tl Casi^g: Cj,~l~ Shoe: 115 MD ~~lS TVD; UV: ?~? -~~ _,:,er . ~''' Shoe : 1~6'~ ~ 1 10 ~`~ ; ~Gr : 1t'13`~ ~-~ ~'13y ='';~ =ubi-~~ ~'`~,~, Packer (~6 ~ :~ T'JD; Set at 1 «~~ =ole S`ie ~a~~~l and ~~ ~-- _~ Perf:~ ia0"l~ to laa?Z~~ ~~in~~~~s) ~~1~ ~ ICS \03 ~!v c7 :~= ii=.~?~ _ C.I. INTEGRITY - PART # ~nnu.~us Press Test: ~? ?5 nin ~0 min Coc~ents '~'CHp~IIC~i. INTEGRI'?'~ - PART # 2 ~ S~ ~~~5 ~. Ur u f ,.~/ f~ Q Evaluation CONC-LJS ~ OIdS ?art Il. ~ ~ . _ nr TL: ~ t 1~ ~ ~ S 'C t CC). ' V ~~ ~, ~~~ Cement Volumes :- Amt. miner >`t~; Csg DV~ Ca 3O2o XS 1 Cwt soi to cover oers 3 a ~ih\s s~cler~~ fl 5 } 500 ::eoretical TOC ~~.~~-~ vvc,,S cJ~C'~~\~CJ ~Ue ~i ~t a t~'1 ~g Cement Bond Log (Yes or No)~G~_; In AOGCC File L~5 CBL :valuation, gone aoove perfs ho~Unc~ ~S Qv~~r~~- ~ v~-~~Cc c~~nU,~\CC s~tcC_~tio+-~.~s ~~'Oyfc J C~,~ Production I.og: Tyve 10-403 AOR for END3-35/L~ • Maunder, Thomas E (bOA) From: Derrick, George (Mackie} M [derrgm@BP.com] Sent: Wednesday, November 14, 2007 1:58 PM To: Maunder, Thomas E (DOA} Cc: Seccombe, Jim C; Prebie, Gary B (SAIC}; Garing, John D; Denis, John R (ANC) Subject: RE: 10-403 AOR for END3-35/L-36 Attachments: radius.jpg Tom, Here are the distances for each well from END3-35lL-;36: END3-37/L-35: 1049' 155 - O S 1 END3-33/K-37: 1596' tgsco- l°6C7 END4-32/K-38: 1701' t~5-Qloci DI-02: 785' 1 ^e~- p6 ~ I have attached a picture as well from our Geologist. Mackie Page 1 of 2 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, November 14, 2007 1:32 PM To: Derrick, George (Mackie) M Cc: Seccombe, Jim C; Preble, Gary B (SAIC); Garing, John D; Denis, Jahn R (ANC) Subject: RE: 10-403 AOR for END3-35JL-36 Mackie, The information looks good. Can you provide the actual well separation distances from 3-35/L-36 at the top of the Kekiktuk? Thanks in advance. Tom Maunder, PE AOGCC From: Derrick, George (Mackie) M [mailto:derrgm@BP.com] Sent: Wednesday, November 14, 2007 11:40 AM To: Maunder, Thomas E (DOA) Cc: Seccombe, Jim C; Preble, Gary B (SAIC); Garing, John D; Denis, John R (ANC) Subject: 10-403 AOR for END3-35/L-36 Tom, Thank you for your help with this sundry. Here is a copy of the research done on the AOR. If you need anything else please contact me. Mackie ackie errick 11/14/2007 4-20/M-35 o 0 nl 595000 { • i ~ 3-33/K-37 ' _ 3-37/L-35 ~. e9; aooa --_ ~ 1596' II ~ 1049' - --1 4-32/K-38 3- 5/L-36 ',701`!, 3- ---1 ~ ~ 785' I DI-02 - - _ _• \ ' 1324' ~ Top Kekiktuk Pick Radius' I / 4~8/N-37 ~r EnAkot[TOam - _. - 11118/08 ConHMnWI 1000 0 1000 2000 ° 3000 ft N rr-ra_ --- -- - 1:6000 i~l~~° ~~ ~ NOV 0 5 2007 STATE OF ALASKA ALA A OIL AND GAS CONSERVATION COM~SION Cons. CammisSltlC~i REPORT OF SUNDRY WELL OPERATION~leska Otl & Gas Anchorage 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Other Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension Change Approved Program ~ Operat. Shutdown Perforate Q Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~ Exploratory "' 187-0200 ~ 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: Anchorage, AK 99519-6612 50-029-21701-00-00 ' 7. KB Elevation (ft): 9. Well Name and Number: 56 KB - 3-35/L-36 8. Property Designation: 10. Field/Pool(s): , ADLO-047503 ' _ ._ENDICOTT Field/ ENDICOTT OIL Pool 11. Present Well Condition Summary: Total Depth measured 12640 , feet Plugs (measured) 12250' true vertical 10411 feet Junk (measured) WD PKR ON BOTTOM Effective De th measured 12548 feet ~ , ~ ,~ ~ ~~~~ true vertical 10340.3 feet Casing Length Size MD TVD Burst Collapse Conductor 123' 30" Surface - 161' Surface - 161' Surface 2464' 13-3J8" 68# I-80 Surface - 2503' Surface - 2501' 5020 2260 Intermediate 11951' 9-5/8" 47# NT80S Surface - 11989' Surface - 9915' °~ ~~~ ~"`" 6870 4760 Liner 903' 7" 29# SM-1 i 0 11737' - 12640' 9734' - 10410' 11200 8510 Perforation depth: Measured depth: O 12040' - 12060' O 12066' - 12076' O 12086' - 12096' O 12114' - 12146' S 12199' - 12240' S 12250' - 12332' O 12199' - 12238' True Vertical depth: 9953' - 9968' 9972' - 9980' 9987' - 9994' 10008' - 10032' 10073' - 10104' 10112' - 10167' 10073' - 10103' Tubing: (size, grade, and measured depth) 4-1J2" 12.6# L-80 Surface - 11800' 0 0 - Packers and SSSV (type and measured depth) 9-5{8" BAKER SB-3 11668' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: !~ 3~ ~ti ' ~ aT o~ c OC~ ~~ o~S Intervals treated (measured): ," ~~ ~~IYU ~D01 ~ ~ ~ .. Ct~3o' o'l j •~ Treatment descriptions including volumes used and final pressure: /d" {~ (,SS 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 29 32 5580 1290 Subsequent to operation: SHUT-IN 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 ~' 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: NJA Contact Gary Preble Printed Name Gary Preb Title Data Management Engineer Signature - Phone 564-4944 Date 11/2/2007 roan i~-4u4 nevJlSE3O U4/LVVO v U R 1 G 1 N A L ~ ", ~ Juu~~~~. v~~y~~~¢~ v~~~Y • • 2-35/L-36 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ~ ACTIVITYDATE ~ SUMMARY ~, 10/18/2007~""`WELL S/I ON ARRIVAL*'* ost s z ` DRIFT TBG W/ 2 7/8" DMY PERF GUN & TEL, LOC TT @ 11784' SLM, ;! (+16' CORRECTION = 11,800' ELM), TD @ 12209' ELM, 'DRIFT W/ 2 1/8" DMY PERF GUN TO 12220' ELM, `-DRIFT W 2" DMY PERF GUN TO 12220' ELM, 1/4 CUP OF CEMENT RETRIEVED IN S-BAILER. ""`WELL LEFT S/I, NOTIFIED DSO*"" _ _ _ 10/27/2007': CTU#, W/1.75" !Coil, Mill Cement Sheath and add perforations, Standby on 'location for winds to diminish. Begin rig up..... Job continued on 10/28/07 ____ ...... ....... ... H,._. _ ... ........ .... _. ... .... _.... 10/28/2007 CTU#, W/1.75" (Coil, Mill Cement Sheath and add perforations, Continued from 10!27/07. Finish Rig up. Perform weekly BOP test. MU &RIH Weatherford tools '°.with undereamer with 6.0" blades. Tag top of cement at 12200' ctm. Begin `undereaming using 1 % XS KCI. Encounter ar no es at iT~~ir''c~m. Milled to 12250',_ PUH to locate bottom of TT, could not locate TT. PU to 11725', TT should :have been 11800'. POOH chasing Biozan pill at 80%.... Job continued on :10/29/07.... 10/29/2007:` CTU # 8 w/1.75" !Coil, Mill Cement Sheath and add perforations. Continued from :10/28/07. At surface rig down Milling equipment. Rig up and !Coil, had to rehead ":twice to get good signal. MU BHA #2, iCoil CCL and 3.36" DJN for drift and depth '::correlation. RIH had excellent resolution on CCL. Set down wp",aht at 12223'. . '':Attempt to log up unsuccessfully. POOH. No external marks apparent on tools ;string. Inspection of iCoil connector revealed broken fiber optic strands. MU BHA #3, Weatherford motor and Reeve underreamer with 6.00" blades. RIH underream ``from 11885' to 12250', making multiple passes in area from 12220' to 12230'. Pump `20 bbl Biozan sweep and chase out at 80% .... Job continued on 10/30/07 10/30/2007`. CTU # 8 W/1.75" CT, Mill Cement Sheath and add Perforations. Continued from ;10/29/07. POOH from undereaming. MU &RIH 3.70" junk mill to drift tubing... ac ':'down at 12,230'. Mill from 12,230' to 12,250' with 1 % XS KCI with 4 stalls. At ':12,250' ctm, pump 10 bbl Biozan sweep and chase into tubing. Dry tag bottom at :12,260' ctm. Chase Biozan out of hole at 80% pump rate. At surface, mill had `.:slight wear on outer edges and gauged at 3.70". MU iCoil connector. "'`'`* Job in progress *** • • 1013112007;"*`CTU # 8 W/ 1.75" ICoil, Add perfs. Continued from 10/30/07*'* Running in Hole `with Perforating BHA. with 3 318" guns 3406 Power Jet charges 6 spf 60 degree `°`~ phasing to a depth of 12200', made preliminary correction based on logging down. :Begin logging up and lost communication with tools. Did not get enough data on log' "`" up to confirm the correction. POOH. RIH w. SLB memory tools in carrier w. 3.5" ' ' JSN. Tag TD three times and start logging up @ 45 fpm from 12251' (getting depth'' 'on up swing) to 11500' RIH w/ 3.318" HSD 3406 PJ puns 6 spf Shoot puns 12218` ' ' ;top shot 12238` bottom shot. ""*Continue job on 11/1/200T`** ~~......_..1-1/12007; *'`*CTU # 8 cont` WRS from 10!31/07 Perforating"''* Confirmed auns fired. M/U ':second set of 3 3/8" HSD 3406 PJ 6 spf. Fire top shot at 12199' bottom shot 12218' ROOH and Confirmed all shots fired. Perform infectivity test per town APE. Established injection rate of 720 bpd @ 2260 psi. Freeze protected well and left S/i `' CT Reel blown down with N2 "'*Job Complete""" FLUIDS PUMPED BBLS 52 50/50 METH 346 N2 348 TOTAL STATE OF ALASKA ~ I v C ~ /O~ ~? ALASKA OIL AND GAS CONSERVATION C~ O~~nn REPORT OF SUNDRY WELL OPT A Q~C~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations S 8 ~ i E1S. Oi)1ti11SS)tlf~r ~ cement sgze Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ W~'8ge Time Extension Change Approved Program ~ Operat. Shutdown Perforate ~ Re-enter Suspended Wel{ 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ' ~ Exploratory 187-020o J 3. Address: P.O. Box 196612 StratlgraphlC S@rV1Ce 6. API Number: Anchorage, AK 99519-6612 50-029-21701-00-00 ' 7. KB Elevation (ft): 9. Well Name and Number: 56 KB 3-35/L-36 ~ 8. Property Designation: 10. FieldiPool(s): ADLO-047503 ENDICOTT Field/ ENDICOTT OIL Pool 11. Present Well Condition Summary: Total Depth measured 12640 feet Plugs (measured) 12250' true vertical 10411 ~ feet Junk (me asured) 20" WD PACKER ON BOTTOM nn Effective Depth measured 12548 feet ¢,~~ ~ ~~~ ~ ~j ZUU7 ~~~~" "" "~"~ true vertical 10340.3 feet Casing Length Size MD TVD Burst Collapse Conductor 123' 30" Surface - 161' Surface - 161' Surface 2464' 13-3/8" 68# L-80 Surface - 2503' Surface - 2501' 5020 2260 Intermediate 11951' 9-5/8" 47# NT80S Surface - 11989' Surface-,-9915'°°~'""""""" 6870 4760 Liner 903' 7" 29# SM-110 11737' - 12640' 9734' - 10410' 11200 8510 Perforation depth: Measured depth: O 12040' - 12060' O 12066' - 12076' O 12086' - 12096' O 12114' - 12146' S 12199' - 12240' S 12250' - 12322' True Vertical depth: 9953' - 9968' 9972' - 9980' 9987' - 9994' 10008' - 10032' 10073' - 10104' S 10112' - 10167' Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 Surface - 11800' 0 0 - Packers and SSSV (type and measured depth) 9-5/8" BAKER SB-3 11668' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~~` ~~' ~ ~ ~ ZdQ~ Treatment descriptions 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: 29 32 5580 1290 Subsequent to operation: SHUT-IN 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 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: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 10/11/2007 unn IU-4u411eVI5~U/C/4/GUVO~ K ~ ~' ~`~r~~ auurnuvnymaivnry • • 3-35lL-36 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE ( SUMMARY' 10/3/2007 CTU #8, CMT SQZ; MIRU. MU 2.0" OD BDN. STDBY for SLB pump truck and crew. ... Cont' on WSR 10/04/2007 ... 10/4/2007': Heat 2 upright tanks w/1 %KCL to 180*F for coil unit. Job Continued on 10-5-07 'WSR. 10/4/2007! CTU #8, CMT SQZ; Cont' from WSR 10!03/07. .., STDBY for SLB pump truck and crew. Cont' on WSR 10/05!07. i Oi5i2007' CTU #8, CMT SQZ; Job Cont' from WSR 10/04/07. Standby for pilot test of 'cement.... _ ~_e . ..~..~ ~ _ _.__.. ~ _ _ ~.v. 10/5/2007 CTU #8, Cement Squeeze; ... Cont' from WSR 10/04/07 ... MU 2.0" OD BDN. 'Kill well with 300 bbls of 1 %KCL. RIH. Tag btm at 12275' ctmd. Correct to ELMD o 81'Sr Jet 47.6 bbls of 12% HCL across perfs. Initial injectivity of 1500 ~ a~ ~~(, ;psi bpm. Final injectivity of 1000 psi at 1.0 bpm. Observed an excellent !..break down with 10 bbls of acid out the nozzle. Batch mix 40 bbls of 15.8 ppg ~~-~ ' Class G LARC cement. Lay in cement from 12308' ctmd at 1/1. Bump pressure up to 2500psi in 500psi increments every 15 minutes. Hold 2500psi squeeze :pressure for 30min. Drop WHP to 500psi while pumping .68" ball with biozan. 'Contaminate to 12250' ctmd. Reciprocate between 11800' and 12250' jetting 'biozan followed by 1 % XS KCL. POOH C~ 80% jetting all jewelry. Cont' on WSR ;10/06/07. 10/6/2007' CTU #8; CMT SQZ, Job Cont' from WSR 10/05!07 POOH holding 500psi and ` ':jetting all jewelry with 1% XS KCL. Lay in 50/50 methanol freeze protect from 2500' . OOH. Wash tree valves and BOP's. Trap 500psi on well. Notify Drill I Site Operator of well status. CMT SOZ depth 12250' - 12300'; 12301' - 12322' RDMO....WELL TO REMAIN SHUT IN FOR 10 DAYS* JOB COMPLETE*"' FLUIDS PUMPED BBLS 720 1 %KCL 90 Xs 1 %KCL 25 60/40 Meth 90 1.5 ppb Biozan 40 15.8 ppg Class G LARC cement 45 12% HCL 140 Fresh Water 1150 TOTAL 09/28/07 ti~i~f~~U~i~~~r~ NO. 4440 Alaska Data & Consulting Services Company: State of Alaska 25z5 Gambell Street, Suite 400 A' ~ / {~ (~~y Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 ~~~ IVD y Z: ~ ZUU~ Attn: Christine Mahnken ATTN: seth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay WRIT _Inh it 1 nn rlncn.lnr:nn n~~., n~ r..~... rn 15-39A 11661174 MEMORY PROD PROFILE 09/23/07 1 W-42 11745235 MEM SBHPS/TEMP 09114!07 1 Z-07A N/A SBHP SURVEY 09/14/07 1 A-04 11594519 SBHP SURVEY a - 08/26/07 1 Y-24 11630499 LDL 09I04I07 1 L5-28A 11855810 PRODUCTION PROFILE - (~ 08/31/07 1 X-33 11849931 SBHP SURVEY = - t~L 08/31/07 1 E-14A 11686784 LDL ~ ~ 09/23/07 1 01-15A 11855509 DDL - ai (~ 09I22I07 1 D-21 11626119 PRODUCTION PROFILE '(`fa ->~ 09/11/07 1 K-07D 11745234 MEM PROD PROFILE C _ 09/06/07 1 11-32 11630498 PRODUCTION PROFILE j L _ ( 09/03/07 1 L-01 11745233 MEM LDL a U (- ~ 09104!07 1 07-30A 11661168 MEM STP & CORRELATION - 08/28/07 1 Z-28 11630500 INJECTION PROFILE ZC 09/05/07 1 Z-16 NIA SBHPS/JEWELRY / 09/13/07 1 14-26 11676959 LDL ~/j 09109!07 1 04-02A 11630504 LDL !( 09/11/07 1 14-37 11695075 LDL - ~ 09/13/07 1 3-35/L-36 11630502 PRODUCTION PROFILE 09/09/07 ' 1 r~~~aac n~.r~rvvvv~tuut KttitlY I e3Y 51(7rvlNl9 ANU„KtJ Uttry11VF,s VNt I:UYY EAGN 1 V: BP Exploration (Alaska) Ina _..._ Petrotechnical Data Center LR2-1 "' 900 E. Benson Blvd. Anchorage, Alaska 99508 ; •,~ ~m ~1:~41 ~ ~n =4 , Date Delivered: s ~a,q~l Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 i Anchorage, AK 99503-28 ATTN: Beth Received by: • MICROFILMED 9/28/00 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 24 October 1995 Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL ~y-( ~q 2-16/M-16 ¥. # DESCRIPTION 1 PLS FINAL BL+RF 1 PLS FINAL BL+RF 1 PDK FINAL BL+RF 1 PLS FINAL BL+RF ECC No. Run # 1 5921.10 Run # ! 6006.06 Run # 1 6148.04 Run # 1 6351.09 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Received by' ~~///~/ ' STATE OF ALASKA ALA~,,~ OIL AND GAS CONSERVATION COMMISS. IL~ 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 I 5. Type of Well: BP Exploration (Alaska) Inc. I Development ., Exploratory 3. Address Stratigraphic P. O. Box 196612, Anchorage, Alaska 99519-661.2 Service 4. Location of well at surface 2508' SNL, 680' WEL, Sec. 8, T11N, R17E At top of productive interval 4529' SNL, 1835' WEL, Sec. 4, T11N, R17E FED At effective depth 4418' SNL, 1650' WEL, Sec. 4, T11N, .A.~ohora~ U ~'~ ~ ~ At total depth 4386' SNL, 1620' SEL, Sec. 4, T11N, R 17E 6. Datum elevation (DF or KB) KBE = 55.4 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 3-35/L-36 SDI 9. Permit number/approval number 87-20/Not Required 10. APl number 50- 029-21701 11. Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 12640 feet 10410 BKB feet 12548 feet 10239 BKB feet Plugs (measured) Junk (measured) Top of cement after workover of 11/20/93 at 12250' MD 20' WD packer on bottom Length Size Cemented Measured depth True vertical depth BKB BKB 123' 30" Driven 161' 161' 2464' 13 3/8" 3720 c.f. Permafrost Cmt 2503' 2501' 11951' 9 5/8" 575 c.f. Class G 11989' 9915' measured 903' 7" 315c. f. Class G 11737'- 12640' 9734'- 10410' 12040'. 12060' (Open), 12066' - 12078' (Open), 12086' - 12096' (Open), 12114' - 12146' (Open), 12199' - 12229' (Open), 12229' . 12240 (Squeezed), and 12250' - 12322' (Squeezed) true vertical (Subsea) 9897' - 9912; 9916' - 9925; 9931' - 9939, 9952'. 9976', 10017' - 10040' (All Open) 10040' - 10048' and 10056' - 10111' (Ail squeezed) Tubing (size, grade, and measured depth) 4 1/2" 12.6#/Ft. L80 TDS Tubing to 11801' MD Packers and SSSV (type and measured depth) Baker 9 5/8" 9CR SB-3 Packer at 11668'; 4 1/2" Otis 'HXO' BVLN at 1516' 13. Stimulation orcement squeeze summary Water shut off cement squeeze 10/31/95, Reperforate 12/3/95 and reperforate 1/11/96. Intervals treated (measured) 12040'- 12060', 12066'- 12076', 12086'- 12096', 12114'- 12146', 12129'- 12229' Treatment description including volumes used and final pressure 318 Bbls seawater, 56 bbls fresh water, 34 bbls cement and 30 bbls methanol. FWSHP = 1700 psig 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 100 3244 0 205 398 0 Tubing Pressure 391 365 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. Signed ~"'~'~'~7_/7~:~/ ~. /q~~ TitleSr. TechnicalAssistantll Form 10-40~ Rev- 06/15/88 Endicott Production Engineering Department Re-Perforation DATE. 12/3195 WELL N-°: 3-35 / L-36 BP EXPLORATION REP: R. CLUMP SERVICE COMPANY: ATLAS (BARBA) [I DATE/TIME OPERATIONS SUMMARY 0800 MIRU ATLAS. FWHT= 125 o F, FWHP=350 PSI, IAP=1250 PSI. 0900 SI well and RIH w/Gun #1 (20' x 3-3/8" Alpha Jet- 6 spf, 60 o phasing, random orientation). 1000 POP well @ FOC w/GL. 1020 Well is flowing liq. Tie into CBT Dated 4/2/87 (-14'). 1040 Drop down to flag line @ 12169' md bkb. Log into position @ CCL depth of 12038' md bkb. Shoot Gun #1 from 12040- 12060' md bkb. Log off. 1104 Shut in well. POOH. 1148 OOH. All shots fired. 121 5 RIH w/Gun #2 (10'). 1300 Stop above all perfs. Pop well @ FOG w/GL. 1312 RIH to flag @ 12169' md bkb. Log into position @ CCL depth of 12084' md bkb. 1319 Shoot Gun #2 from 12086-12096' md bkb. Log off. Shut in well. POOH. 1409 OOH. All shots fired. ,,, 1428 RIH w/Gun #3 (12'). 151 0 Stop above all perfs. POP well @ FOC w/GL. 1525 RIH to flag @ 12169' md bkb. Hung up at 12076' md bkb on first attempt to log into position. LOg into position @ CCL depth of 12056' md bkb. 1535 Shoot Gun #3 from 12066-12078' md bkb. Log off. Shut in well. POOH. 1620 OOH. All shots fired. RDMO Atlas. 1700 POP well FOC w/GL. PERFORATION SUMMARY: GUN INTERVAL FEET SUBZONE I 12040 - 12060 20 3B 2 12086 - 12096 10 3B 3 12066 - 12078 12 3B Intervals shot using 3-3/8" Alpha Jet at 6 spf, 60 degree phasing, random orientation. Endicott Production Engineering Department DATE: 1/11/96 Re-Perforation WELL N°: 3-35/L-36 BP EXPLORATION REP: POWERS SERVICE CO: ATLAS (BARKER) I DATE/TIME OPERATIONS SUMMARY I 1330 MIRU. FWHP = 400 PSI; lAP = 1300 PSI; OAP = 0 PSI 1516 INSTALL SSV FUSIBLE CAP. SI WELL. PRESSURE TEST LUBRICATOR TO WELLHEAD PRESSURE. RIH WITH GUN #1 (24 FEET). 1600 OPEN WING VALVE AND SET CHOKE TO 50 BEANS. SIWHP=650 PSIG 1615 TIE IN TO CBL DATED 4/2/87. TAKE OUT 20'. 1640 HANG GUN #1 AT 12120'. SHOOT GUN #1 FROM 12122' TO 12146'. LOG OFF. 1650 GAINED 100 PSIG AND LOST 100 LBS. SI WELL AND POOH. 1800 RIH WITH GUN #2 (8'). SIP=535. 1845 OUT OF TUBING. POP WELL @ 50 BEANS. SIP=600 PSIG. 1900 TIE-IN AT FLAG. TAKE OUT 4'. 1905 HANG CCL AT 12110'. SHOOT GUN #2 FROM 12114'-12122'. NO INDICATIONS. 1915 LOG OFF. SI WELL. DROP BACK TO RECORD PBTD =12,191'.. 1925 POOH 2015 CONFIRM ALL SHOTS FIRED. 203O RD. COMMENTS: · THE HEADER IN THE PERFORATION LOG IS INCORRECT..THE TIE-IN LOG WAS DATED APRIL 2, 1987 AND NOT JAN. 2. · SCALE WAS EVIDENT AFTER PERFORATING THE 24' INTERVAL AS THE GR WAS VERY HOT LOGGING OFF. WHP INCREASED FROM 250 PSIG TO 370 PSIG WHILE FLOWING AT 50 BEANS. · PBTD = 12,191' ELMD PERFORATION SUMMARY: GUN CBL DEPTH FEET SUBZONE I 12122' - 12146' 24' 3A3 2 12114' - 12122' 8' 3A3 ALL INTERVALS WERE SHOT USING 3-3/8" ALPHAJET GUNS AT 6SPF, 60° PHASING AND RANDOM ORIENTATION. LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 16 January 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL 3-35/s-36 (sDi) DESCRIPTION PFC/PERF FINAL BL+RF PFC/PERF FINAL BL+RF PLS FINAL BL+RF ECC No. Run # 1 5723.08 Run # 1 5921.12 Run # 1 6001.17 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 :F /M'~chorage, J~K 99518 AX to (907) 563-7803 Received by: Date: LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 16 January 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL 3-35/ .-36 (sDi) 2-5o/u-o8 # DESCRIPTION 1 PFC/PERF FINAL BL+RF 1 PFC/PERF FINAL BL+RF 1PLS FINAL BL+RF ECC No. Run # 1 5723.08 Run # 1 5921.12 Run # 1 6001.17 Received by: Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 2/FAnchorage, AK 99518 AX to (907) 563-7803 Date: LARRY GRANT . Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 7 December 1995 Transmittal of Data Sent 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 PFC/PERF FINAL BL+RF 1 SBT FINAL BL+RF ECC No. Run $ 1 5869.07 Run # 1 5921.11 Run # 1 6530.01 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 _ . Re~ei.ved~._.~~/j . . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISS~,JN 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, Anchora'ge, Alaska 99519-6612 Service __ 4. Location of well at surface 8. 2508' SNL, 680' WEL, Sec. 8, T11N, R17E At top of productive interval 4529' SNL, 1835' WEL, Sec. 4, T11N, R17E At effective depth 4418' SNL, 1650' WEL, Sec. 4, T11N, R17E At total depth 4386'SNL, 1620'SEL, Sec. 4, T11N, R17E o 1995 St-? 20 6as Cons. 6ommissioQ Anchorage Datum elevation (DF or KB) KBE = 55.4 feet Unit or Property name Duck Island Unit/Endicott Well number 3-35/L-36 SDI 9. Permit number/approval number 87-20/Not Required 10. APl number 50- 029-21701 11. Field/Pool Endic~t'~il,.P~ool 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 12640 feet Plugs (measured) 10410 BKB feet 12548 feet Junk (measured) 10239 BKB feet Size Cemented Top of, cement after wor~d~r'¢fj,'1132¢/93 at 12250 MD 7'/ 20' WD packer on bottom Measured depth True vertical depth BKB BKB 123' 30" Driven 161' 161' 2464' 13 3/8" 3720 c.f. Permafrost Cmt 2503' 2501' 11951' 9 5/8" 575 c.f. Class G 11989' 9915' measured 903' 7" 315c. f. Class G 11737'- 12640' 9734'- 10410' 12040'- 12060' (Open), 12066'- 12076'(Open), 12086'- 12096' (Open), 12114'- 12146' (Open), 12199'- 12229' (Open), 12229' - 12240 (Squeezed, and 12250' - 12322' (Squeezed) true vertical (Subsea) 9897' - 9912', 9916' - 9924', 9931' - 9939, 9952' - 9976', 10017' - 10040' (All Open) 10040' - 10048' and 10056' - 10111' (Ail squeezed) Tubing (size, grade, and measured depth) 4 1/2" 12.6#/Ft. L80 TDS Tubing to 11801' MD Packers and SSSV (type and measured depth) Baker 9 5/8" 9CR SD-3 Packer at 11668'; 4 1/2" Otis 'HXO' BVLN at 1516' 13. Stimulation or cement squeeze summary Scale Inhibitor Treatment (8/5/95) Intervals treated (measured) 12040'- 12060', 12066'- 12076', 12086'- 12096', 12114'- 12146', 12129'- 12229' Treatment description including volumes used and final pressure 46 Bbls. seawater with mutual solvent, 62.5 Bbls seawater with BPCl inhibitor, 211 Bbls seawater/0.2% NE-118 Mix as overflush and 189 Bbls seawater tubing displacement. FSWHP = 400 psig 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 470 55 2467 0 453 91 2567 0 Tubing Pressure 4O9 414 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 (~._.~/~~ c.~. ~~---~'"~ Title Sr. Technical Assistant II Form 10-/i~4 Rev 06/15/88 Date SUBMIT IN DUPLI(~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__ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2508'SNL, 680' WEL, Sec. 8, T11N, R17E At top of productive interval 4529'SNL, 1835' WEL, Sec. 4, T11N, R17E At effective depth 4418' SNL, 1650' WEL, Sec. 4, T11N, R 17E At total depth 4386' SNL, 1620' SEL, Sec. 4, T11N, R17E 5. Type of Well: Development .. Exploratory Stratigraphic Service __ 6. Datum elevation (DF or KB) KBE = 55.4 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 3-35/L-36 SDI 9. Permit number/approval number 87-20/Not Required 10. APl number 50- 029-21701 11. Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 12640 feet 10410 BKB feet 12548 feet 10239 BKB feet Plugs (measured) Junk (measured) Top of cement after workover of 11/20/93 at 12250'MD 20' WD packer on bottom Length Size Cemented Measured depth True vertical depth BKB BKB 123' 30" Driven 161' 161' 2464' 13 3/8" 3720 c.f. Permafrost Cmt 2503' 2501' 11951' 9 5/8" 575 c.f. Class G 11989' 9915' 903' 7" 315c. f. Class G 11737'- 12640' 9734'- 10410' measured 12040'- 12060' (Open), 12066'- 12076'(Open), 12086'- 12096' (Open), 12114'- 12146' (Open), 12198'- 12240' (Squeezed), 12250' - 12300'(Squeezed), 12301' . 12322' (Squeezed) 12199' - 12229' (Open) true vertical (Subsea) 10016'- 10049' (Squeezed), 10056'- 10095' (Squeezed) 10095' - 10111' (Squeezed), 9897' - 9912; 9916' - 9924', 9931' - 9939, 9952' - 9977' (All Open) 10017' - 10040' (Open) Tubing (size, grade, and measured depth) 4 1/2" 12.6#/Ft. L80 TDS Tubing to 11801' MD Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary Baker 9 5/8" 9CR SB-3 Packer at 11668'; 4 1/2" Otis 'HXO' BVLN at 1516' 'RECEIVED Intervals treated (measured) Treatment description including volumes used and final pressure JUL Oil & Gas Cons. Commissto¢~ ~llL;IIO.'~ 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 412 71 2013 0 885 326 2065 0 Tubing Pressure 447 439 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. Signed ~~, ~ TitleSr. TechnicalAssistantll Form 1~ Rev 06/15/88 SUBMIT IN dUPliCATE L. ~icott Production Engineering Department DATE: 6/17/95 WELL N°: 3-35 / L-36 BP EXPLORATION REP: REPERF R. CLUMP SERVICE CO: ATLAS (BARBA) DATE/TIME OPERATIONS SUMMARY 8:00 MIRU. FWHP = 380 PSI; lAP = 1730 PSI; OAP = 0 PSI; FWHT 143 °F 8:45 SI GL. 8:50 SI WELL. 8:55 RIH WITH PFC, GR, AND GUN #1 (20 FEET), 2.0' FROM CCL TO TOP SHOT. NEW LINE. RIH SLOW TO SEASON LINE. 10:15 SIWHP=1300 PSI. STOP @ 11950'. OPEN CK TO 40 BEANS. DROP DOWN TO 12200'. TIE IN TO CBL DATED 4/2/87. (-17'). ** HUNG UP @ 12054'. TOOLS FREE AFTER WORKING UP & DOWN TWICE. RIH TO PBTD @ 12210'. LOG CONFIRMATION PASS (+3). ** WT SWINGING BADLY OFF BTM. OPEN UP CK 80 BEANS. RIH TO PBTD @ 12234' MD GUN BTM. LOG CONFIRMATION STRIP. HANG UP @ 12052' CCL & 12038' CCL DEPTH. RIH. 11:18 LOG INTO PLACE @ 12207' CCL. SHOOT GUN#1 FROM12209-12229' MD BKB. GOOD INDICATION 100# WT. LOSS. LOG OFF. FLAG LINE @ 11998'. SHUT IN WELL. POOH. 12:47 OOH. ALL SHOTS FIRED. 13:15 RIH W/GUN #2 (10 FEET), 2.0' FROM CCL TO TOP SHOT. RIH TO 11950'. OPEN CK TO 40 BEANS. RIH. LOG TIE IN PASS (-2). LOG INTO POSITION @ 12197' MD CCL DEPTH, TS @ 12199' MD.. 14:45 SHOOT GUN #2 FROM 12199'-12209' MD BKB. NO WT. CHANGE. NO CAP BREAK? LOG OFF. SHUT IN WELL. POOH. 16:10 OOH. ALL SHOTS FIRED. RDMO ATLAS. 16:30 POP WELL FOC WITH GL. PERFORATION SUMMARY: GUN SBT DEPTH FEET SUBZONE I 12209'-12229' 20 3A2 2 12199'-12209' I 0 3A2 THE INTERVAL WAS SHOT USING 3-3/8" ALPHA JET HSC GUNS AT 6 SPF, 60° PHASING AND 0° ORIENTATION. NOTE: THE ORIGINAL PERF INTERVAL TO BE SHOT WAS FROM 12198-12238'. THE BTM 9' WAS NOT SHOT BECAUSE PBTD HIGHER THAN EXPECTED. THE TOP 1' OF THE INTERVAL NOT SHOT BECAUSE GUN #1 HAD TOO MUCH DRAG OFF ALOT OF DRAG OFF BTM.; POSSIBLY COULD HAVE SHOT TO HIGH. WAS ABLE TO CONTROL DEPTH BETTER WITH SHORTER GUN LENGTH. 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 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) BP Exploration (Alaska) Inc. Development X KBE = 55.4 feet Exploratory 3. Address Stratigraphic __ 7. Unit or Property name P. O. Box 196612, Anchorage, Alaska 99519-6612 Service Duck Island Unit/Endicott 4. Location of well at surface 8. Well number 2508' SNL, 680' WEL, Sec. 8, T11N, R17E At top of productive interval 4529' SNL, 1835' WEL, Sec. 4, T11N, R17E At effective depth 4418' SNL, 1650' WEL, Sec. 4, T11N, R17E At total depth 4386' SNL, 1620' SEL, Sec. 4, T11N, R17E 3-35/L-36 SDI 9. Permit number/approval number 87-20/Not Required 10. APl number 50- 029-21701 11. Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 12640 feet 10410 BKB feet 12548 feet 10239 BKB feet Plugs (measured) Junk (measured) Top of cement after workover of 11/20/93 at 12250' MD 20' WD packer on bottom Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 123' 2464' 11951' 903' Size 30" 13 3/8" 9 5/8" Cemented Measured depth BKB True v~r~al depth Driven 161' 161' 3720 c.f. Permafrost Cmt 2503' 2501' 575 c.f. Class G 11989' 9915' measured 7" 315 c.f. Class G 11737' - 12640' 9734' - 10410' 12040'- 12060' (Open), 12066'. 12076'(Open), 12086'- 12096' (Open), 12114'- 12146' (Open), 12198'- 12240' (Squeezed), 12250' - 12300'(Squeezed), 12301' - 12322' (Squeezed) 12199' - 12229' (Open) true vertical (Subsea) 10016'- 10049' (Squeezed), 10056'- 10095' (Squeezed) 10095' - 10111' (Squeezed), 9897' - 9912; 9916' - 9924; 9931' - 9939, 9952' - 9977' (All Open) 10017' - 10040' (Open) Tubing (size, grade, and measured depth) 4 1/2" 12.6#/Ft. L80 TDS Tubing to 11801' MD Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary Baker9 5/8" 9CR SB-3 Packer at 11668'; 4 1/2" Otis 'HXO' BVLN at 1516' 14. Intervals treated (measured) Treatment description including volumes used and final pressure ,v,,~,~i~[t 0it & ~s C0~s. ~.0mrnis~'°n Representative Daily Average Production or Injection"l~ta , OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 412 71 2013 0 447 Subsequentto operation 885 326 2065 0 439 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. J/ Si~ned ~~-~-~. ~- Title Sr. Technical Assistant II Date 7//~-~/~., ' SUBMIT IN [~UPDOATE Form 10~t' Rev 06/15/88 Production Engineering Department DATE: 6/1 7/9 5 WELL N°: 3-35 / L-36 BP EXPLORATION REP: REPERF R. CLUMP SERVICE CO: ATLAS (BARBA) DATE/TIME OPERATIONS SUMMARY 8:00 MIRU. FWHP = 380 PSI; lAP = 1730 PSI; OAP = 0 PSI; FWHT 143 °F 8:45 SI GL. 8:50 SI WELL. 8:55 RIH WITH PFC, GR, AND GUN #1 (20 FEET), 2.0' FROM CCL TO TOP SHOT. NEW LINE. RIH SLOW TO SEASON LINE. 10:15 SIWHP=1300 PSI. STOP @ 11950'. OPEN CKTO40 BEANS. DROP DOWN TO 12200'. TIE IN TO CBL DATED 4/2/87. (-17"). ** HUNG UP @ 12054'. TOOLS FREE AFTER WORKING UP & DOWN TWICE. RIH TO PBTD @ 12210'. LOG CONFIRMATION PASS (+3). ** WT SWINGING BADLY OFF BTM. OPEN UP CK 80 BEANS. RIH TO PBTD @ 12234' MD GUN BTM. LOG CONFIRMATION STRIP. HANG UP @ 12052' CCL & 12038' CCL DEPTH. RIH. 11:18 LOG INTO PLACE @ 12207' CCL. SHOOT GUN#1 FROM1;2,~209-12229' MD BKB. GOOD INDICATION 100# WT. LOSS. LOG OFF. FLAG'LINE @ 11998'. SHUT IN WELL. POOH. 12:47 OOH. ALL SHOTS FIRED. 13:15 RIH W/GUN #2 (10 FEET), 2.0' FROM CCL TO TOP SHOT. RIH TO 11950'. OPEN CK TO 40 BEANS. RIH. LOG TIE IN PASS (-2). LOG INTO POSITION @ 12197' MD CCL DEPTH~ TS @ 12199' MD.. 14:45 SHOOT GUN #2 FROM 12199'-12209' MD BKB. NO WT. CHANGE. NO CAP BREAK? LOG OFF. SHUT IN WELL. POOH. 16:10 OOH. ALL SHOTS FIRED. RDMO ATLAS. 16:30 POP WELL FOC WITH GL. PERFORATION SUMMARY: GUN SBT DEPTH FEET SUBZONE I 12209'-12229' 20 3A2 2 12199'-12209' I 0 3A2 THE INTERVAL WAS SHOT USING 3-3/8" ALPHA JET HSC GUNS AT 6 SPF, 60° PHASING AND 0° ORIENTATION. NOTE: THE ORIGINAL PERF INTERVAL TO BE SHOT WAS FROM 12198-12238'. THE BTM 9' WAS NOT SHOT BECAUSE PBTD HIGHER THAN EXPECTED. THE TOP 1' OF THE INTERVAL NOT SHOT BECAUSE GUN #1 HAD TOO MUCH DRAG OFF ALOT OF DRAG OFF BTM.; POSSIBLY COULD HAVE SHOT TO HIGH.. WAS ABLE TO CONTROL DEPTH BETTER WITH SHORTER GUN LENGTH. LARRy GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 20 June 1995 RE: Transmittal of Data Sent by: PRIORITY MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL ~/~ # DESCRIPTION 3-05/0-29 1 PFC/PERF.FINAL BL+RF 3-35/L-36 SDI~' /f'~')1 PFO/PERF--'~ ~ FINAL BL+RF V-- PFC/PERF FINAL BL+RF 1-31/M-21 1 SBT/GR FINAL BL+RF ECC No. Run # 1 2628.06 Run # 1 5921.09 Run # 1 6446.01 Run # 1 Run # 1 6446.00 Please sign and return to: Att~ Rodney/~. Paulson atlas~r~ine Services ~C~ A~ch~rage, AK 99518~~/ AX to (907) 563-7803 Received .~~(//~~ Date: ' STATE OF ALASKA A~_ASKA OIL AND GAS CONSERVATION COMMIo,51ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2508'SNL, 680'WEL, Sec. 8, T11N, R17E At top of productive interval 4529'SNL, 1835' WEL, Sec. 4, T11N, R17E At effective depth 4418'SNL, 1650' WEL, Sec. 4, T11N, R17E 5. Type of Well: Development X Exploratory Stral~graphic Service. RECEIVED JAN 0 1995 Gas Cons. Commission 6. Datum elevation (DF or KB) KBE = 55.4 feet '7. Unit or Property name Duck Island Unit/Endicott 8. Well number 3-35/L-36 SDI 9. Permit number/approval number 87-20/Not Required ,, 10. APl number 50- 029-21701 At total depth 4386' SNL, 1620' SEL, Sec. 4, T11N, R 17E 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 12640 feet 10410 BKB feet 12548 feet 10239 BKB feet ~ch0r[ :' 11. Field/Pool Endicott Oil Pool Plugs (measured) Junk (measured) T1~P25of cement after workover of 11/20/93 at O' MD Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True ve~PBal depth BKB 123' 30" Driven 161' 161' 2464' 13 3/8" 3720 c.f. Permafrost Cmt 2503' 2501' 11951' 9 5/8" 575 c.f. Class G 11989' 9915' Tubing (size, grade, and measured depth) 903' 7" 315 c.f. Class G 11737' - 12640' 9734' - 10410' measured 12040' - 12060' (Open), 12066' - 12076'(Open), 12086' - 12096' (Open), 12114' - 12146' (Open), 12198'- 12240' (Squeezed), 12250'- 12300'(Squeezed), 12301'- 12322' (Squeezed) true vertical (Subsea) 10016'- 10049' (Squeezed), 10056'- 10095'(Squeezed) 10095' - 10111' (Squeezed), 9897' - 9912', 9916' - 9924', 9931' - 9939, 9952' - 9977' (All Open) 4 1/2" 12.6tt/Ft. L80 TDS Tubing to 11801' MD Packers and SSSV (type and measured depth) Baker 9 5/8" 9CR SB-3 Packer at 11668'; 4 1/2" Otis 'HXO' BVLN at 1516' 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 Reoresentative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 962 641 1385 0 1767 1263 2O75 0 Tubing Pressure 406 409 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. Signed ~~;L...-'/2.,,-/~ ~. ,~,,-~'"~.d TitleSr. TechnicalAssistantll SUBMIT IN DU'PLIC'ATE Form 10- ~:{ev 06/15/88 I, Endicott Production Engineering Department DATE: 10/16/94 WELL N~: 3-35/L-36 TYPE OF OPERATION: BP EXPLORATION REP: SERVICE COMPANY: ADD PERFORATIONS MARTIN ATLAS WlRELINE SERVICES CURRENT WELL DATA ,, Date Gross Oil Choke GOR W/C IGL Rate WHP WHT TGLR Liquid Rate 10/15/94 3,298 1,319 104 528 60% 3,197 418 158 1,181 10/12/94 2,347 962 104 666 59% 3,064 406 156 1,578 · 09/21/94 2,434 876 104 642 64% 2,962 3'60 154 1,448 08/18/94 2,142 728 104 57a 66% 2,864 349 153 1,531 08/04/94 2,367 852 104 612 64% 2,770 352 152 1,391 07/23/94~ 2,434 876 104 634 64% 2,605 355 153 1,298 CURRENT PERFORATIONs Meas Depth Meas DepthSubsea Depth Subsea Depth Shot Comments Top Base Top Base Densit~ 12,114 12,1461 9,952 9,976 6 ~ 12,198 12,240 10,016 10,048 Squeeze' 12,250 12,300 10,056 10,095 Squeez~ 12,301 12,322 10,095 10,111 ~~ DATE TiME OPERATIONS SUMMARY 10/16/94 1100 ATLAS ON LOCATION. RIG UP. 1300 ARM GUN #1 & 2 WITH EBW F-2 PACKAGE. SHUT IN GAS LIFT. 1400 SHUT IN WELL AND RUN IN HOLE. TIE IN TO CBL-GR DATED 4/2/87. 1530 POSITION AND FIRE GUN #1 AT 12,086' TO 12,096' POSITION AND FIRE GUN #2 AT 12,066' TO 12,076'. POH. ALL SHOTS FIRED. 1700 RIH WITH GUN #3. 1830 POSITION AND FIRE GUN ~3 AT 12,040' TO 12,060' POH 2000 OUT OF HOLE AND RIG DOWN. POP WELL AT 104/64" CHOKE WITH 1.5 MM GAS LIFT. ,,, NOTE: THIS WAS THE FIRST SUCCESSFUL FIRING OF THE ATLAS WIRELINE EBW/F2 SYSTEM (2 GUNS ON ONE TRIP IN THE HOLE). ALSO THE FARTHEST NORTH. · . PERFORATING SUMMARY:. DEPTH GUN TYPE CHARGE SHOTS PHASING ORIENTATION PER FT. 12,040' - 12,060' 3-3/8" ALPHA JET 21 GM. 4 60 / 120° RANDOM 12~066' - 12,076' 3-3/8" ALPHA JET 21 GM. 4 60 / 120° RANDOM 12,086' - 12,096' 3-3/8" ALPHA JET 21 GM. 4 60 / 120° RANDOM RECEIVED JAN 03 1995 Naska 0ii & Gas Cons. Commission LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: RE: 20 October 1994 Transmittal of Data ECC #: 5921.08 Sent by: U.S. MAIL Data: PFC/PERF Dear Sir/Madam, Reference: BP 3-35/L-36 SDI ENDICOTT NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 PFC/PERF FINAL BL Run # 1 1 PFC/PERF RF SEPIA Run # 1 Pl~e-~Ign ~nd retU~--n ko: '~t~as Wi==ti~= -" ' 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson ~ Or FAX~o (907) 563-7803__~ Received by~~~//~~~r Date: RE¢£1V b ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 23 April 1994 RE: Transmittal of Data Sent by: ANCHORAGE EXPRS Dear Sir/Madam, Enclosed, please find the data as described below: WELL 2-7o/u-15 3-17/J-30A SDI DESCRIPTION 1 PFC/PERF FINAL BL ~I/PFC/PERF RF SEPIA 1 SBT/GR/CCL FINAL BL 1 CN/GR FINAL BL 1 SSVD/CN/GR FINAL BL C.?,,/1 SBT/GR/CCL RF SEPIA C~,-/I CN/GR FINAL RF SEPIA ¢~ v,,'Z SSVD/CN/GR RF SEPIA 1 GR/CCL JEWL.FINAL BL I PLS 'PROF. FINAL BL /1 GR/CCL JEWL.RF SEPIA ~/1 PLS PROF. RF SEPIA 2-08/K-16 MPI 1/PLS FINAL BL ~ PLS FINAL RF SEPIA 3-47/Q-35 SDI 1/PFC/PERF 'FINAL BL PFC/PERF RF SEPIA 1 PLS PROF. FINAL BL 1 GR/CCL JEWL.FINAL BL ~/.PLS PROF. RF SEPIA -~1 GR/CCL JEWL.RF SEPIA ~-~O 3-35/L-36 SDI ~% ~2- 2-04/M-19 2-04/M-19 1 PLS PROF. FINAL BL /PLS PROF. RF SEPIA 1 PLS PROF. FINAL BL _3~PLs PROF. RF SEPIA /1 PFC/PERF FINAL BL PFC/PERF RF SEPIA ECC No. Run # i 6110.01 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run ~ 1 Run # 1 Run $ 1 Run # 1 Run $ 1 Run # 1 Run $ 1 Run ~ 1 Run ~ 1 Run $ 1 Run ~ 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run ~ 1 6185.00 6006.01 6175.00 5764.02 6034.03 5921.07 5985.04 5985.05 Cont / 2-v0/U-lS i'PFC/PERF FINAL BL PFC/PERF RF SEPIA 1 PLS INJ. FINAL BL /~PLS INJ. RF SEPIA 1PFC/PERF FINAL BL .wl PFC/PERF RF SEPIA Run # 1 Run # 1 6001.09 Run # 1 Run # 1 6110.02 Run # 1 Run # 1 6034.02 Please sign and return to: Atlas-"Wireline Services 5600 B-Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Received by: Date: Please sign and return to: Sonya-Wallace (MB 3-3) Petrotechnical Data Center BP Exploration (Alaska) Inc. 900 East Benson Boulevard Anchorage, Alaska 99508 Received by: Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISc,,ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown .. Stimulate Plugging .. Perforate× L~,~?,/~,~, I Pull tubing Alter casing Repair well Other X 5. Type of Well: 6. Datum elevation (DF or KB) Development ~ KBE = 55.4 .... 2. Name of operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface Exploratory , Stratigraphic Service ,,, 2508'SNL, 680'WEL, Sec. 8, T11N, R17E At top of productive interval 4,529'SNL, 1835' WEL, Sec. 4, T11N, R17E At effective depth 4418' SNL, 1650' WEL, Sec. 4, T11N, R17E At total depth 4386' SNL, 1620' SEL, Sec. 4, T11N, R17E 12. Present well condition summary Total depth: measured true vertical RECEIVED Cons. Commission Anchorage 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 3-35/L-36 SDI 9. Permit number/approval number 87-20/Not Required 10. APl number 50- 029-21701 11. Field/Pool Endicott Oil Pool 12640 feet 10410 BKB feet Plugs (measured) Top of cement after workover of 11/20/93 at 12250' MD Effective depth: measured true vertical 12548 feet 10239 BKB feet Junk (measured) 20' WD packer on bottom Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth BKB 123' 30" Driven 161' 2464' 13 3/8" 3720 c.f. Permafrost Cmt 2503' 11951' 9 5/8" 575 c.f. Class G 11989' Tubing (size, grade, and measured depth) True ve~l depth 161' 2501' 9915' 903' 7" 315 c.f. Class G 11737' - 12640' 9734' - 10410' measured 12114' - 12146' (Squeezed), 12198' - 12240' (Squeezed), 12250' - 12300'(Squeezed) 12114' 12146' (Open) true vertical (Subsea) 9952'- 9977/(Squeezed), 10016'- 10049' (Squeezed), 10056'- 10095' (Squeezed) 9952'- 9977' (Open) 4 1/2" 12.61t/Ft. LSO TDS Tubing to 11801'MD Packers and SSSV (type and measured depth) Baker 9 5/8" 9CR SB-3 Packer at 11668'; 4 1/2" Otis 'HXO' BVLN at 1516' 13. Stimulation or cement squeeze summary Coiled tubing Cement Squeeze performed on January 8, 1994 Intervals treated (measured) 12114'-12146', 12198'-12240', 12250'-12300' Treatment description including volumes used and final pressure 1198 Bbls seawater, 20 Bbls Class "G" cement, 45 Bbls Methanol, 21 Bbls effluent water, 24 Bbls 15% HCL w/20% Xylene, and 95 Bbls seawater overflush acid. FSlWHP = 2100 psig 14. Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run . Daily Report of Well Operations X Representative Daily Average Producti0rt or Injection Data OiI-Bbl Tubing Pressure 283 329 239 321 Gas-Mcf Water-Bbl Casing Pressure 362 3259 0 ~ 23 585 0 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. Form 10,404 Rev 06/15/88 SUBMIT IN DOPLI~,ATE ,,,, Endicott Production Engineering Department Post Squeeze Perforations DATE: 1/14/94 WELL N~: 3-35/L-36 BP EXPLORATION REP: POWERS SERVICE COMPANY: ATLAS/BARKER DATE/TIME OPERATIONS SUMMARY 1/14/94 080 Spotted heater & bleed tank. Shot fluid levels IA = 3800' @ 500psig, Tubinl~ = 3500' @ 400 psil~. Underba!ance = + 600 psil~. 0900 MIRU. Post radio silence signs at the entrance to the island and adiacent to the well site. 1100 Install SSV fusible cap. The SSSV is OUT. WHP = 400 psig. IAP = 500 psig. OAP = 0 psig. 1120 ESTABLISH RADIO SILENCE AND ARM GUNS '~'._4otify rig, security). 1200 PT Lubricator and RIH with Gun gl (22 feet, 60° Phase, 6 SPF - 3- 3/8" Alpha Jet) 1330 Tie in to CBL dated 4/2/87 logging up. 1340 Hang gun gl @ 12,120' (4' stand off), Shoot gun gl from 12124'- 12146' MDBKB. SIWHP = 450 psig. 1345 POH. 1350 FWHP = 450 psig. Started flowing well @ 15 Beans & 2 MMSCFD Lift Gas. 1520 RIH with Gun g2 (10 feet, 60° Phase, 6 SPF - 3-3/8" Alpha Jet. FWHP = 970, IAP = 1500 psig 1630 Tie in to CBL logging up. 1645 Hang gun g2 @ 12112' (2' standoff). Shoot gun g 2 from 12114' - 12124' MDBKB. WHP = 1500 psig~ IAP = 2100 psig 1650 POH 1800 Confirm all shots fired. 1820 End radio silence. 1900 RD Atlas. FWHP = 1300 psig, IAP = 1700 psig. Choke @ 50 beans. Turned off gas lift to bleed well to flowline pressure. 2000 MO, FWHP=350 psig, IAP=1000 psig, 2.3 MMSCFD Gas lift. PERFORATION SUMMARY: GUN INTERVAL(CBL) i 12124-12146 2 12114-12124 FEET SUBZONE 22 3A3 10 3A3 All intervals were shot using 3 3/8 guns at 6 spf, 60 degree phasing, and random orientation. The tie-in log was on depth with the open hole reference log. ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 25 January 1994 RE: Transmittal of Data ECC #: 5921.06 Data: PL Dear Sir/Madam, Reference: BP ' 3-35/L-36 SDI ~'~__ ~ ENDICOTT NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: . 1 1 Sent by U.S. MAIL PFC PERF FINAL BL I Run # 1 Run # 1 Please sign and return to: Atlas Wireline Services Petrophysical Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Received by: Date: coo2 . ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 7 January 1994 RE: Transmittal of Data ECC #: 5921.04 Data: NONE Dear Sir/Madam, Reference: BP 3-35/L-36 SDI ENDICOTT NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 1 Sent by U.S. MAIL COLLAR LOG RF SEPIA COLLAR LOG FINAL BL Run # 1 Run # 1 Please sign and return to: Atlas Wireline Services Petrophysical Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Date: ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRy GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 7 January 1994 RE: Transmittal of Data ECC #: 5921.05 Data: PL Dear Sir/Madam, Reference: BP 3-35/L-36 SDI ENDICOTT NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 1 Sent by U.S. MAIL PLS FINAL BL PLS FINAL RF SEPIA Run # 1 Run ~ 1 Please sign and return to: Atlas Wireline Services Petrophysical Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Received by: Date: BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson BouLevard P.O, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 12/22/93 T# 85366 DUCK ISLAND/ENDICOTT SUNDRIES Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. / %3-17/J-3o SN lZ/14/93 REF#93-338 ~3~-35/L-36 SM 12/17/93 REF#93-302 87- ~o V~IANdE/PERMIT # 89-53 BPX PULL TUBING/PERMIT #87- BPX Cathryn Mitchell Petrotechnical Data ~entre STATE OF ALASKA · · AI.A~, OIL AND GAS CONSERVATION COMMIS$,,.,N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Pull tubing _X.. Stimulate Alter casing .. Plugging Perforate Repair well Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519,6612 4. Location of well at surface 2508' SNL, 680' WEL, Sec. 8, T11N, R17E At top of productive interval 4529'SNL, 1835' WEL, Sec. 4, T11N, R17E At effective depth 4464'.SNL, 1753' WEL, SEC. 4, T11N, R17E o At total depth 4386' SNL, 1620' SEL, Sec. 4, T11N, R17E 5. Type of Well: Development Exploratory StralJgraphic Ser~ce X. .. RECEIVED JAN 0 7 1994 Oil & &~s Cals. ~ 6. Datum elevation (DF or KB) KBE,, 55.4 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 3.35/L-36 SDI 9. Pe~umber/approval number ~3-302 10. APl number 50- 029-21701 11. Field/Pool Endicott Oil Pool 12, Present well condition summary Total depth: measured true vertical 12640 feet 10410 BKB feet Plugs (measured) Effective depth: measured 12395 feet Junk (measured) · . true vertical 10222 feet 20' WD packer on bottom Fill @ 12395' (11/17/93) Casing . . .~ Length. . Size Cemented --' ' Intermediate . 11951' - 9 5~" 575 cf. Cl~s G Pr~u~ion -~:~ Uner ~,x.-.-~. -::~:.~ ?::~: - - ... ~--.~-~, _ 903'. ......... ',: '-~-.. ~ 315 ~f. Cl~s G _~. ' . '..:-.?:: ' ' . ;L · ' "." "Peroration de,h: ~ measured ~2~4'- .. &~:~?'/?:':--'--~ :--. ..... ;':: tmeVe~i~ 10~-10032; 10071~10103; 10111~10150' ':::.Tubing (s~e, grade, and measured ~pth) 4 1~" 12.~t. ~0 Tubi~ ~ 11801'MD - -~-'~ Pa~ers a~ S~V {~ a~ measur~ d~th) Measured depth True v~al depth BKB , ' 161' .. 161' 2503' .2501' 11989' 9915' 11737' - 12640' 9734'- 10410' Baker9 5/8', 9CR SB-3 Packer at 11668'; 4 1/2' Otis 'HXO' BVLN at 1516' 13, Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Reoresentative Daily Averaoe Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys. run -- Daily Report of Well Operations. X ~ Oil. X Gas Suspended Service 17. i hereby c~. rtify that the,foregoing is tr~e and correct to the best of my knowledge. sig~ed~ ~ ~' '~'" ~(,..'J *"~/~/~/'/(.~ T~tle Drill/hq Engineer Supervisor For -404 OSn S/SS j Date SUBMIT IN DUPLICATE ...... BP/AAI SHARED SERVICE DAILY OPERATIONS WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: SD1 3-35/L-36 . ' -_-. -- : . -:'.. ._.._- . NORTH SLOPE .- . - .. ._--_ -: ....~ .....--- _ _ ACCEPT: ENDICOTT - :-.. ~- _- ........ '_ - SPUD: ENDICOTT ~" - -' RELEASE: ..... - ...... OPERATION: 50-029-21701 - .- .--- ~:~:'"~:-:------ ........... DRLG RIG: DOYON 15 .... '-' - WO/C RIG: DOYON 15 pAGE: 1 : 11/13/93 ( 1) TD:12548 PB: 0 11/14/93 ( 2) TD:12640 PB:12548 11/15/93 ( 3) 7%~?: 'PB: 12548 R/D WELLHOUSE. ' ' MW: 0.0 MOVE RIG. RIG ACCEPTED_ @~22:00 HRS, 11/12/93. R/U CAMCO. . . ' TEST TBG. R/D- CAMCO. DECOMMISION WELLHOUSE. DISP WELL TO-SEAWATER. - MW: 8.6 Seawater R/D WELLHOUSE.'- N/D TREE N/U BoPE. TEST BOPE. M/U LAND JT. P/U HGR. SHEAR SBR SCREWS. DISP OUT DIESEL. _ _ . N/U BOPE. ' MW: 8.6 Seawater POOH, L/D TBG~'- RIH W/ SLICK STICK FISH ASS'Y TO 11500'. 'N/D BOPE. CHANGE PACKOFF. N/U BOPE. TD:12640 :/~::--~:~:_ ~--'~:':::~'~:~<~:~:N/U BOPE?~f:--.TEST BOPE.- L/D STO~ P~. FISH FOR SLICK . 8 ~:/.:.:'-:' ...... '-:-'-~:::~:~:~:' STICK. u POOH W~' S~..:-:: RIH W/ MILL. MILL PKR. PUSH P~ TO ~-. ~':~':~'"' ~-~ ' ~:'"? TOL ~ 11737'. ' CBU. -' :11/17/93~--(-5) '::- L/D PKR. ' ~: 8.6 Seawater TD:12640.~;::__~, ~, ::,...3:; CIRC. POOH: '~ L'/D B~._ RIH W/ SPEAR. CIRC. RIH TO 11716' PB:12548~f,?~::'..':~.: ~:---:-:::~::_~:-(TOF)-.-~---CBU.-- FISH P~.::~-CIRC. --POOH W/ PKR. L/D S~. ..~:~::~%11/18/93-(.'. 6) . -- L/D DP .... ' - '-:-' ~: 8.6 Seawater 'TD:12640~:'-~%,:'_ "- ~._~ L/D B~.-'- RIH. TAG FmLL' ~ 121'09' - ~ TO PBTD 8 12395'. PB:12548'/~?~:-::'~.~ ~.. ,_, .... '~''--~' CmRC. ~V CIRC. CmRC.-'":~ ~V CIRC..~ POOH. 'i'~:~9/93-~ (7) N/U T~E.. - ..... ::'-: .......... ~: 8.6 Seawater ' .:.~:TD:12640 L/D DP. RIH W/ 4-1/2" 'L-80 CO~ ASS'Y. INSTALL HGR. 12548 ~:." . TBG. L/D-~ ~-~ JT. ~'N/D BOPE.' -~' 11/20/93 ( 8) TD: 12640 SIGNAT~: RIG RELEASED. MW: 8.6 Seawater N/U TREE. TEST TREE. OK. DROP BALL. SET PKR W/ 3500 PSI. TEST TBG. OK. TEST.ANNULUS. OK. PUMP 103 BBLS DIESEL DN ANNULUS, TBG.- F/P TO 1500'_ SET BPV. SECURE WELL._ RIG RELEASED. @ 01:00 HRS, 11/20/93. MOVE RIG. ,, (drilling superintendent) DATE: : . STATE OF ALASKA ALA,_..,~ OIL AND GAS CONSERVATION COMMISS,,_.. REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate '~!~?~.~- _.-.~ Pull tubing X Alter casing Repair well Other "' ~?~)'~'" ~..,~ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) BP Exploration (Alaska) Inc. Development X KBE = 55.4 Exploratory 7. Unit or Property name 3. Address Stratigraphic P. 0. Box 196612, Anchorage, Alaska 99519-6612 Ser~ce 4. Location of well at surface 2508' SNL, 680' WEL, Sec. 8, T11N, R17E At top of productive interval 4529'SNL, 1835' WEL, Sec. 4, T11N, R17E At effective depth 4464' SNL, 1753' WEL, SEC. 4, T11N, R17E At total depth 4386'SNL, 1620'SEL, Sec. 4, T11N, R17E Duck Island Unit/Endicott 8. Well number 3-35/L-36 SDI 9. Permit number/approval number 87-2O/93-3O2 10. APl number 50- 029-21701 11. Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured true vertical 12640 feet 10410 BKB feet Plugs (measured) Effective depth: measured true vertical 12395 feet 10222 feet Junk (measured) 20' WD packer on bottom Fill @ 12395' (11/17/93) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth BKB 123' 30" Driven 161' 2464' 13 3/8" 3720 c.f. Permafrost Cmt 2503' 11951' 9 5/8" 575 c.f. Class G 11989' 903' 7" 315 c.f. Class G measured 12114'- 12146', 12198'-12240', 12250'-12300' 11737' - 12640' True v~B~l depth 161' 2501' 9915' 9734'- 10410' true vertical 10007'-10032', 10071'-10103', 10111'-10150' Tubing (size, grade, and measured depth) 4 1/2" 12.6#/Ft. L80 Tubing to 11801'MD Packers and SSSV (type and measured depth) Baker9 5/8", 9CR SB-3 Packer at 11668'; 4 1/2" Otis 'HXO' BVLN at 1516' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. DEC 2 0 199~ Alaska 0il & Gas Cons. Commission - .:.-,,u, ayu Representative Daily Average Production or In!ection Data Prior to well operation OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Subsequent to operation 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 ce. rtify that the,foregoing is true and correct to the best of my knowledge. Signedt~ ~ ~ ~/~---/~ "'~.,,-~/(.A Title Drilling Engineer Supervisor Form 11~-404 F~ev 06/15/88 '~ ~/ Date SUBMIT IN DUPLICATE .B.P/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: SD1 3-35/L-36 BOROUGH: NORTH SLOPE UNIT: ENDICOTT FIELD: ENDICOTT LEASE: API: 50-029-21701 PERMIT: APPROVAL: ACCEPT: SPUD: RELEASE: OPERATION: DRLG RIG: DOYON 15 WO/C RIG: DOYON 15 11/13/93 ( 1) TD:12548 PB: 0 R/D WELLHOUSE. MW: 0.0 MOVE RIG. RIG ACCEPTED @ 22:00 HRS, 11/12/93. R/U CAMCO. TEST TBG. R/D CAMCO. DECOMMISION WELLHOUSE. 11/14/93 ( 2) TD:12640 PB:12548 DISP WELL TO SEAWATER. MW: 8.6 Seawater R/D WELLHOUSE. N/D TREE. N/U BOPE. TEST BOPE. M/U LAND JT. P/U HGR. SHEAR SBR SCREWS. DISP OUT DIESEL. 11/15/93 ( 3) TD:12640 PB:12548 N/U BOPE. MW: 8.6 Seawater POOH, L/D TBG. RIH W/ SLICK STICK FISH ASS'Y TO 11500'. N/D BOPE. CHANGE PACKOFF. N/U BOPE. 11/16/93 ( 4) TD:12640 PB:12548 11/17/93 ( 5) TD:12640 PB:12548 CBU. MW: 8.6 Seawater N/U BOPE. TEST BOPE. L/D STORM PKR. FISH FOR SLICK STICK. POOH W/ SAME. RIH W/ MILL. MILL PKR. PUSH PKR TO TOL @ 11737' CBU. L/D PKR. MW: 8.6 Seawater CIRC. POOH. L/D BHA. RIH W/ SPEAR. CIRC. RIH TO 11716' (TOF). CBU. FISH PKR. CIRC. POOH W/ PKR. L/D SAME. 11/18/93 (6) TD:12640 PB:12548 L/D DP. MW: 8.6 Seawater L/D BHA. RIH. TAG FILL @ 12109'. REAM TO PBTD @ 12395'. CIRC. REV CIRC. CIRC. REV CIRC POOH. 11/19/93 ( 7) TD:12640 PB:12548 N/U TREE. MW: 8.6 Seawater L/D DP. RIH W/ 4-1/2" L-80 COMP ASS'Y. INSTALL HGR. LAND TBG. L/D LAND JT. N/D BOPE. 11/20/93 (8) TD: 12640 PB:12548 RIG RELEASED. MW: 8.6 Seawater N/U TREE. TEST TREE. OK. DROP BALL. SET PKR W/ 3500 PSI. TEST TBG. OK. TEST ANNULUS. OK. PUMP 103 BBLS DIESEL DN ANNULUS, TBG. F/P TO 1500' SET BPV. SECURE WELL. RIG RELEASED @ 01:00 HRS, 11/2~/93. MOVE RIG. SIGNATURE: (drilling superintendent) DATE: RECEIVED C 2 0 1995 & Gas Cons. Commission Anchorage EMORAND UM TO: David JohnSon Chairma~ STATE O l t LA SKA ALASKA OIL AND GAS CONSER VA TION COMMISSION DATE: November-15-1993 FILE NO: ALHJKOAD.DOC THRU: Blair Wondzeli P.I. Supervisor FROM: Lou Grimaldi/A:9~:~ Petroleum Inspector PHONE NO.: 279-1433 SUBJECT: BOP test Doyon rig # 15 BPX well # 3-35/L-36 SDI Endicott field D.I.U. PTD # 87-2O Monday, November 15, 1993, I witnessed the weekly BOP test on Doyon rig # 15 which is performing workovers in the Endicott field. When I arrived,, the rig was not ready to start testing. Once the test began, things went smoothly, there was one failure I observed, this being the APl ring gasket between the riser and base flange of the stack assembly. This was a new ring and took a couple of tightening sequences to get a reliable seal on this connection. The remainder of the test went well and I feel, as is the case with the other Doyon rigs, that rig #15 is well maintained. The area surrounding the rig was clean and orderly, with adequate access provided. SUMMARY; ! witnessed the weekly BOP test on Doyon rig # 15. Test time four hours, one failure. Attachment: ALHJKOAD.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: 3-35/1_-36 Casing Size: Set (i~ Test: Initial Weekly X Other ~ DATE: 11/15/93 15 PTD # 87-20 Rig Ph.# 659-6510 Rep.: Steve Walls Rig Rep.: Al Sinclair Location: Sec. T. R. Meridian Test Well Sign OK Drl. Rig OK MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) Reserve Pit NA FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan. Pressure P/F 1 500t5000 I P . I 500t5000 I P I 500t5000 P ,,, 1 500~5000 P Test Quan. Pressure Test I 500/3500 Pressure I 500t5000 500t5000 1 500~5000 500~5000 BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve 500t5000 500~5000 500~5000 NrA P/F P P P P P P P 1 1 1 2 N~A MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators P P Flow Indicator P P Gas Detectors P P CHOKE MANIFOLD: No. Valves 18 No. Flanges 46 Manual Chokes 2 Hydraulic Chokes I 500~5000 P/F P 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: Four bottles 2100 Average 3,000 I P 1,400 P minutes 45 sec. minutes 25 sec. OK Remote: OK Psig. Number of Failures: I · ,Test Time: 4.0 Hours. Number of valves tested 25 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: APl ring gasket leaked, tightend ,tested "OK" Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c- Inspector FI-021L (Rev. 7/19) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES NO X Waived By: Witnessed By: ALHJKOAD.XLS Louis R Grimaldi 1. Type of Request: STATE OF ALASKA ~" ALAbr, A OIL AND GAS CONSERVATION COMMISS,,_. ~ ~ APPLICATION FOR SUNDRY APPROVALS Abandon __ Suspend Operation Shutdown Re-enter suspended well /6~'~'~ '1 Alter casing __ Repair wel--T- Plugging Time extension Stimulate I Change approved program __ -~--Pull tubing X Variance Perforate Other 6. Datum elevation (DF or KB)'~_/ KBE = 55.4 '~pet 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2508' SNL, 680' WEL, Sec. 8, T11N, R17E At top of productive interval 4529'SNL, 1835' WEL, Sec. 4, T11N, R17E At effective depth 4418' SNL, 1650' WEL, Sec. 4, T11N, R17E At total depth 4386'SNL, 1620'SEL, Sec. 4, T11N, R17E 12. Present well condition summary Total depth: measured true vertical 5. Type of Well: Development X Exploratory __ Stratigraphic 7. Unit or Property name Service Duck Island Unit/Endicott RECEIVED N OV - 2 1993 Alaska Oil & Gas Cons. Anchorage 12640 feet 10410 BKB feet Plugs (measured) 8. Well number 3-35/L-36 SDI 9. Permit number 87-20 10. APl number 50- 029-21701 11. Field/Pool Endicott Oil Pool Effective depth: measured true vertical 12548 feet 10239 BKB feet Junk (measured) 20' WD packer on bottom Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured cl~ Tru~/~rtical depth 123' 30" Driven 161' 161' 2464' 13 3/8" 3720 c.f. Permafrost Cmt 2503' 2501' 11951' 9 5/8" 575c. f. Class G 11989' 9915' 903' 7" 315 c.f. Class G 11737' - 12640' 9734' - 10410' measured 12114'- 12146' (Squeezed), 12198'- 12240' (Squeezed), 12250'- 12300'(Squeezed) 12113'- 12145', 12197'- 12237' true vertical (Subsea) 9952'- 9976'(Squeezed), 10016'- 10048' (Squeezed), 10056'- 10095' (Squeezed) 9952'- 9976', 10016'- 10047' Tubing (size, grade, and measured depth) 4 1/2" 12.6#/Ft. L80 TDS Tubing with 3-1/2" 9.2# tailpipe to 11807' Packers and SSSV (type and measured depth) 9 5/8" Packer at 11707'; 4 1/2" SSSV at 1566' 13. Attachments Description summary of proposal X Detailed operations program BOP sketch 14. Estimated date for commencing operation 11/5/93 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 fo. regoing is trpe and correct to the best of my knowledge. Signed - ' " , Title Drilling En,qineer Supervisor Date I/.~, " 'L~, ] FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness 2Approval No. ~ ~_ ~ ~ Plug integrity ~ BOP Test~ Location clearance ~ Approved ,.,,~y , Mechanical Integrity Test __ Approved by order of the Commission Form 10-403 Rev 06/15/88 Subsequent form required 10-//o. Origins! P~ed By Returned Commissioner Date /~'/~//~ ;~ SUBMIT IN TRIPLICATE ENDICOTT SDI 3-35/L-36 WORKOVER PLAN OBJECTIVES: A rig workover will be required on well 3-35/L-36 to change out the gas lift valves & run new 4-1/2" tubing. The scope of the work will be as follows: 1. Pull the 4-1/2" tubing 2. Mill and recover the 9-5/8" packer 3. Make a bit & scraper run & displace to clean brine 4. Recomplete with 4-1/2" L-80 tubing TIMING: 4th Quarter 1993 9 days plus well to well move with rig Doyon 15 PRE-RIG OPERATIONS , RU slick line. dummy off gas lift mandrels. Pull the WL SSSV. Bullhead sized salt pill to perforations followed by 8.6 ppg seawater. . RIH and set a positive plug in the 3-1/2" XN nipple in 3-1/2" tail pipe. Pressure test the 9-5/8" to 3500 psi. Report the test to Anchorage Drilling. . Dig out the cellar and level the pad. Inspect the wellhead and tree. Test the 9-5/8" packoff and function test the LDS's. 4. RUE line. RIH and cut the tubing 15' above the PBR. 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. RIG OPERATIONS , Mobilize Doyon 15. Review Endicott Simultaneous Operations Plan concerning rig moves. (1 day standby for pre rig work) . Circulate out the 10.7 ppg brine from the 4-1/2" x 9-5/8" with 8.6 ppg seawater. Check that the well is dead. Set the TWC. (1/2 day) 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 directly above the PBR. (1 day) . Set storm packer. N/D & change out 9-5/8" packoff. N/U BOPE. (1/2 day) hi OV - ~ 199) JLH Page 1 A~aska Oil & Gas Cons. Cor~'s$~'°t~ Anchorage November 1, 1993 ENDICOTT SDI 3-35/L-36 WORKOVER PLAN . . . . 10. 11. GIH w/ overshot and DP and RIH to the tubing cut directly above PBR. Recover the tubing stub and PBR. Fish the PBR and latch. (1-1/2 days) Mill up the packer. Recover the packer with a PRT if the packer has a millout extension. (1-1/2 day) Run an 6"mill and 9-5/8" casing scraper (spaced out above the liner top) to PBD. Dispace to clean 9.2 ppg brine. (1 day) P/U and run 9-5/8" packer with 4-1/2" L-80 completion assembly. (1 day) N/D BOPE. N/U 4-1/2" tree. (1/2 day) Release rig and turn the well over to Production. N OV - 2 A~aska ()ii & Gas Cons. Anchor,~ge JLH Page 2 November 1,1993 STATE OF ALASKA /"~') AL/~SKA OIL AND GAS CONSERVATION COMMISSION ,, REPORT OF SUNDRY WELL OPERATIO,, o Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other X 1. Operations performed: Operation shutdown 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2508'SNL, 680' WEL, Sec. 8, T11N, R17E At top of productive interval 4529'SNL, 1835'WEL, Sec. 4, T11N, R17E At effective depth 4418'SNL, 1650' WEL, Sec. 4, T11N, R17E At total depth 4386'SNL, 1620' SEL, Sec. 4, T11N, R17E 5. Type of Well: Development Exploratory Stratigraphic Service RECEIVED J UN 2 4 t99 Alaska Oil & Gas Cons, Commission Anchorage Datum elevation (DF or KB) KBE = 55.4 feet Unit or Property name Duck Island Unit/Endicott 8. Well number 3-35/L-36 SD/ 9. Permit number/approval number 87-20/Not Required 10. APl number 50- 029-21701 11. Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured true vertical 12640 feet 10410 BKB feet Plugs (measured) Effective depth' measured true vertical 12548 feet 10239 BKB feet Junk (measured) 20' WD packer on bottom Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True ve~l depth BKB 123' 30" Driven 161' 161' 2464' 13 3/8" 3720 c.f. Permafrost Cmt 2503' 2501' 11951' 9 5/8" 575 c.f. Class G 11989' 9915' Tubing (size, grade, and measured depth) 903' 7" 315 c.f. Class G 11737'- 12640' 9734'- 10410' measured 12114' - 12146' (Squeezed), 12198' - 12240' (Squeezed), 12250' - 12300'(Squeezed) 12113'- 12145', 12197'- 12237' true vertical (Subsea) 9952'- 9976'(Squeezed), 10016'- 10048' (Squeezed), 10056'- 10095' (Squeezed) 9952'- 9976', 10016'- 10047' 4 1/2" 12.6#/Ft. LBO TDS Tubing with 3-1/2" 9.2# tailpipe to 11807' Packers and SSSV (type and measured depth) 9 5/8" Packer at 11707'; 4 1/2" SSSV at 1566' 13. Stimulation or cement squeeze summary Coiled tubing Cement Squeeze Intervals treated (measured) 12114'-12146', 12198'-12240', 12250'- 12300' Treatment description including volumes used and final pressure 1088 Bbls seawater, 17 Bbls Class "G" cement, 38 Bbls Methanol, and 10 Bbls effluent water. FSIWHP = 1700 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 43 //// 1 387 0 1065 // 931 908 0 Tubing Pressure 410 323 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. (~j' 'C~ /~- TitleSr. TechnicalAssistantl! Signed ,,~"7,.~_. _ . ,¢~¢~' Form l~4'~'ev 06/15/88 SUBMIT IN D'UPL~OA~E ~ Endicott Production Engineering Department Perfgration After DATE: 4/13/93 WELL N~: 3-35/L-36 BP EXPLORATION REP: ALLAN/NORLANDER SERVICE COMPANY: AWS/BRUNNER Squeeze INOTE: INSURE THAT THE WELL SITE AREA, WELL HOUSE AND PRODUCTION TREE] ARE KEPT FREE OF CRUDE OIL, EQUIPMENT LEAKS OR TRASH, CLEAN UP ANY I CRUDE/HYDRAULIC OIL LEAKS BEFORE LEAVING THE JOB SITE, DATE/TIME OPERATIONS SUMMARY I 4/13/93 1030 RU. Post radio silence signs at the entrance to the island and adjacent to the well site. 1100 Install. SSV fusible cap. The SSSV is OUT. SIWHP = 500 psig. WHT = N/A de# F. IAP = 2500 psi#. OAP = O psi#. 1140 ESTABLISH RADIO SILENCE AND ARM GUNS. 1230 Test lubricator to SIWHP. RIH with GR/CCL and Gun gl (20 feet).Put well on production. 1330 Tie in to CET dated 4/2/87. All of the depths listed below are from the CET. Fla~ line for next run. SIWHP = 300 psi# . 1410 Hang gun gl Top Shot at 12218' MDBKB. 1420 Shoot gun gl from I2218-12238' MDBKB. FWHP = 300 psi#. 1425 POH. 1520 Ooh, all shots fired. RIH with Gun //2 (20 feet). SIWHP = 250 psi#. 1640 Open wing valve . 1650 Tie in to CBT logging up. Shoot gun # 2 from 12198 - 12218 MDBKB. FWHP = 250 psi#. 1710 SI well and POH. 1750 Ooh, all shots fired. RIH with Gun #3 ( 20 feet). SIWHP = 250 psi#. 1910 Open wing valve . 1920 Tie in to CBT logging up. Shoot gun # 3 from 12126 12146 MDBKB. FWHP = 250 psi#. 1940 Si well and POH. 2015 Ooh, all shots fired. RIH with Gun #4 ( 12 feet). SIWHP = 250 psig. 2045 Open wing valve . 2130 Tie in to CBT logging up. Shoot gun # 4 from 12114 - 12126' MDBKB. FWHP = 250 psi#. 2140 SI well and POH. SIWHP = 250 psi#,. Confirm all shots fired. 2230 End radio silence. 2315 RD. POP. PERFORATION sUMMARY: GUN INTERVAL(DLL) CET DEPTH FEET SUBZONE 1 12217-12237 12218-12238 20 3 A 2 2 12197-12217 12218-12198 20 3 A 2 3 12125-12145 12126-12146 20 3 A 3 4 12113-12125' 12114-12126 12 3 A 3 ~DATE: WELL N~: TYPE OF OPERATION: All intervals were shot using 2 1/8" JUMBO JET D. P. II guns at 4 spf, 0 degree phasing, no orientation, and 6.5 grams/charge. The t/e-in log was I feet deep with the open hole reference log. ,I UI~ 2 4 1§93 ,~laska Oil & Gas Cons. 6ommlssi°'~ Anchorage WELL NAME -I~t -.- 3-03/J-33 i- I~[0- 3-41/K-39 )~0~ 3-35/L-36 )- I~[ - 1-29/M-25 ~;," ~[ 3-45/M-39 L~-|~C~ 2-14/O-16 ~).- ,~ 1 - 15/P-25 '/'" '~<~ 4-08/P-27 ~-| t"l 2-12/Q-16 ~1 - 0t~ 1-63/T-22 )."It q 1-51N-20 DATE INTERVALS LOG NAME 5123/93 13400'- 13670' 5/15193 132o0'-13655' 5122193 119o0'-12264' 5~24~93 131oo'-14071' 5~20~93 29'.11848' 611193 1035o'-10578' 6~4~93 1 o350'-10800' 5114~93 1195o'-12960' 5/14~93 1195o'- 1296o' 5/17~93 11700'- 12897' 5/17/93 117o0'-12897' 5/19~93 13000'-13676' 5/27/93 10000'- 10300' 5127193 9950'- 1 o318' 5~26~93 121 o0'-12700' 5~26~93 1140o'-12200' 5115~93 113oo'-12500' 5tl 6~93 12350'-12600' 6/18~93 1235o'-12600' PFC/CCL PRODUCTION LOC-.-~ING PRODUC~ ~ING PDK - 100 PRCX:XJCTION I..(:::~.-~ING PFIODUCTION LO~ING PRODUC~ LOCKING DUAL LATEROLOG - MSFL DLL-MSFL-GR SSTVD LOG CNL/GR ~il~OR/OOk PRODUCTION LOCkiNG PRODUC~ LOCkiNG PROI:XJCTION LO~ING PFIODUCTION LOGGING GR/CCL PFC/CCL · PFC/CCL PFC/CCL RUN NO COMPANY NAME ATLAS ATLAS ATLAS ATLAS ATLAS ATLAS ATLAS SCHLLIVI~ ATLAS ATLAS ATLAS ATLAS ATLAS ATLAS ATLAS ATLAS ATLAS ATLAS 'o. ~ ~pt.o~rto~ june 1 O, 1993 Oil and GaS Conservation commission AnchOm~ ' Oemr AoGCC Represen~S~1ve' i~ed information · ~s det~ me questions- SincerelY, JLH Enclosures ~c; File 06.10 · · (he enclosed wei~ togs reg~d.,~ ~{ v u have any 564-~'~ . . NOI E1VED JUN 11 1993 Oll & Gas cons. commission BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 April 29, 1993 Alaska Oil and Gas Conservation Commission 3001 Porcupine 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, ~anfi~,-L Haas- ' OSenior Technical Assistant II JLH Enclosures xc: File 06.10 BLUELINE AND SEPIA INFORMATION TO THE STATE ENDICOTT FIELD ONLY WELL NAME DATE INTERVALS ~'~- ~"7 1-01/J-19 3/29/93 LOG NAME RUN NO 11640'-12250° PDK-100/GR/CCL COMPANY NAME ATLAS WIRELINE ~--...hl 1-55/R-25 ~.%-" t t'""/ 2-12/Q-16 ~;~,' ~ ~ 2-52/S-14 :~,- ~.\ 3-03/J-33 r-C) ~' L~L, 3-29/J-32 ~I¢ ~-['~O 3-33/K-37 ~,.~ -,.~ 3-35/L-36 8/10/91 12750'-14200' 3/19/93 9000'- 10321' 4/10/93 & 4/12/93 10000'-10301' 3/27/93 11600'- 12616' 3/19/93 13500'- 13721' 4/14/93 12300'-12670' 10/4/91 12700'-13288' 4/3/93 11550'- 12360' 4/11/93 12200'- 12270' 4/13/93 12100°- 12262' TMD SEGMENTED BOND LOG/GR/CCL PFC/CASING COLLAR LOG PRODUCTION LOGGING SERVICES PFC/CASING COLLAR LOG PFC/CASING COLLAR LOG TMD PRODUCTION LOGGING SERVICES PRODUCTION LOGGING SERVICES PFC/CASING COLLAR LOG HLS ATLAS WIRELINE ATLAS WIRELINE ATLAS WIRELINE ATLAS WIRELINE ATLAS WIRELINE HLS ATLAS WIRELINE ATLAS WIRELINE ATLAS WIRELINE RECEIVED APR 5 0 1995 Alaska 0]1 & Gas Cons, Comml~slort Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 May 15, 1992 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sirs: Enclosed please find one sepia and one blueline print for the well logs run on the following Endicott wells' WELL 3-39/J-3~9 4000-8002, ~ LEAK DETECTION v" 4/1 9/92 RUN 1 WELL 3-35/L-36 11900-12375' PRODUCTION PROFILE SCHLUMBERGER WELL 3-07/N-28 12000-133~2' JEWELRY WELL 3-0,5/0-29 11600-12500 PRODUCTION PROFILE" SCHLUMBERGER 2596/JLH/clt 5/2/92 RUN I 3/29/92 RUN I RECEIVED MAY 2 0 1992 5/1/92 RUN 1 Alaska 0il & Gas Cons. Commission Anchorage 1. Type of Request: STATE OF ALASKA ALA,.,,,A OIL AND GAS CONSERVATION COMMISSI,,)N APPLICATION FOR SUNDRY APPROVALS Abandon __ Suspend __ Operation Shutdown __ Re-enter suspended well __ Alter casing __ Repair well __ Plugging __ Time extension Stimulate X Change approved program __ Pull tubing __ Vadance __ Perforate __ Other __ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2508' SNL, 680' WEL, Sec. 8, T11N, R17E At top of productive interval 4529' SNL, 1835' WEL, Sec. 4, T11N, R17E At effective .depth 4418' SNL, 1650' WEL, Sec. 4, T11N, R17E At total depth 4386'SNL, 1620'SEL, Sec. 4, T11N, R17E 12. Present well condition summary Total depth: measured true vertical measured true vertical Length 123' 2464' 11951' Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 5. Type of Well: Development X Exploratory __ Stratigraphic __ Servi~e RECEIV£D MAR 1 1 1-992 Alaska 0il & Gas Cons. CommissiOn Anchorage 6. Datum elevation (DF or KB) KBE = 55.4 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 3-35/L-36 SD/ 9. Permit number 87-20 10. APl number 50- 029-21701 11. Field/Pool Endicott Oil Pool 12640 feet 10410 BKB feet 12548 feet 10239 BKB feet Plugs (measured) Junk (measured) 20' WD packer on bottom Size Cemented Measured de~B 30" Driven 161' 13 3/8" 3720 c.f. Permafrost Cmt 2503' 9 5/8" 575 c.f. Class G 11989' 903' 7" 315 c.f. Class G measured 12114'- 12146', 12198'- 12240', 12250'- 12300' 11737' - 12640' true vertical (Subsea) 9952'- 9976', 10016'- 10048', 10056'- 10095' Tubing (size, grade, and measured depth) 4 1/2" 12.6~/Ft. L80 TDS Tubing with 3-1/2" 9.2# tailpipe to 11807' Packers and SSSV (type and measured depth) 9 5/8" Packer at 11707'; 4 1/2" SSSV at 1566' 13. Attachments Description summary of proposal ~ Detailed operations program X BOP sketch feet 14. Estimated date for commencing operation March/April 1992 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas Service 17. I hereby....._,,certify that,, the foregoing istru~e.and,~/' ~ correct to the best of my knowledge. Signed ~'-'-~~z;:~~ J~ .)~..~,~.Y__~, Title Senior TechnicalAssistant II ~"',/' FOR COMMISSION USE ONLY Condition~-~"of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test~ Location clearance __ Mechanical Integrity Test~ Subsequent form required 10- ORIGINAL SIGNED BY Approved by order of the Commission LONN~E C. SF/IITH TrueBv/~ical depth 161' 2501' 9915' 9734'- 1O41O' Suspended~ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Welchem Scale Inhibitor Squeeze Procedure Well 3-35/L-36 PRE-TREATMENT OPERATIONS 1. Please contact Greg Berezny in Anchorage at 261-8220 to allow for Welchem personnel to come to Endicott for the treatment and flowback analysis. 2. Obtain well test at normal recommended rate prior to treatment. Ensure WC sample is taken. SCALE INHIBITOR TR[~ATMENT 1. Mix or obtain fluids as detailed on attached treatment fluids sheet. . MIRU for bullhead treatment. Pressure test lines to 3000 psi. Pump the following without exceeding frac gradient. Avoid shutting down during the treatment. Evidence indicates that even brief shut- downs of 5-10 min have an adverse affect on the treatment. a. 7 b. 446 c. 872 d. 160 e. 30 bbl Super A-Sol mutual solvent bbl WA-8851 inhibitor as 9% mixture in CaCI2 and seawater bbl seawater ovedlush bbl seawater to displace tubing bbl arctic diesel to freeze protect (tubing displaced to top perforation) Note: Filter all fluids that are to enter the perfs to 3 I~, preferably on the fly while pumping the job. 3. RDMO. Leave the well shut in for 24 hours. . POP well to test separator for 24 hrs. and arrange with Welchem to monitor returns. Pull single brine samples, for inhibitor flowback evaluation, per the following schedule. Aisc obtain a watercut sample with each inhibitor flowback sample pulled. · Every hour for the first 24 hours · Daily for the following seven days · Weekly for the following four weeks · Monthly thereafter The brine samples will be used by Weichem for inhibitor analysis. Watercut samples should be analyzed at the Endicott production lab. Mark each sample with date and time pulled. Please note on telex when the well is actually POP'd. , After the last 24 hr sample has been obtained (,,,8th day), set a DH corrosion coupon in the tubing tailpipe or sliding sleeve to monitor scale inhibitor effectiveness. Ensure that a watercut sample is pulled during the test. 6. Sample for inhibitor returns weekly thereafter. Pull the downhole coupon monthly, as operations permit, and inspect for scale deposition. DVT/2406 R£C£1¥ED Alaska Oil & Gas Cons. C0mm~ss't0~ Anchorage WELCHEM SCALE INHIBITION PROGRAM TREATMENT FLUID SUMMARY Well 3-35/L-36 WELCHEM SUPER A-SOL MUTUAL SOLVENT Volume' 7 bbls WELCHEM INHIB!TOR. WA-8851 Volume: 446 bbls DilUte 1705 gal of Welchem's inhibitor with 405 bbls of seawater in a clean stainless steel vac truck equipped with mixing paddles. Mix thoroughly. ~;EAWATER' OVERFLUSH / DISPLACE Volume- 1032 bbls Pump 872 bbls as ovedlush. Pump 160 bbls to displace tubing. Add non-ionic sudactant to seawater (not required on 160 bbl tubing displacement volume). ~;er vice Company Product Name ~Co nce ntratio n BJ NE-18 0.2% Halliburton Losud 300 0.2% Dowell/Schlumberger F-75N 0.2% ARCTIC DIESEL FREEZE PROTECTION For tUbing displacement only; mutual solvent not required. Volume: 30 bbls DVT/2406 RECEIVED it, AR 11 1392 A~aska 0il & Gas Cons, Comm[$sio'n 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 x Change approved program __ Pull tubing __ 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 6. Datum elevation (DF or KB) KBE = 55.4 feet Unit or Property name Duck Island Unit/Endicott 4. Location of well at surface 8. 2508' SNL, 680' WEL, Sec. 8, T11N, R17E At top of productive interval 4529' SNL, 1835' WEL, Sec. 4, T11N, R17E At effective depth 4418'SNL, 1650' WEL, Sec. 4, T11N, R17E At total depth 4386'SNL, 1620'SEL, Sec. 4, T11N, R17E Well number 3-35/L-36 SDI 9. Permit number 87-2O 10. APl number 50- 029-21701 11. Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured true vertical 12640 feet 10410 BKB feet Plugs (measured) Effective depth: measured true vertical 12548 feet 10239 BKB feet Junk (measured) 20' WD packer on bottom Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured d~Bh 123' 30" Driven 161' 2464' 13 3/8" 3720 c.f. Permafrost Cmt 2503' 11951' 9 5/8" 575 c.f. Class G 11989' 903' 7" 315 c.f. Class G 11737'- 12640' measured 12114'- 12146', 12198'- 12240', 12250'- 12300' true vertical (Subsea) 9952'- 9976', 10016'- 10048', 10056'- 10095' True vertical depth BKB 161' 2501' 9915' 9734'- 10410' RECEIVi Tubing (size, grade, and measured depth) 4 1/2" 12.6#/Ft. L80 TDS Tubing with 3-1/2" 9.2# tailpipe to 11807' F E Alaska Oil & Sas Cons. Packers and SSSV (type and measured depth) 9 5~8"Packer at 11707'; 4 1/2" SSSV at 1566' Anchorage 13. Attachments Description summary of proposal __ Detailed operations program X BOP sketch 14. Estimated date for commencing operation December2, 1990 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~,~.~,.~ ~ ~ Title Reservoir Development Coordinator FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity .~ BOP Test~ Location clearance __ Mechanical Integrity Test~ Subsequent form required 10- Approved Copy Retu~rned Approved by order of the Commission ~;~ ~, / Form 10-403 Rev 06/15/88 JApproval No.~:~/ Commissioner Date SUBMIT IN TRIPLICATE D 3-35/L-36 Stimulation/Bullhead EDTA PRE-TREATMENT WORK: . Coordinate with Control Room Oil Board Operator for maximum rate pro-stimulation well test (104 beans). Ensure the well has stabilized before terminating the test. . Obtain wellhead sample from the subject well. Using APl RP 42 emulsion/sludge test procedures, test for emulsion tendencies when mixing wellhead liquid sample with spent and unspent EDTA (with additives) at 210 deg F. Adjust additives as required by test results. Notes: Also obtain (if possible) 3-separate l-liter size samples of produced water from the subject well for base line water composition information. Chemistry of produced water will be required for delineation of returned fluids. 3. RIH with slick line to puli SSSV. If felt to be necessary. . Vedfy that there is no substantial communication between the tubing and inner annulus that would allow inadvertent placement of treating fluids into the annulus. TREATMENT PROCEDURE: . Block the SSV with a fusible cap and SI the well at the choke and wing valve. Note wellhead and annulus pressures on telex and prepare to monitor dudng the job. . MIRU, stimulation company, pump unit, filtering unit, and other required field equipment. . Pressure test treating lines and valves to 4500 psig. Sample acids to ensure acceptable concentration and that iron count is less than 350 ppm. Note*s: Filter all fluids that aro to enter the formation through a 3 micron nominal filtering unit, preferably on the fly while pumping the job. Do not filter Diverter. Ensure sample bottles are on location prior to pumping job in order to catch acid samples. Make certain service company can circulate tanks prior to pumping job for a uniform acid mixture. Catch acid samples after circulating tanks. Check acid strength on location with a calibrated hydrometer. , Hook up a stdp chart recorder and ensure an adequate scale will be utilized. Mark pertinent events on stdp chart to note stimulation progression. . Pump a sufficient amount of diesel down the the well (+ 20 BBLS) in order to liquid packed the wellbore. . Acidize 124' (620 holes) of Zone 3A3/3A2/2B5 perfs with Na2-H2-EDTA w/additives. Do not exceed a 0.54 psi/ft fracture gradient (-1200 psig WHP once liquid packed with water based liquids) during treatment. If these pressures aro obtained, reduce rate and/or allow acid to soak on peals as necessary to break them RECEIVED 1658/TLR/JHD FEB - 1 t991 Al.q_e&~ 1511 ~. P..~e ~nn. ~nmm|_qRiOll 3-35/L-36 Stimulation/Bullhead EDTA 2 down instead of aborting job. The rate vs. pressure chart should record wellhead pressure. Pump as follows: 1) 840 gals (20 BBLS) Diesel to compress wellbore fluids (See Step 5 above) 2) 840 gals (20 BBLS) Diesel w/10% Xylene & Mutual Solvent across perfs 3) 1300 gals (,,,31 BBLS) Na2-H2-EDTA (DJ-Sodium DJ-Hydrogen EDTA) w/additives and Diverter (1000 gals = 620 lbs = - 24 BBLS = 0.25 #/perf Diverter) - Mix On Fly or Separately 4) 11900 gals (-283 BBLS) Na2-H2-EDTA (Di-Sodium Di-Hydrogen EDTA) w/additives 5) 7476 gals (178 BBLS) Diesel to diplace tubing volume to 11707 MD. Leave EDTA in Liner 7. Shut Down pumps. 8. Leave well Shut-In for a soak period of 24hrs. POST TREATMENT WORK: 1. FLOWBACK A(;ID HANDLIN(~: It is recommended to flow back the well as follows: Line up for flow through the high flow test separator and then to the main 3-phase production train, it is believed that due to the small volume of this treatment and due to the nature of the EDTA reaction products, that facility upset will be prevented with the mutual solvent and iron reducing/complexing agents pumped with the acid system. The decision of when to divert the well out of the SDI Hi-Flow separator should be based on increasing pH as determined from wellhead flowback samples. Coordinate with and/or notify plant personnel that the well is ready for flowback. Configure flowback through the high flow test separator in order to monitor cumulative BBLS produced to facilitate "bottoms up" flowback sampling. This Well should clean up in a short pedod of time (aprox 6-8 hours) and be re- configured back to the normal production train. Notes: Capacity to top of peals: -190 BBLS As 3-35/L-36 currently produces -3000 BFPD at 42 beans, bottoms up should be anticipated within -1.5 hours from opening the master valve. Start sampling at 30 minutes based on a potential higher fiowback rate than the present 3000 BFPD. At 82 beans, 3-35/L-36 should flow approximately 6700 BFPD or require ~40 minutes for bottoms up. Once acid is at surface, gather samples over the next few hours until the well cleans up as determined from pH and water cut. Puli and retain one additional sample at the very end of the flowback. , Coordinate flowback sampling needs and analysis with Chemlink. Ensure a sufficient number of samples are obtained throughout the clean-up pedod of the flowback. Also submit 3-separate one-liter size samples of backflowed acid to the stimulation company's lab for an independent analysis of the following: A. 1658/TLR/J H D Amount, Size, and type of returned solids Strength of returned acid (pH determination and Fluid color) Total Iron content, Badum, and Calcium. RECEIVED FEB - 1 1991 ~laska 0il & Gas Cons. ,G(;l~ Anchorag 3-35/L-36 Stimulation/Bullhead EDTA 3~ . D. Presence of Emulsions (Stable or Unstable) Formation of any precipitates (Total Suspended Solids) Coordinate with control Room Oil Board Operator to obtain maximum rate well test after treatment. Note; Ensure the well is returned to production at the same choke setting as used during the pre-stimulation well test (104 beans). Also ensure the well has sufficiently stabilized pdor to commissioning the post-stimulation well test. RU slickline unit and set SSSV. Return well to allocated rate production ASAP. 1658/TLR/J H D RECEIVED FEB - 1 t99! Alaska Oil & Gas Cons. Commission Anchorage 3-35/L-36 S timul'ation/Bullhead EDTA 3-35/L-36 SUMMARY OF TREATMENT FL, UIDS Fluid Treatment Volume a_al/ft ~ Diesel NA 840 Diesel 6.8 840 EDTA 100.0 12400 Diverter 8.06 1000 EDTA NA 8 05 Diesel 10.2 7476 Additives (20 BBL Liquid Pack) No Additives (20 BBL Pre-Flush) 10% Xylene (295 BBL Treatment Fluid) AS LISTED BELOW ACCORDING TO APl RP 42 TESTING (24 BBL carryer fluid) 2% NH4Ci, 3g surfactant, 620# Diverter as outlined below according to vendor (19.2 BBL Treatment Fluid) AS LISTED BELOW ACCORDING TO AP! RP 42 TESTING, Liner wash (178 BBL to displace tubing volume) No Additives Halliburton EDTA; Inhibitor: Surfactant: Anti-sludge: Diverter Mutual Solvent: MSA @ 2 g/mg Losurf 300 @ 2-5g/mg as per emulsion test AS-5 @ 2-12g/mg as per sludge test 100 gals SmalI-Matdseal "0" and 220 lbs Large - OSR - 100 5% MusoI-A Dowell EDTA: Inhibitor: Anti-sludge: Non-emulsifier: Sudactant: Diverter: Mutual Solvent: BJ Tiian EDTA; Inhibitor Surfactant: Non-emulsifier: Diverter: Mutual Solvent: A-186 @ 2 g/mg W-35 @ 3-10g/mg as per sludge test W-54 @ 0-10g/mg as per emulsion test F-75N @ 2g/mg 100 gals Small - J237 and 220 lbs Large - J168 10% U-66 Ci-9 @ 2 g/mg N E-18 @ 4g/mg Inflow-45 @ 2-10g/mg as per emulsion test 620 lbs Divert 1 5% MS-10 EDTA Preparation 314 BBLS of fresh water at a temp of 100o F or greater with 32.6 #/BBL of Na2-H2-EDTA added. Titrate solution for the correct concentration. Do not use more than 36.0 #/BBL of Na2-H2-EDTA regardless of titration. Ph should be 4,0-5.0. Report value on telex. Add other chemicals after EDTA. 1658/TLR/JHD RECEIVED FEB - 1 t991 Alaska 0ii & Gas Cons. Commission Anchorage RE~.EIVED ~ll~l~ Oil & aas ~as. ~.o~nit. tiss'ton BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P,O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 January 30, 1991 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Endicott Well 3-35/L-36 SDI Dear Sirs: Enclosed please find Form 10-403 and 10-404 for the subject well. Form 10-403 was inadvertently overlooked and not filed with the State prior to operations. The stimulation was performed on December 2, 1990. We apologize for this mistake and are taking action to prevent this from occuring in the future. Sincerely, Herman L. Hellman HLH/WRB/jlh Enclosures cc: File 76.10 1806/JLH STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Perforate Pull tubing Alter casing Repair well Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2508' SNL, 680' WEL, Sec. 8, T11N, R17E At top of productive interval 4529' SNL, 1835' WEL, Sec. 4, T11N, R17E At effective depth 4418' SNL, 1650' WEL, Sec. 4, T11N, R17E At total depth 4386'SNL, 1620'SEL, Sec. 4, T11N, R17E 5. Type of Well: Development X Exploratory Stratigraphic Service RECEIVED FEB - 1 t991 Alaska 0ii & Gas Cons. commtsstoa Nir, l~orage 6. Datum elevation (DF or KB) KBE = 55.4 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 3-35/L-36 SDI 9. Permit number/approval number e7-20//¢'/"-' ~.--~ 10. APl number 5O- 029-21701 11. Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 12640 feet 1041O BKB feet 12548 feet 1O239 BKB feet Plugs (measured) Junk (measured) 20' WD packer on bottom Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth BKB 123' 30" Driven 161' 2464' 13 3/8" 3720 c.f. Permafrost 2503' 11951' 9 5/8" 575 c.f. Class G 11989' 903' 7" 315 c.f. Class G 11737' - 12640' measured 12114'- 12146', 12198'- 12240', 12250'- 12300' True ve~i~ depth 161' 2501' 9915' 9734'- 10410' true vertical (Subsea) 9952'- 9976', 10016'- 10048', 10056'- 10095' Tubing (size, grade, and measured depth) 4 1/2" 12.6~/Ft. L80 TDS Tubing with 3-1/2"9.2# tailpipe to 11807' Packers and SSSV (type and measured depth) 9 5/8" Packer at 11707'; 4 1/2" SSSV at 1566' 13. Stimulation or cement squeeze summary EDTA perf wash Intervals treated (measured) 12114'-12146', 12198'-12240', 12250'-12300' Treatment description including volumes used and final pressure 314 barrels Na2-H2-ED TA, 24 barrels diverter and 218 barrels diesel. WHSIP = 1300 psig. 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection I~ata Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure 6388 4421 1597 0 6780 4469 1488 0 Tubing Pressure 551 561 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. Form 10-404 Rev 06/15/88 ' "- - SUBMIT IN DOP(IC/(TE WELL 2~36/O-14 COLLAR LOG 10100'-10350' HRS WELL 2-42/P-13 DUAL STATIC 0-11783' SCHLUMBERGER WELL 2-46/Q-15 PRODUCTION LOG 10500'-11100' SCHLUMBERGER WELL 2-58/S-09 PRODUCTION LOG 155'-14313' SCHLUMBERGER WELL 2-64/U-10 PERF 13800'-14180' SCHLUMBERGER WELL 2-70/U-15 INJ/TEMP 11350'-12000' WELL 3-35/L-36 PRODUCTION LOG 11950'-12350' CASING/TUBING CALIPER SURF-12370' PRODUCTION LOG 11950'-12350' WELL 4-08/P-27 WOPITS 13100'-13550' 10/4/90 RUN ONE I 1/8/90 RUN ONE 1 1/21/90 RUN ONE 1 1/7/90 RUN ONE 1 2/1 7/90 RUN ONE 1 1/1 7/90 RUN ONE 12/1/90 RUN ONE 12/1/90 RUNTWO 12/6/90 RUN ONE 1 1/20/90 RUN ONE RECEIVED JAN ? 1991 Alaska Oil & Gas Cons. Commission Ancho[age *GAMMA RAY SURVEY 11600' - 12350' Camco 6/25/90 Run No. 1 *PRODUCTION PROFILE 6/28/90 11700' - 12350' Run No. 1 Camco WELL 3-! 1/M-30, 6/29/90 *DUAL BURST TDT LOG (TDT-P) 12675' - 13395 Run No. 1 Schlumberger WELL 3-21/L-34 7/2/90 *DUAL BURST TDT LOG (TDT-P) 12290' - 12834' Run No 1 Schlumberger WELL 3-27/M-33 5/19/9..0.. *DUAL BURST TDT LOG (TDT-P) 11500' - 12070' Run No. 1 Schlumberger *WATER FLOW LOG SERVICE (TDT-P) 11500' - 12070' Run No. 1 Schlumberger " WELL 3-35/L-36 7/1/90 *DUAL BURST TDT LOG (TDT-P) 11980' - 12390' Run No. 1 Schlumberger *WATER FLOW LOG SERVICE (TDT-P) 11980' - 12390' Run No. 1 Schlumberger WELL 3-41/K-39 *TEMPERATURE LOG 12900' - 13650' Camco 5/7-8/90 Run No. 1 *INJECTION PROFILE TEMP WARM BACK 13200' - 13669' Run No. 1 Camco WELL 4-04/T-26 *RADIO ACTIVE TRACER LOG 13530' - 14027' Run No. 1 Schlumberger 5/19/90 7/1/90 6/12-13/90 R[ CEIVED ALIG -' 2 19B0 Alaska 0il & Gas Cons. Commissio[~ A.chorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 February 13, 1990 Mr. C. V. Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Endicott Field Well 3-35/L-36 Gentlemen' Enclosed in duplicate is Form 10-404, Report of Sundry Well Operations, for the above named well. We stimulated this well on October 25, 1989. Please contact Quinn Meads at 564-5880 if any additional information is required. Sincerely, H. L. Hellman Reservoir Development Coordinator HLH/~~slk Enclosures x¢: W. R. Blosser J. H. Dupree J. L. Haas S. L. Harvey R. Q. Meads Well File Working Interest Owners File 76.10 232JLH STATE OF ALASKA A~_,-,$KA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Pull tubing Alter casing Repair well Perforate 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 2508' SNL, 680' WEL, Sec. 8, T11N, R17E At top of productive interval 4529' SNL, 1835' WEL, Sec. 4, T11N, R17E At effective depth 4418' SNL, 1650' WEL, Sec. 4, T11N, R17E At total depth 4386'SNL, 1620'SEL, Sec. 4, T11N, R17E 12. Present well condition summary Total depth: measured true vertical 12640feet 10410 BKBfeet 5. Type of Well: Development X Exploratory Stratigraphic Service Plugs (measured) 6. Datum elevation (DF or KB) KBE = 55.4 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 3-35/L-36 SDI 9. Permit number/approval number 87-20/9-021 10. APl number 50- 029-21701 11. Field/Pool Endicott Oil Pool Effective depth: measured true vertical 12548feet 10239 BKBfeet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth BKB BKB 123' 30" Driven 161' 161' 2464' 13 3/8" 3720 c.f. Permafrost 2503' 2501' 11951' 9 5/8" 575c. f. Class G 11989' 9915' 903' 7" 315 c.f. C/ass G 11737' - 12640' measured 12114'- 12146', 12198'- 12240', 12250'- 12300' 9734'- 1041O' true vertical (Subsea) 9952'- 9976', 10016'- 10048', 10056'- 10095' Tubing (size, grade, and measured depth) 4 1/2" 12.6#/Ft. LBO TDS Tubing to 11674'; 3 1/2" 9.2#~Ft. LBO TDS with 2 7/8" Tailpipe to 12188' Packers and SSSV (type and measured depth) 9 5/8" Packer at 11690'; 7" Packer at 12169'; 4 1/2" SSSV at 1549' i 13. Stimu,ation or cement squeeze summary See a,tachment Intervals treated (measured) Treatment description including volumes used and final pressure Gas Cons. C0m~ 'Art ~h n 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 4350 2776 565 0 5210 3371 848 0 Tubing Pressure 568 728 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service Production Signed ~#)'~/'/~'~~~,",.~'~ Title Reservoir Development Coordinator Form 10-404 Rev 06~'15~18 Date~//~'/q ~ SUBMIT IN D"UP(_ICATE ENDICOTT FIELD PRODUCTION ENGINEERING DEPARTMENT BRITISH PETROLEUM EXPLORATION OPERATIONS REPORT DATE: 1 0/25-26/89 WELL N~: 3-35/L-36 TYPE OF OPERATION: MUD ACID TREATMENT BP EXPLORATION REP: ALLAN/MACDONALD/HOFFMAN/VIGIL SERVICE COMPANY: HALLIBURTON/ACT I[' DATE/~IME I OPERATIONS SUMMARY 10/25/89 0700 SHUT IN WELL AT WING AND CHOKE. I 1 00 RIG UP 2.5~ SWIRL PATTERN NOZZLE TO coIL WITH DUAL CHECK VALVES AND TUBING TAILPIPE LOCATOR. RIG UP ACT INJECTOR HEAD BY FLANGE TO TREE. RIG UP HARD LINE. FILL CTU WITH DIESEL. TEST LINES, COIL, WELLHEAD CONNECTIONS AND BOPS TO 4000 PSI. SIWHP=1300 lAP=0 OAP=0 ,., 1 I 1 5 CIRCULATE AcID TRANSPORTS. SAMPLE ALL FLUID cOMPARTMENTS. 1 43 0 SAFETY MEETING AND JOB OVERVIEW. 1 43 0 ZERO FOOTAGE COUNTER AT SWAB VALVE +39' INSURE THE CTU CHART RECORDER IS OPERATING PROPERLY. ~ 44 5 PUMPED 50 BBLS OF DIESEL TO FLUID PACK TUBING. 1 500 RIH WITH CTU. 1 72 2 TIED INTO THE TUBING TAILPIPE AND CORRECTED ODOMETER +8 FEET. 1730 RIHTO 12114'. 1 73 0 BEGAN TO PUMP TREATMENT AT A PUMP RATE NOT TO EXCEED 2300 PSI WELLHEAD PRESSURE. ONCE INITIAL STAGE OF TREATMENT BEGAN TO DISCHARGE OUT OF NOZZLE, BEGAN TO RECIPROCATE CTU ACROSS THE PERFORATED INTERVAL 12114-12300' AT 20-25 FPM. NOTED ON pUMP CHART WHEN DIFFERENT STAGES DISCHARGE oUT OF THE COIL NOZZLE. HIGHLIGHTED STAGES DIFFER FROM PROGRAM. P Q TREATMENT STAGES: 1 730 4000 1.36 STAGE1 11.3 BBLS DIESEL WITH 25 GALS SS-8660 , 1 738 3960 1.37 STAGE2 11.3 BBLS 6% NH4CL WITH 25 GALS SS-8660 1 746 3860 1.38 STAGE3 10 BBLS 6% GELLED NH4CL WITH 10 GALS OSR AND 17 LBS OSR. 1 754 3885 1.46 STAGE 4 11.9 BBLS 7.5 % HCL WITH CORROSION INHIBITOR, NONEMULSIFYING AGENTS AND IRON REDUCER. , i 801 4000 2 00 STAGE5 23.8 BBLS 6:1.5% HCL:HF wITH 0.2% LS 259, 45ff/1000 FERRCHECK, 45#/1000 CITRIC ACID 1812 3700 2.55 STAGE6 29.8BBLs6% NH4CL 1 828 3700 1.50 STAGE 7 6.0 BBLS 6% GELLED NH4CL WITH 6 GALS OSR AND 10 LBS OSR 1 832 ~3520 i .40 STAGE8 23.8 BBLS 7.5% HCL WITH STAGE 4 ADDITIVES 1 847 3990 1.55 STAGE9 47.6 BBLS 6:1.5% HCL:HF WITH STAGE 5 ADDITIVES 1909 3850 2.55 STAGE 10 59.5 BBLs NH4CL 1 935 3750 2.42 STAGE 1i 11.9 BBLS 6% GELLED NH4CL WITH 12 GALS OSR AND 21 LBS OSR i939 3885 2.33 STAGE12 35.7BBLST.5%HCL WITHSTAGE4 ADDITIVES i 956 ' 1 500 0.29 STAGE 13 71.4 BBLS 6:1.5% HCL:HF wITH STAGE 5 ADDITIVES 2040 3800 1.50 STAGE 14 95.2 BBLS NH4CL DATE: 9/3-4/89 WELL N=: 2-68/S-17 TYPE OF OPERATION: MUD ACID TREATMENT 2146 3780 1.50 STAGE 15 23.8 BBLS 6% GELLED NH4CL WITH 12GALS 2202 1 900 0.50 STAGE 16 47.6 BBLS 7.5% HCL WITH STAGE 4 ADDITIVES 2349 1300 0.40 STAGE 17 95.2 BBLS 6:1.5% HCL:HF wITH STAGE 5 ADDITIVES 1 0-26 89 0058 3670 2.20 STAGE 18 47.6 BBLS 6% NH4CL 0124 4000 1.80 STAGE 19 47.6 BBLS 6% NH4CL WITH i00 GALS SS-8660 0153 RUN CTU TO 12300' MD. SQUEEZE FOLLOWING TREATMENT AWAY WHi'Li~ RECIPROCATING ACROSS PERFS. 12114'-12300' MD. 0153 3900 11.53 lsTAGE 2o 80 BBLS DiESEL WITH125 GALS SS-8660 0 i 5 7 DIESEL HEADER FROZEN. ATTEMPT TO THAW. CALL oUT NEW TRUCK. 0 4 3 3 RESUME PUMPING STAGE 20 0 61 3 POH. RIG DOwN ACID TRUCKS. 0 7 4 5 NOTIFIED pRODUCTION SUPERVISOR AND OIL BOARD OF THE POTENTIAL FOR THE PRESENCE OF UVE ACID IN THE FLOWBACK STREAM. ,, , 0 7 4 5 PUT WELL ON PRODUCTION THROUGH HIGH FLOW SEPARATOR AND MONITOR FLOW. STABILIZED FLOW AT 3600 BOPD TO MINIMIZE TURBULENCE AND TO ASSURE REPRESENTATIVE SAMPLES. GRABBED SAMPLES EVERY 30 MINUTES FOR FLOWBACK ANALYSIS FOR 1200 BBLS OF RETURN FLUID. 14 3 0 RD coILED TUBING 1 600 Q=3800 BPD WHP=838 CUM--1050 BBL , OBTAINED THE FOLLOWING: PRETREATMENT FLUID SAMPLES CHART RECORDINGS LOAD our SHEET ' ~:LOWBACI~ ~AMPLI=S SUMMARY OF TREATMENT FLUIDS PUMPED: 119 BBLS 7.5% HCL 238 BBLS 6:1.5% HCL:HF 232 BBLS 6% NH4CL 51.6 BBLS GELLED NH4CL WITH OSR DIVERTERS 59.5 BBLS SPACER 6% NH4CL WITH MUTUAL SOLVENT 94.9 BBLS DIESEL WITH MUTUAL SOLVENT BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 · Anchorage, Alaska 99519-6612 (907) 561-5111 December 19, 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' ~-22/L-14 1 0/23/89 2-52/S-14 11/24/89 3-05/0-29 1 1/27/89 3-1 l/M-30 10/28/89 3-35/L-36 1 1/1 1/89 4-14/R-34 10/22/89 5-03/SAG 9 11/24/89 5-03/SAG 9 11/25/89 If there are any questions regarding this data, please contact Dave MacDonald at 564-4697. RECEIVED DEC 2 ]. 1989 Alaska 0il & Gas Cons. commissiO~ Anchorage WELL 1-43/P-26 *TEMPERATURE SURVEY 12900' - 14290' Run No. 1 CAMCO WELL 1-05/O-20 *COLLAR LOG 10312' - 10670' Run No. 1 ATLAS WIRLELINE SERVICES WELL 2-34/P-14 MPI *TEMPERATURE LOG 10450' - 10950' CAMCO Run No. 1 WI~L,I,, 3-35/L-36 SDI *PRODUCTION PROFILE 12000' - 12350' CAMCO Run No. 1 WELL 2-34/P-14 MPI *TEMPERATURE LOG 10450' - 10950' CAMCO Run No. 1 Sincerely, Lynoa M. Stamper LMS cc: File 06.10 BP EXPLORATION October 11, 1989 BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 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 cased hole well logs run in the following Endicott wells: WELL 4-28/N-37 *PRODUCTION PROFILE Logged 9/13/89 Run 1 WELL 4-50/K-41 *PRODUCTION PROFILE Logged 9/6/89 Run 1 WELL 2-42/P- 13 *PRODUCTION PROFILE Logged 9/11/89 Run 1 WELL 3-17/J-30 *PRODUCTION PROFILE Logged 9/4/89 Run 1 WELL 3-47/Q-35 *PRODUCTION PROFILE PRODUCTION PROFILE SURVEY GND/Ims ~ BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. 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 Alaslca0il & Gommt lQO Cons. ' Ancnomg8 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ,,, ~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging . Perforate Pull tubing X. Alter casing Repair well X Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2508' SNL, 680' WEL, SEC. 8, T11N, R17E At top of productive interval 4529' SNL, 1835' WEL, SEC. 4, T11N, R17E At effective depth 4418' SNL, 1650' WEL, SEC. 4, T11N, R 17E At total depth 4386' SNL, 1620' WEL, SEC. 4, T11N, R 17E 5. Type of Well: Development X Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) 55.40 KBE feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 3-35/L-36 SDI 9. Permit number/approval number 87-2O/9-157 10. APl number 50- 029-21701 11. Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 12640' feet Plugs (measured) 10410' feet BKB 12548' feet Junk (measured) 10239' feet BKB Casing Length Size Cemented Structural Conductor 123' 30" Drive Pipe S u trace 2464' 13-3/8" 3720 cuft Permafrost Intermediate 11950' 9-5/8" 575 cu ft Class G Production ......... Liner 903' 7" 315 cu fl Class G Perforation depth: measured 12114'-12146'; 12198'-12240'; 12250'-12300' 20' WD Packer above PBTD @ 12548' Measured depth True vertical depth BKB BKB 161' 161' 25O3' 2503' 11988' 9914' 11737'- 12640' 9733'- 10410' true vertical (subsea) 9952'-9976'; 10016'-10048'; 10056'-10095' Tubing (size, grade, and measured depth) 4-1/2" 12.6#~ltL-80 TDS to 11707'; 3-1/2" 9.2#/ft L-80 TDS to 11807' Packers and SSSV (typo and measured depth)9-5/8"TIW@11707';4-1/2"SSSV@1566' ~..~!~V~.E 13. Stimulation or cement squeeze summary Intervals treated (measured), Treatment description including volumes used and final pressure Oil & Gas Cons. C0mmis.s~ Alasl~ai~!l,,&,/~bt~a~~ ,>,:-,,n~ss~o - ~nchorar..j6 14. Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run_ Daily Report of Well Operations X 3003 1584 0 0 psig 3326 2193 297 0 psig I16. Status of well classification as: Oil X Gas Suspended 897 psig 827 psig Service 17. I hereby certify t.hat the foregoing is.true and correct to the best of my knowledge. Signed ~~.,~~ TitleCompletionEn~ineerin~Supervisor Form 10-404 Rev 06/15/~ - - ' SUBMIT IN DUPLICATE WELL 3-35/L~36 WORKOVER ATTACHMENT I Procedure Outline: · · 4. 5. 6. 7. e 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. MIRU rig. Accepted rig @ 1800 hrs on 3/11/89. Pulled BPV. Weight brine up to 10.7 ppg and circulated - killed well. Set 2-way check valve. ND tree. NU & tested BOP's to 5000 psi. Pulled 4-1/2" tubing. RIH and recovered slick stick from 9-5/8" packer. Recovered 9-5/8" TIW retrievable packer and 3-1/2" tailpipe assembly. RIH w/ overshot dressed 3-3/8". Latched on to 3-1/2" fish. Recovered 3-1/2" pup joint, and latch assembly. Milled on 7" packer at 12159' to 12397'. RIH w/ 9-5/8" casing scraper to 7" liner top @ 11737'. RIH w/7" casing scraper to 12366'. RIH with 7" RTTS. Tested 9-5/8" casing & 7" liner lap to 2500 psi-ok. Ran 4-1/2" tubing and landed same. Set 2-way check valve. ND BOP's. NU & tested tree to 5000 psi. RIH with wireline and set plug in 3-1/2" tailpipe. Set 9-5/8" permanent packer. Pressure tested tubing X annulus - ok. Opened sliding sleeve and displaced the 9-5/8" x 4-1/2" annulus with 9.8 ppg brine + 35 bbls diesel and displaced tubing with diesel. Closed and tested sliding sleeve. Set BPV. ReleaSed rig @1900 hrs on 3/26/89. Alaska 0ii & Gas Cons. commission Anch0raga BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 17t3612 Anchorage, Alaska 99519-6612 (907) 561-5111 June 7, 1989 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 Attention' Mr. C. V. Chatterton Gentlemen' Well 3-35/L-36 SDI (Endicott) Enclosed, in duplicate, is form 10-404, Report of Sundry Well Operations, for the above-named well. This contains our subsequent report of pulling tubing and repairing the well. Yours very truly, Workover/Completions Supervisor RVS/KTH Enclosures (3) cc' J. Oldenburg (MB7;1) Endicott Wl©'s w/4 Endicott Production.. Engineers Mark Grindle (MB ~5'3) Well File RECEIVED IUN o 9 .989 Alaska 011 & Gas Cons. Commission Anchorage. STATE OF ALASKA A~..SKA OIL AND GAS CONSERVATION COMMIb,.,ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown__ Stimulate Plugging Pull tubing X Alter casing Repair well X Perforate__ Other 2. Name of Operator BP Exploration (Alaska) inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2508'SNL, 680' WEL, SEC. 8, T11N, R17E At top of productive interval 4529' SNL, 1835' WEL, SEC. 4, T11N, R17E At effective depth 4418' SNL, 1650' WEL, SEC. 4, T11N, R17E At total depth 4386' SNL, 1620' WEL, SEC. 4, T11N, R17E 5. Type of Well: Development X Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) 55.40 KBE feet 7. Unit or Property name Duck Is/and Unit/Endicott 8. Well number 3-35/L-36 SDI 9. Permit number/approval number 8 7-2O/9-157 10. APl number 50- O29-217O 1 11. Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 12640' feet Plugs (measured) 10410' feet BKB 12548' feet Junk (measured) 10239' feet BKB Casing Length Size Cemented Structural Conductor 123' 30" Drive Pipe Surface 2464' 13-3/8" 3720 cuft Permafrost Intermediate 11950' 9-5/8" 575 cu fl Class G Production ......... Liner 903' 7" 315 cu ft Class G Perforation depth: measured 12114'-12146'; 12198'-12240'; 12250'-12300' 20' WD Packer above PBTD @ 12548' Measured depth True vertical depth BKB BKB 161' 161' 2503' 25O3' 11988' 9914' 11737'- 12640' 9733'- 10410' true vertical (subsea) 9952'-9976'; 10016'-10048'; 10056'-10095' Tubing (size. grade, and measured depth) 4-1/2" 12.6#/ft L-80 TDS to 11707'; 3-1/2" 9.2#/ft L-80 TDS to 11807' Packers and SSSV (type and measured depth) 9-5/8" TIW @ 117077 4-1/2" SSSV @ 1566' RECEIVED 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure JUN o 1989 Alaska 011 & Gas Cons. Commission Anchorage 14. Prior to well operation Subsequent to operation Reoresentative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 3003 1584 0 0 psig 3326 2193 297 0 psig Tubing Pressure 897 psig 827 psig 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil × Gas Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Completion En~/ineering Supervisor Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE WELL 3-35/L-36 WORKOVER ATTACHMENT I Procedure Outline' · · 4. 5. 6. 7. · 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. MIRU rig. Accepted rig @ 1800 hrs on 3/11/89· Pulled BPV. Weight brine up to 10.7 ppg and circulated - killed well. Set 2-way check valve. ND tree. NU & tested BOP's to 5000 psi. Pulled 4-1/2" tubing. RIH and recovered slick stick from 9-5/8" packer. Recovered 9-5/8" TIW retrievable packer and 3-1/2" tailpipe assembly. RIH w/ overshot dressed 3-3/8". Latched on to 3-1/2" fish. Recovered 3-1/2" pup joint, and latch assembly. Milled on 7" packer at 12159' to 12397'. RIH w/ 9-5/8" casing scraper to 7" liner top @ 11737'. RIH w/7" casing scraper to 12366'. RIH with 7" RTTS. Tested 9-5/8" casing & 7" liner lap to 2500 psi-ok. Ran 4-1/2" tubing and landed same. Set 2-way check valve. ND BOP's. NU & tested tree to 5000 psi. RIH with wireline and set plug in 3-1/2" tailpipe. Set 9-5/8" permanent packer. Pressure tested tubing X annulus - ok. Opened sliding sleeve and displaced the 9-5/8" x 4-1/2" annulus with 9.8 ppg brine + 35 bbls diesel and displaced tubing with diesel. Closed and tested sliding sleeve. Set BPV. Released rig @1900 hrs on 3/26/89. RECEIVED ~IJN o 91989 Alaska 011 & Gas Cons. Commission Anchorage BP E~I. ORATION Daily Drilling Report -- ENDICOTT -- Workover March 13, 1989 at 0600 hrs Rig: POOL 7 Well: 3-35/L-36 (SDI) AFE # 176202 AFE Amount: Current Amount: 0600 Depth: 0 Day: 2 Current Operation: Weighting-up b.rine. Move rig to Well 3-35. Accept rig @ 1800 hrs. on 3/11/89. Rig-up to kill well. Attempt to kill well; no success. Shut-in well. Weight-up brine to 10.3 ppg. RECEIVED ~JUN o ~ l~g Alaska 011 h Gas Cons. Commlssk)n Anchorage Bi~ EXi~.OR~;~ON Daily Drilling Report -- ENDICOTT -- Workover March 14, 1989 at 0600 hrs .{ig: POOL 7 Nell: 3-35/L-36 (SDI) AFE # 176202 AFE Amount: Current Amount: 0600 Depth: 0 Day: 3 Zurrent Operation: Spotting an 11 ppg salt pill. Weight brine up to 10.3 ppg. Attempt to kill well; no success. Weight brine up to 10.5 ppg and circulate. Monitor well. Mix bridge-sal salt pill. BP EXPLOR~N Daily Drilling Report -- ENDICOTT -- Workover March 15, 1989 at 0600 hrs Rig: POOL 7 Well: 3-35/L-36 (SDI) AFE # 176202 AFE Amount: Current Amount: 0600 Depth: 12548' PBTD Day: 4 Current Operation: PuRing and laying down 4-1/2" robing. Spot salt pill. Weight brine up to 10.7 ppg and circulate. Killed well. Nipple down tree. N/U BOP and test to 5000 psi. Pulled tubing hanger. RECEIVED JUN o 9 Alaska Oil & Gas Cons. Commission Anchorage' BP E~G~ORAT~N Daily Drilling Report -- ENDICOTT -- Workover March 16, 1989 at 0600 hrs Rig: POOL 7 Well: 3-35/L-36 (SDI) AFE # 176202 AFE Amount: Current Amount: 0600 Depth: 12548' Day: 5 Current Operation: POH and lay down packer and tailpipe. Lay down 4-1/2" tubing. RIH with overshot. Retrieve slick stick from 9-5/8" packer. RIH with TIW packer retrieving tool. Pull packer free and lay down same. RECEIVED JUN o 9 Alaska Oil & Gas Cons. Commission Anchorage BP Daily Drilling Report -- ENDICOTT -- Workover March 17, 1989 at 0600 hrs .~ig: POOL 7 Nell: 3-35/L-36 (SDI) AFE # 176202 AFE Amount: Current Amount: 0600 Depth: 12157' Day: 6 2urrent Operation: Circulating. Lay down 3-1/2" tailpipe assembly. RIH with overshot dressed 3-1/2" to fish anchor. POH - no fish. RIH with overshot dressed 3-3/8". Latch on to fish. POH to 7" liner top. Circulate. t EC EIVED .4/aska Oil & ~as Cons. Commission Anchorage BP EXPI,.OR.~TION Daily Drilling Report -- ENDICOTT -- Workover March 20, 1989 at 0600 hrs Rig: POOL 7 Well: 3-35/L-36 (SDI) AFE # 176202 AFE Amount: Current Amount: 0600 Depth: 12548' Day: 9 Current Operation: Trip in hole with mill. Recovered 3-1/2" pup joint and latch assembly. Mill on 7" packer at 12159'. Change out mill. Mill on 7" packer. Change out mill. Mill on 7" packer. Change out mill. Mill on 7" packer. Change out mills. RIH with mill #5. RECEIVED 41aska Oil & Gas Cons. Cor~rnisslon Anchorage IBP EXPLORATION Rig: POOL 7 Well: 3-35/L-36 (SDI) Daily Drilling Report-- ENDICOTT -- Workover March 21, 1989 at 0600 hrs AFE # 176202 AFE Amount: Current Amount: 0600 Depth: 12548' Day: 10 Current Operation: Pull out of hole. RII-I with mill #5. Mill on packer. Spot bridge-sal pill. Change out mills. R/ti with mill #6. Mill on packer. POH. BP E;XP[ORATION Daily Drilling Report -- ENDICOTT -- Workover March 22, 1989 at 0600 hrs Rig: POOL 7 Well: 3-35/L-36 (SDI) AFE # 176202 AFE Amount: Current Amount: 0600 Depth: 12548' PBTD Day: 11 Current Operation: Milling on 7" packer. POH. RIH with fiat bottom mill. Mill on packer. RECEIVED :JUN o 9 IBSg Alaska 011 & Gas Cons. Commission tmchorage BP EXPLOR~N Daily Drilling Report-- ENDICOTT-- Workover March 23, 1989 at 0600 hrs Rig: POOL 7 Well: 3-35/L-36 (SDI) AFE # 176202 AFE Amount: Current Amount: 0600 Depth: 12548' Day: 12 Current Operation: Milling on 7" packer. Mill through 7" packer at 12160'. Push packer down to 12395', packer hung up. Mill on packer at 12395'. Spot Bridge-Sal pill and POH. Change out mill. RIH, found junk at 12386'. Wash down to top of packer. Mill on 7" packer at 12397'. BP ~t:~..ORAT~N Daily Drilling Report -- ENDICOTT -- Workover March 27, 1989 at 0600 hfs Rig: POOL 7 Well: 3-35/L-36 (SDI) AFE # 176202 AFE Amount: Current Amount: 0600 Depth: 12548' PBTD Day: 16 Current Operation: Moved rig to 4-14. Mill on 7" packer at 12397'. POH. RIH with 9-5/8" casing scraper to 7" liner top at 11737'. POH. RIH with 7" casing scraper to 12366. POH. RIH with 7" RTTS. Test 7" liner lap and 9-5/8" casing to 2500 psi. - OK. POH. RII-I with 4-1/2" tubing and land same. ND BOP's and NU and test tree to 5000 psi. RU slickline and set plug in tailpipe. Set 9-5/8" packer and test 9-5/8" X 4-1/2" annulus - OK. Displace annulus to treated 9.8 ppg brine and displace tubing to diesel. Install BPV. Release rig at 1900 hrs. on 3-26-89. BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 March 8, 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, 2;16/M-16 *TEMPERATURE LOG 10900'- 11464' Run No. 1 .WELL 3-45/M-39 *POST INJECTION TEMPERATURE LOG 12200' 12690'. Run No. 1 *INJECTION PROFILE LOG 12300'- 12690' Run No. 1 'WELL 3-33/K-37 *FLOWMETER LOG 12667'- 13109' Run No. 1 WELL 2-42/P-13 *TEMPERATURE LOG 11300' - 12268' Run No. 1 *PACKER LEAK TEMPERATURE LOG 11500'- 12174' Run No. 1 Logged By CAMCO Alaska 0ii & Gas Cons. Commission Anct~orage Sincerely, BP EXPLORATION BP E×PI°rati°n (,Alaska} thC. 900 East Benson Boulevard p,O. Box 196612 Anchorage, A~aska 99519-6612 (,907) 561-5111 FebrUarY 24, 1989 AlaSka Oil & GaS conservation commission 3001 porcupine Dr. Anchorage, AlaSka 99501 Attention: Mr. C.V. Chatterton sundry Gentlemen' . 10-403, APplication for Enclosed, in triplica.te, ~..~emd weft. This contains our Approvals, for the ao°ve'"~"~epair the well. propoSa~ to purl tubing and Yours very trut¥, R. ~/- SchoCk supervisOr Wotkover/C°mp~eti°ns RVS/KTH Enclosures cc: j. Bragg (MB9-4~ RECEIVED .Oil .& Gas Gons..C0mlzl!sSj~ ...... ~ ~chorag~" 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 X 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 4. Location of well at surface 2508' SNL, 680' WEL, SEC. 8, T11N, R17E At top of productive interval 4529' SNL, 1835' WEL, SEC. 4, T11N, R17E At effective depth 4418' SNL, 1650' WEL, SEC. 4, T11N, R17E At total depth 4386' SNL, 1620' WEL, SEC. 4, T11N, R17E 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 12640' feet 10410' feet BKB 5. Type of Well: Development X Exploratory Stratigraphic Service Plugs (measured) 12548' feet Junk (measured) 10239' feet BKB Length Size Cemented 123' 30" Drive Pipe 2464' 13-3/8" 3720 cuft Permafrost 11950' 9-5/8" 575 cu ft Class G 903' 7" 315 cu ft Class G Datum elevation (DF or KB) 55.40 KBE feet Unit or Property name Duck Island Unit/Endicott 8. Well number 3-35/L-36 SDI 9. Permit number 87-2O 10. APl number 50- O29-21701 11. Field/Pool Endicott Oil Pool RECEIVED .;~laska,,0il & Gas Cons, Commission Measured depth''''%1.;~ ~[li~rtiCai depth BKB BKB 161' 161' 2503' 2503' 11988' 9914' 11737'- 12640' 9733'- 10410' measured 12114'-12146'; 12198'-12240'; 12250'-12300' true vertical (subsea) 9952'-9976'; 10016'-10048'; 10056'-10095' Tubing (size, grade, and measured depth)4-1/2" 12.6#/ft L-80 TDS to 11674'; 3-1/2" 9.2#/ft L-80 TDS to 12161' and 2-7/8" Tailpipe to 12188' Packers and SSSV (type and measured depth)9-5/8" TIW @ 11690'; 7" TIW @ 12169', 4-1/2" SSS V @ 1549' 13. Attachments Description summary of proposal X Detailed operations program BOP sketch 14. Estimated date for commencing operation March 1989 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas Service Production Suspended 17. I hereby certj:[y that t~e foregoing/~true ~and correct to the best of my knowledge. Signed .~~~_~ Title Completion Engineerin~lSupervisor ~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test~ Mechanical Integrity Test~ Approved by order of the Commission Form 10-403 Rev 06/15/88 [ Approval No. Location clearance Subsequent form required 10- ;~'~pro¥Od G~op¥ ' 'Returne~ ~ ORIGINAL SIGNED B~ ~ ~ ~'~. ~¢ I.~NNIE C. SMI~" ~er Date /~- ~ SUBMIT IN TRIPLICATE ATTACHMENT I PROPOSED 3-35/L-36 SDI RIG WORKOVER PROCEDURE: . 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. MIRU rig. Pull BPV. Circulate diesel out of well. Set 2-way check valve. ND tree. NU & test BOP's to 5000 psi. Pull 2-way check valve. Pull 4-1/2" tubing. RIH and recover slick stick. Test 9-5/8" packoff on FMC wellhead. Replace if necessary. Recover 9-5/8" TIW retriveable packer and 3-1/2" tailpipe assembly. RIH with 9-5/8" scraper and tailpipe assembly. Reverse circulate. RIH with 3-1/2" overshot and grab 3-1/2" fish. RU wireline and drift through drill string, 7" packer, and 2-7/8" tailpipe. RD wireline. Release latch and reverse circulate. POH with latch assembly. RIH with 7" RTTS. Test 9-5/8" casing & 7" liner lap to 2500 psi. Run 4-1/2" tubing with 6 GLM's and a 3-1/2" tailpipe. Set 2-way check valve. ND BOP's. NU & test tree to 5000 psi. RIH with wireline and set plug in 3-1/2" tailpipe. Set 9-5/8" permanent packer. Pressure test tubing X annulus. Open sliding sleeve and displace the 9-5/8" by 4-1/2" annulus with 9.6 ppg brine + 35 bbls diesel and displace tubing with diesel. Close and test sliding sleeve. Set BPV. Release rig. ';Jaska 0il & Gas Cons, ": ~chorago WORKOVER B.O.P. STACK CONFIGURATION 13-S/g IN. TRIPLE RAM STACK S000 PSI WP ATTACHMENT II DRILLING ANNULAR PREVENTER 2 IN. KILL LINE GATE GATE I BLIND RAMS' 1 , PIPE RAMS i ?z?E RAMS ,, ,1 I ! i DRILLING ~ SPOOL i GATE GATE Standard Alaska Production Company 900 East Benson Boulevaru P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 564-5111 January 25, 1989 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 ! -~ 1-41/O-23 ~-'1-43/P-26 t -2-04/M-19 ~-- 3-21/L-34 t.~ 3-35/L-36 12-06-88 12-16-88 01-02-89 01-02-89 01-15-89 If there Twyford are at any questions regarding this data, 564-4401. please contact Loren Sincerely, JLH Jeanne L. Haas Anchorage A unit of the original Standard Oil Company Founded m Cleveland. Ohio, ,n 1870 Standard Alaska Production Company 900 East Benson Boulevo,~ P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 564-5111 January 20, 1989 STANDARD ALASKA PRODUCTION Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Endicott Well 3-35/L-36 Stimulation Dear Sirs: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for Endicott Well 3-35/L-36. We are planning to perform a mud acid stimulation on this well in late January, 1989. Commissioner Chatterton gave verbal approval of this work to Loren Twyford on January 11, 1989. If there are any questions regarding this data, please contact Loren Twyford at 564-4401. Working Interest Owners Well File RECEIVED Alaska Oil & Gas Cons. Commissior~ Anchorage A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. 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 X Change approved program __ Pull tubing __ Variance __ Perforate Other __ 2. Name of Operator Standard Alaska Production Company 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development x Exploratory Stratigraphic Service Datum elevation (DF or KB) KBE = 55.4 feet Unit or Property name Duck Island Unit/Endicott 4. Location of well at surface 8. 25O8' SNL, 680' WEL, Sec. 8, T11N, R17E At top of productive interval 9. 4529' SNL, 1835' WEL, Sec. 4, T11N, R17E At effective depth 10. 4418'SNL, 1650' WEL, Sec. 4, T11N, R17E At total depth 11. 4386'SNL, 1620'SEL, Sec. 4, T11N, R17E Well number 3-35/L-36 SDI Permit number 87-2O APl number 5O- 029-217O1 Field/Pool Endicott Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 12640 feet 10410 BKB feet 12548 feet 10239 BKB feet Plugs (measured) Junk (measured) Length Size Cemented 123' 30" Driven 2464' 13 3/8" 3720 c.f. Permafrost Cmt 11951' 9 5/8" 575 c.f. Class G RECEIVED JAN 2 o 51 ls.ka.0il & Gas Cons, C0mmi. ssjQi i Measured d.~ ~i~t~~ ~p~ h: ~' "~" 161' 161' 25O3' 2501' 11989' 9915' 903' 7" 315 c.f. Class G 11737' - 12640' measured 12114'- 12146', 12198'- 12240', 12250'- 12300' 9734'- 10410' true vertical (Subsea) 9952'- 9976', 10016'- 10048', 10056'- 10095' Tubing (size, grade, and measured depth) 4 1/2" 12.6tt/Ft. L80 TDS Tubing to 11674'; 3 1/2" 9.2#~Ft. L80 TDS with 2 7/8" Tailpipe to 12188' Packers and SSSV (type and measured depth) 9 5/8" Packer at 11690'; 7" Packer at 12169'; 4 1/2" SSSV at 1549' 13. Attachments Description summary of proposal X Detailed operations program X BOP sketch 14. Estimated date for commencing operation January 21 - 25, 1989 16. If proposal was verbally approved Co['~ti s s±oner Chatterton Name of approver 1/11/89 Date approved 15. Status of well classification as: Oil X Gas Service Production Suspended __ 117. I herel~ify t..h~t')4'e~re.,~oing is true and correct to the best of my knowledge. Signe Title Manager, Reservoir & Production Engineering7 FOR COMMISSION USE ONLY Con~~~'s of approval: Notify Commission so representative may witness Plug integrity__ BOP Test__ Location clearance__ Mechanical Integrity Test _ ~.,~Subseque~rm~quired 10- ~.?"/' Approved by order of the Commissio< Form 10-403 Rev 06/15/88 -- ~ ~"-~/ "/7' /' J Approval No. 2_ O~// Approved Copy Retuj:ned Co m m ,ss i~n'~r"~-~at o ~7~' SUBMIT IN '~IP~.I~CATE Mud Acid Stimulation on well 3-35/L-36 Due to the low productivity of the upper 3A sand interval in well 3-35/5-36 and +14.4 skin due to formation damage in the lower 3A sands, a mud acid job has been prepared. Attached is a detailed procedure for the mud acid stimulation. Please note that a pressure build-up has been requested to evaluate the upper 3A sand interval. This pressure buildup will be completed prior to the stimulation. '2.. WELL 3-35/L-36 MUD ACID PROCEDURE (FOR SELECTIVE TREATMENT OF STRADDLED INTERVAL) 1, . . , . . Prior to Stimulation: Obtain a well head sample and test for emulsion tendency and sludging. The results of these tests will determine the additives to be incorporated in the following procedure. RU Pumping unit, CTU and acid tanker. Shut-in well. Record WHSIP/WHSIT. Annulus pressures should be monitored throughout the job. Prepare the following treatments: PREFLUSH: 15 BBLS DIVERTING AGENT: 9.5 BBLS MUD ACID: 80 BBLS 12% HCL With a mutual solvent Gelled NH4CL with OSR 6% HCL - 1.5% HF Mud Acid Treat the perforations 12,114' - 12,146' MDBKB with the following preflush, the diverting agent will be added to the pr,flush in slugs. Pump: 5 BBLS Preflush Add: 1 BBLS Diverting Agent Pump: 5 BBLS Preflush Add 1 BBLS Diverting Agent Pump: 5 BBLS Preflush Stimulate the perforations behind the straddle with the following mud acid/diverter treatment: Pump: 20 BBLS Mud Acid Add: 2.5 BBLS Diverting Agent (Repeat sequence until 80 BBLS of mud acid and 7.5 BBLS of diverting agent have been pumped.) Treat the perforations behind the straddled interval with an overflush of 80 BBLS diesel and 10% mutual solvent. Return well to production immediately. Due to the rapid reaction rate of the mud acid it is important to flow the well back immediately after the overflush to minimize the precipitation of detrimental reaction products. Initially bring the well on slowly to minimize fines migration.. Obtain several flowback samples. Label samples with time. Continue to obtain samples until clean oil is obtained. 8. Rig down. Leave well on for production. Rig: PAA #7 Well: 3-35/L-36 (SDI) Daily Drilling Report-- ENDICOTT August 14, 1987 at 0600 hrs STANDARD ALASKA PRODUCTION Depth: 12,640' Day: 31 24-Hour Ftg: -' Current Operation: NIU BOPE. Accept rig at 0001 hrs on 8-14-87. Install check valve in hanger. N/D tree and NIU BOPE. Mud Type: Brine WT: 9.7 VIS: PV: YP: FL: SOLIDS: TEMP: °F ANGLE DIRECTION TVD, SECTION I?£CEIVF. D OC'[' 0 2 .!.% / Alas~ Oil & Gas Cons. Cornrnissiot~ Anchorage STANDARD ALASi<A PRODUCTION Rig: PAA #7 Well: 3-35/L-36 (SDI) Daily Drilling Report-- ENDICOTT August 17, 1987 at 0600 hrs 0600 Depth: 1~548' Day: 34 72-Hour Ftg: -' Current Operation: NID BOPE. N/U BOPE. Remove tubing hanger. Test BOPE. RIH and displace diesel from well. RIH to bottom. Circ and filter brine. POH. RIH with perforating guns and space out. Pressure up on drill pipe and fire guns. Flow oil to surface. Kill well with brine. POH and L/D guns. Run gauge ring and junk basket to 12158'. Run 4-1/2" completion and land in wellhead. N/D BOPE. Mud Type: Brine WT: 9.6 VIS: PV: YP: FL: SOLIDS: TEMP: °F SURVEY ,MD ANGLE DIRE~WION TVD SEGTIQN COORDINATES DLS Alaska 0il & Gas Cons. commission Anchorage STANDARD ALASKA PRODUCTION Rig' PAA #7 Well: 3-35/L-36 (SDI) Daily Drilling Report -- ENDICOTT August 18, 1987 at 0600 hrs 0600 Depth: 1~,548' Day: 35 24-Hour Ftg: -' Current Operation: N/D BOPE. Install and test tree. Pull dummy SSSV. Set plug in tailpipe. Pressure up and set packer with 3000 psi. Test annulus to 2500 psi - 0 Jr. Open s.s., displace tubing to diesel, close s.s. Set BPV in hanger. Release rig at 2200 hrs on 8-17-87 Mud Type: Brine... WT: 9.6 VIS: PV: YP: FL: SOLIDS: TEMP: °F ,,SURVEY MD ANGLE DIRE(~SFION TVD SE~rlON COORDINATES OLS Standard ~.laska .... ~ Production Company 900 East Benson Boulevard.: P.O. Box 196612 Anchorage, AIoska 99519-6612 (907) 561-5111 5'I'ANDARD ALASKA PRODUCTION October 26, 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: WELL 1-09/J- 18 *Tempemn'e Log 11740'-12185' Camco Run No. 1 WELL 3-5~0-29 *Temperture Log 11800'-12565' Camco Run No. 1 WELL 3-35/L-36 *Temperture LOg 11900'-12545' Camco Run No. 1 Sincerely, ~illard Received B Gas Cons, Commissio;~ gn¢orage Date A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. Standar. d Alaska p ~ ~' ~e_nsan ~Ou~ev ux 1966 ! 2 arc, : vz', J6).5] } I 9'66t2 October 20, 1988 S'/'AN DARD ALAS PRODUCTION Alaska Oi/ and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sirs: Enclosed are BOttom Hole Pressure the Endicott Reservoir: Reports for the following Wells in 1-09/]_18 2-28/p. 19 2-44/R_12 3-05/0.29 3-11/M-30 3-35/L-36 3-39/.t:39 4-02/Q_28 I0-10-88 09-27-88 08-30-88 10-10-88 09-27-88 10-09-88 09-12-88 4-26/0-34 07-26-88 'there are any questions regarding 09-18_88 Twyford at 564-4401. this data, please Contact Loren o m Cleve~ - au~'a Oil ,,~na 0~.. Company · mo, in 1070. Sincerely, -/eanne L. Haas --. STATE OF ALASKA ALAS , ".AND GASCONSERVATIOI~ WELL COMPLE OR RECOMPLETIOh ,. EPORT 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 87-20 _ 3'. Address 8. APl' Number P. O. Box 196612 Anchorage Alaska 99519-6612 50-029-21701 4. Location of well at surface 9. Unit or Lease Name 2508' SNL, 680'WEL, Sec 8, TllN, R17E Duck Island Unit/ Endicot' At Top Producing Interval 10. Well Number 4529' SNL, 1835' WEL, Sec. 4, TllN, R17E 3-35/L-36 SDI At Total Depth 11. Field and Pool 4386' SNL, 1620' WEL, Sec. 4, TllN, R17E 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Endicott Field 55.40' = KBE ADL 47503 Endicott Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 3-2-87 3-28-87 8-17-87J N/A feet MSLJ one ., 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where sSsv set ~ 21. Thickness of Permafrost 12640 ' MD 10410 ' TV D 12558 ' MD i0239' 5V~9~S ~ NO [] 1549 feet MDI 1466 ' 2'2. T~/pe Electric or Other Logs Run CNL, GCT, CBT, CET, DLL/MSFL 23. CASING. LINER AND CEMENTING RECORD SETIING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED ~0" Stru.~tural DrLve Pipe Surface 161' '"~3,'3/8" 68# L-80 Surface 2503' 17%" 3720 cu.ft. Permafrost 9-5/8" 47# NT80S Surface 10021' 12%" , 9-5/8" 47# NT95HS 10021' 11989' 12¼" 575 cu.ft. Class G . [%CFR-2 .25% HR-7 7" 29# SMll0 11737' i 12640' 8%" 315 cu.ft. Class G .~% Halad 344 ,i6L~ 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD & .2% CFR-2 interval, size and number) SIZE DEPTH SET (MD) pACKER SET (MD) MD BKB TVDss 4% ~DS 11674' 9-5/8"TIW 11690' 12114,-12146, 9952,_9976, 3% TDS 12161' 7,, TIW 12169' .. 12198 ' -12240 ' 10016 ' -10048 ' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 12250 ' -12300 ' 10056' -10095 ' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 13-3/8" x 9-5/8" Downs~ueez~ 13-3/8" x 9-5/~" annulus w~th ~45 followed bv 119 bbls dry crur .--. 27. PRODUCTION TEST Date First Production I Method of Operation (F~owin§, gas ~ift. etc.) October 1987/ Flowing Date Of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO iTEST PERIOD ~ FI°w Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA , , Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ~L Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate Top Hrz Put River NAME GEOLOGIC MARKERS MEAS. DEPTH 11651' 12009' Top Kekiktuk 12040' TRUE VERT. DEPTH 9618 ' 9874' 9898' 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 ~.~_~_~, ¢ ~ ~ Drilling S~gned' ~ · 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". TELECO Teleco Oilfield Se~ ~s of Alaska Inc. 6116 Nielson Way Anchorage, AK 99502 (907) 562-2646 March 25, 1987 JOB #567 STANDARD ALASKA PRODUCTION CO. WELL: 3-35/L-36 ENDICOTT SDI RIG: PAA #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 ,~1~_'!' COMPANY TELECO OILFIELD SERVICES JOB 567 SURVEY CALCULATIONS Date Page 03/25/87 Company: Well: Location: Rig: STANDARD ALASKA PROD CO 3-35/L-36 ENDICOTT SDI POOL ARCTIC AK #7 TELECO Job # 567 TAK Grid Correction: Magnetic Declination: Total Correction: Proposed Direction: 0.00 degrees 31.50 degrees 318.50 degrees 51.50 degrees RADIUS OF CURVATURE CALCULATION 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 @ 2490' 2490.00 1.5 339.0 N 21 00 W 2488.77 -10.56 35.61N 42.07W 55.11 N 49.754W 0.000 TELECO MWD SURVEYS 2877.00 1.1 347.2 N 12 48 W 2875.68 -8.52 43.11N 45.18W 62.45 N 46.341W 0.126 3158.00 1.6 14.6 N 14 36 E 3156.60 -4.35 49.67N 45.07W 67.08 N 42.223W 0.286 3437.00 1.3 9.4 N 09 24 E 3435.51 1.09 56.58N 43.61W 71.43 N 37.623W 0.118 3717.00 0.9 32.6 N 32 36 E 3715.46 5.69 61.56N 41.69W 74.35 N 34.111W 0.211 2597.00 1.2 330.3 N 29 42 W 2595.74 -10.18 37.88N 43.14W 57.42 N 48.716W 0.339 TELECO Job # 567 TAK 03/25/87 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' **************************************************************************************************** 3954.00 1.3 1.6 N 01 36 E 3952.41 9.39 65.85N 40.37W 77.24 N 31.514W 0.297 4076.00 3.7 32.9 N 32 54 E 4074.29 13.74 70.87N 38.82W 80.80 N 28.711W 2.193 4180.00 6.6 40.6 N 40 36 E 4177.86 22.76 78.34N 33.23W 85.10 N 22.989W 2.860 4264.00 7.8 45.9 N 45 54 E 4261.19 33.17 86.01N 26.02W 89.86 N 16.836W 1.632 4359.00 9.9 41.3 N 41 18 E 4355.06 47.64 96.59N 15.95W 97.90 N 9.377W 2.331 4471.00 12.6 39.6 N 39 36 E 4464.90 69.09 113.21N 1.77W 113.23 N 0.900W 2.429 4564.00 14.2 40.6 N 40 36 E 4555.36 90.21 129.70N 12.10E 130.26 N 5.331E 1.738 4659.00 15.9 41.3 N 41 18 E 4647.10 114.46 148.33N 28.27E 151.00 N 10.790E 1.799 4754.00 17.6 43.5 N 43 30 E 4738.07 141.49 168.55N 46.73E 174.90 N 15.496E 1.910 4847.00 18.6 45.6 N 45 36 E 4826.46 170.17 189.14N 66.99E 200.65 N 19.506E 1.284 4947.00 20.0 45.6 N 45 36 E 4920.84 203.05 212.25N 90.62E 230.78 N 23.121E 1.400 5040.00 22.0 46.6 N 46 36 E 5007.66 236.23 235.36N 114.63E 261.79 N 25.969E 2.185 5138.00 23.8 47.7 N 47 42 E 5097.93 274.25 261.29N 142.59E 297.66 N 28.622E 1.888 5233.00 25.8 47.3 N 47 18 E 5184.17 314.00 288.21N 171.97E 335.61 N 30.824E 2.113 5333.00 28.5 47.7 N 47 42 E 5273.14 359.51 319.03N 205.61E 379.55 N 32.801E 2.706 5428.00 31.0 49.1 N 49 06 E 5355.61 406.58 350.33N 240.86E 425.14 N 34.509E 2.731 5522.00 33.2 50.8 N 50 48 E 5435.24 456.51 382.47N 279.09E 473.47 N 36.119E 2.530 TELECO Job # 567 TAK 03/25/87 Page 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' 5621.00 35.9 51.2 N 51 12 E 5516.77 512.65 417.80N 322.72E 527.92 N 37.684E 2.737 5715.00 38.0 52.2 N 52 12 E 5591.88 569.15 452.81N 367.06E 582.90 N 39.029E 2.324 5808.00 40.2 52.6 N 52 36 E 5664.05 627.79 488.60N 413.53E 640.11 N 40.243E 2.381 5904.00 42.5 53.3 N 53 18 E 5736.11 691.19 526.81N 464.14E 702.11 N 41.381E 2.444 5998.00 45.2 54.7 N 54 42 E 5803.90 756.24 565.08N 516.82E 765.78 N 42.446E 3.052 6250.00 46.6 55.7 N 55 42 E 5979.26 936.82 668.36N 665.41E 943.12 N 44.874E 0.624 6444.00 46.7 55.8 N 55 48 E 6112.44 1077.52 747.76N 782.03E 1082.00 N 46.283E 0.064 6635.00 47.8 57.2 N 57 12 E 6242.09 1217.23 825.17N 898.98E 1220.28 N 47.452E 0.788 6931.00 48.6 57.3 N 57 18 E 6439.38 1436.78 944.54N 1084.56E 1438.21 N 48.948E 0.272 7024.00 49.0 57.5 N 57 30 E 6500.64 1506.38 982.24N 1143.51E 1507.45 N 49.339E 0.460 7281.00 45.9 48.4 N 48 24 E 6674.41 1695.43 1096.18N 1294.44E 1696.23 N 49.741E 2.872 7382.00 45.9 48.7 N 48 42 E 6744.69 1767.86 1144.19N 1348.80E 1768.74 N 49.692E 0.215 7576.00 46.4 48.7 N 48 42 E 6879.09 1907.60 1236.48N 1453.95E 1908.63 N 49.621E 0.259 7670.00 46.8 48.7 N 48 42 E 6943.68 1975.82 1281.53N 1505.28E 1976.92 N 49.590E 0.427 7852.00 46.8 49.1 N 49 06 E 7068.27 2108.36 1368.75N 1605.26E 2109.58 N 49.547E 0.161 8043.00 46.3 48.0 N 48 00 E 7199.62 2246.83 1460.53N 1709.19E 2248.22 N 49.486E 0.493 8145.00 46.1 48.0 N 48 00 E 7270.22 2320.32 1509.77N 1763.92E 2321.82 N 49.439E 0.202 TELECO Job # 567 TAK 03/25/87 Page 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' 8239.00 45.5 47.0 N 47 00 E 7335.75 2387.54 1555.30N 1813.61E 2389.17 N 49.385E 0.995 8432.00 44.4 47.0 N 47 00 E 7472.34 2523.47 1648.23N 1913.38E 2525.41 N 49.258E 0.570 8528.00 44.0 46.3 N 46 18 E 7541.17 2590.16 1694.17N 1962.04E 2592.27 N 49.190E 0.657 8611.00 43.7 46.6 N 46 36 E 7601.02 2647.44 1733.79N 2003.72E 2649.70 N 49.131E 0.439 8705.00 43.9 46.1 N 46 06 E 7668.87 2712.24 1778.70N 2050.80E 2714.69 N 49.064E 0.425 8808.00 44.1 47.0 N 47 00 E 7742.96 2783.52 1827.90N 2102.74E 2786.17 N 49.000E 0.637 8901.00 44.2 47.0 N 47 00 E 7809.69 2848.10 1872.06N 2150.14E 2850.91 N 48.955E 0.120 9001.00 45.4 46.6 N 46 36 E 7880.64 2918.33 1920.29N 9095.00 46.8 46.6 N 46 36 E 7945.82 2985.81 1966.80N 2201.50E 2921.33 2250.74E 2989.00 N 48.903E 1.233 N 48.852E 1.490 9661.00 48.4 47.3 N 47 18 E 8327.69 3402.20 2252.39N 2555.62E 3406.53 N 48.609E 0.223 9756.00 49.0 48.4 N 48 24 E 8390.39 3473.42 2300.28N 2608.54E 3477.90 N 48.593E 1.075 9933.00 48.7 49.4 N 49 24 E 8506.86 3606.56 2387.89N 2708.97E 3611.17 N 48.605E 0.458 10035.00 47.8 49.4 N 49 24 E 8574.78 3682.61 2437.39N 2766.77E 3687.26 N 48.622E 0.884 9569.00 48.2 47.3 N 47 18 E 8266.48 3333.69 2205.83N 2505.12E 3337.86 N 48.635E 0.436 9464.00 47.8 47.0 N 47 00 E 8196.23 3255.88 2152.76N 2447.91E 3259.86 N 48.671E 0.676 9365.00 47.2 46.6 N 46 36 E 8129.34 3183.14 2102.80N 2394.70E 3186.91 N 48.714E 0.064 9190.00 47.3 46.6 N 46 36 E 8010.55 3055.10 2014.55N 2301.29E 3058.49 N 48.801E 0.528 TELECO Job # 567 TAK 03/25/87 Page 5 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' 10123.00 47.0 49.1 N 49 06 E 8634.34 3747.33 2479.67N 2815.84E 3752.03 N 48.632E 0.943 10223.00 46.4 48.7 N 48 42 E 8702.92 3820.03 2527.51N 2870.68E 3824.81 N 48.638E 0.667 10404.00 44.8 48.7 N 48 42 E 8829.56 3949.20 2612.81N 2967.87E 3954.12 N 48.640E 0.884 10504.00 45.7 50.5 N 50 30 E 8899.96 4020.17 2658.84N 3021.95E 4025.13 N 48.657E 1.563 10600.00 46.8 51.2 N 51 12 E 8966.35 4089.51 2702.62N 3075.73E 4094.42 N 48.694E 1.262 10695.00 48.4 50.1 N 50 06 E 9030.40 4159.66 2747.10N 3129.97E 4164.53 N 48.727E 1.889 10797.00 49.7 51.9 N 51 54 E 9097.25 4236.69 2795.58N 3189.84E 4241.51 N 48.769E. 1.844 10975.00 50.4 52.9 N 52 54 E 9211.55 4373.13 2878.84N 3297.95E 4377.70 N 48.882E 0.583 11069.00 49.9 53.6 N 53 36 E 9271.78 4445.26 2922.02N 3355.78E 4449.65 N 48.953E 0.781 11170.00 50.0 53.3 N 53 18 E 9336.77 4522.53 2968.06N 3417.88E 4526.73 N 49.029E 0.248 11264.00 49.6 52.6 N 52 36 E 9397.45 4594.30 3011.32N 3475.18E 4598.36 N 49.090E 0.711 11360.00 48.5 54.7 N 54 42 E 9460.37 4666.75 3054.29N 3533.58E 4670.64 N 49.161E 2.010 11460.00 48.0 55.1 N 55 06 E 9526.95 4741.22 3097.19N 3594.62E 4744.88 N 49.251E 0.583 11543.00 47.5 55.4 N 55 24 E 9582.76 4802.53 3132.21N 3645.10E 4805.98 N 49.328E 0.659 11643.00 46.6 55.8 N 55 48 E 9650.89 4875.54 3173.56N 3705.49E 4878.75 N 49.422E 0.947 11738.00 45.4 56.5 N 56 30 E 9716.89 4943.65 3211.62N 11833.00 44.6 57.2 N 57 12 E 9784.06 5010.53 3248.36N 3762.24E 4946.62 3818.48E 5013.25 N 49.514E 1.370 N 49.612E 0.991 TELECO Job # 567 TAK 03/25/87 Page 6 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' **************************************************************************************************** 11943.00 43.4 58.9 N 58 54 E 9863.19 5086.44 3288.79N 3883.32E 5088.84 N 49.739E 1.531 7200 64OO 5600 4800 4000 I F-- 0 z B200 2400 1600 800 TELE[O 0 i 1 ~ i e 1 d PLAN VIEW EAST (?t) Services 800 0 BO0 1600 2400 3200 Ig43 ' 4000 TEL~CO 0 i ] ~ i ~ ~ d S~cv i c~s VERTIC^L PROgECTION - ! 000 1000 3000 5000 7000 9000 i 1000 2000 · L , , -T ~ i ~S~A~D~RD AL'¢~K5 tP~OD I;O/ ~ --~..~:F?!~-' ',"-"[ ~= i ~:--~'~;.:~--' ~'--~-: ........ ~ ....... ~ ..... 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LL ......... 4OOO 6000 8ooo .10000 12000 14000 16000 18000 20000 VERTICAL SECTION (Ct) $ UB-$ URFA CE DIRECTIONAL SURVEY F~UIDANCE r~ONTINUOUS rfl OOL Company STANDARD ALASKA PRODUCTIO~ (~OMPANY Well Name 3-35/L-36 SDI(2508' SNL.680' WEL.SEC Field/Location ENDICOTT, NORTH SLOPE, ALASKA 8.TllN.R17E) Job Reference No. 72263 Logaed By; SARBER Date 02-APR-87 Computed By; SINES SCHLUMBERGER ********************* GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR STANDARD ALASKA PRODUCTION CO. 3-35/L-36 SDI ENDICOTT NORTH SLOPE~ALASKA SURVEY DATE: 2-APR-87 ENGINEER: SARBER METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 51 DEG 18 MIN EAST STANDARD ALASKA PRODUCTION CO. 3-35/L-36 SDI ENDICOTT NORTH SLOPE,ALASKA COMPUTATION DATE: 8-APR-87 PAGE 1 DAT~ OF SURVEY: Z-APR-87 KELLY BUSHING ELEVATION: 55.40 FT ENGINEER: SARBER INTERPCLATED 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 -55.40 0 0 N 0 0 E 100.00 100.00 44.60 0 2 N 43 54 W 200.00 200.00 144.60 0 ll S 68 15 N 300.00 300,00 244.60 0 24 S 70 16 W 400.00 400.00 344.60 0 28 S 76 15 W 500.00 499.99 444.59 0 31 S 73 11 W 600.00 599.99 544.59 0 20 S 63 3 W 700.00 599.99 644.59 0 13 S 54 39 W 800.00 799.99 744.59 0 9 S 49 22 W 900.00 899.99 844.59 0 8 S 48 29 W 1000.00 999.99 944.59 1100.00 1099.98 1044.58 1200.00 1199.97 1144.57 1300.00 1299.83 1244.43 1400.00 1399.56 1344.16 1500.00 1499.37 1443.97 1600.00 1599.24 1543.84 1700.00 1699.15 1643.75 1800.00 1799.10 1743.70 1900.00 1899.07 1843.67 0 12 S 66 13 W 0 26 N 78 9 W 1 18 N 50 29 W 4 16 N 50 59 N 3 55 N 54 23 W 3 7 N 58 12 W 2 46 N 58 29 W 1 56 N 54 18 W 1 32 N 50 38 W 1 32 N 49 40 W VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET BEG/lO0 FEET FEET FEET DEG MIN 0.00 0.00 0.00 N 0.00 E 0.01 0.34 0.04 N 0.01 W -0.17 0.04 0.04 S 0.18 W -0.63 0.18 0.19 S 0.66 W -1.36 0.21 0.45 S 1.38 W -2.16 0.09 0.66 S 2,24 W -2.90 0.19 0.94 S 2.96 W -3.38 0.06 1.19 S 3.39 W -3.74 0.06 1.40 S 3.67 W -4.00 O.OZ 1.58 S 3.86 W 0.00 N 0 0 E 0.04 N 15 36 W 0.19 S 77 48 W 0.69 S 74 13 W 1.45 S 71 51 W 2.34 S 73 36 3.11 S 72 25 3.59 $ 70 41 W 3.92 S 69 4 W 4.18 S 67 46 W -4.31 0.16 1.75 S 4.12 W -4.72 0.57 1.81 S 4.59 W -5.21 1.79 1.14 S 5.76 W -6.05 0.91 2.16 N 9.49 W -7.83 0.90 6.68 N 15.38 W -9.65 0.26 10.03 N 20.40 W -11.43 0.60 12.78 N 24.88 W -12.76 1.01 15.05 N 28.41 W -13.45 0.18 16.81 N 30.70 W -13.97 0.21 18.51 N 32.73 W 4.48 S 66 55 W 4.94 S 68 30 W 5.87 S 78 46 W 9.73 N 77 10 W 16.77 N 66 31 W 22.73 N 63 49 W 27.97 N 62 49 W 32.15 N 62 5 ~ 35.0I N 61 17 W 37.60 N 60 30 W ZO00.O0 1999.03 1943.63 2100.00 2098.98 2043.58 2200.00 2198.94 2143.54 2300.00 2298.91 2243.51 2400.00 2398.87 2343.47 2500.00 2498.83 2443.43 2600.00 2598.80 2543.40 2700.00 2698.78 2643.38 2800.00 2798.75 2743.35 2900.00 2898.73 2843.33 3000.00 2998.71 2943.31 3100.00 3098.67 3043.27 3200.00 3198.64 3143.24 3300.00 3298.59 3243.19 3400.00 3398.55 3343.15 3500.00 3498.52 3443.12 3600.00 3598.51 3543.11 3700.00 3698.50 3643.10 3800.00 3798.48 3743.08 3900.00 3898.47 3843.07 1 39 N 41 50 W 1 41 N 35 20 W I 36 N 29 39 W 1 37 N 26 46 W 1 37 N 25 27 W 1 28 N 25 29 W 1 16 N 28 7 W 1 14 N 25 28 W 1 18 N 19 37 W 1 15 N 15 1 W 114 N 2 1 W 131 N 6 i9 E 140 N 8 41 E 141 N 9 50 E 1 31 N 10 3 E 1 6 N 14 39 E 0 56 N 18 17 E 0 50 N 25 4 E 0 51 N 24 J5 E 1 17 N 18 36 E -14.33 0.42 20.43 N 34.73 W -14.31 0.17 22.75 N 36.56 W -13.96 0.18 25.18 N 38.06 W -13.44 0.I0 27.67 N 39.39 W -12.82 0.17 30.23 N 40.64 W -12.15 0.74 32.75 N 41.~1 W -11.70 0.2l 34.74 N 42.83 W -11.28 0.25 36.71 N 43.86 W -10.68 0.41 38.73 N 44.72 W -9.88 0.21 40.83 N 45.3~ W -8.82 0.38 42.97 N 45.73 W -7.13 0.25 45.46 N 45.55 W -5.10 0.17 48.20 N 45.15 W -2.98 0.37 51.06 N 44.73 W -0.83 0.32 53.89 N 44.23 W 0.99 0.51 56.15 N 43.72 W 2.45 0.12 57.83 N 43.19 W 3.78 0.31 59.17 N 42.64 W 5.12 0.12 60.62 N 42.00 W 6.67 0.21 62,28 N 41.35 W 40.29 N 59 31 W 43.06 N 58 6 W 45.64 N 56 30 W 48.14 N 54 54 W 50.65 N 53 21W 53.11 N 51 55 W 55.15 N.50 57 ~ 51.20 N 50 4 k 59.16 N 49 6 N 61.04 N 48 1W 62.74 N 46 46 W 64.35 N 45 3 W 66.05 N 43 7 W 67.~8 N 41 13 W 69.72 N 39 22 W 71.17 N 37 54 W 72.18 N 36 45 W 73.01 N 35 44 W 73.74 N 34 42 W 74.76 N 33 34 W STANDARD ALASKA PRODUCTION CO. 3-35/L-36 SOI ENDICOTT NORTH SLOPEtALASKA COMPUTATION DATE: 8-APR-87 PAGE DATE OF SURVEY: 2-APRil7 KELLY BUSHING ELEVATION: 55.40 ENGINEER: SARBER 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 4000,00 3998,43 3943,03 I 50 4100,00 4098,30 4042,90 4 9 4200,00 4197,82 4142,42 6 47 4300,00 4296,95 4241,55 8 22 4400,00 4395,57 4340,17 10 24 4500,00 4493,43 4438,03 13 6 4600.00 4590,46 4535,06 14 50 4700,00 4686,70 4631,30 16 40 4800.00 4782.10 4726.71 18 3 4900,00 4876,88 4821,48 19 13 N 13 14 E N 33 44 E N 41 57 E N 44 12 E N 41 16 E N 40 53 E N 41 59 E N 43 33 E N 45 5 E N ~6 7 E VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET PEET DEG MIN 5000,00 4970,79 4915,39 21 7 5100,00 5063,38 5007,98 23 8 5200.00 5154.72 5099.32 24 58 5300.00 5244.45 5189.05 27 32 5400.00 5331,96 5276.56 30 13 5500,00 5417.23 5361.83 32 42 5600,00 5500,19 5444,79 35 10 5700.00 5580.71 5525.31 37 33 5800,00 5658,71 5603,31. 39 54 5900,00 5733,86 5678,46 42 35 8.63 2.21 64.74 N 13.25 2.77 69.29 N 22.70 1.50 76.83 N 35.66 2.79 86.23 N 51.99 2.15 98.59 N 72.17 2.12 114.10 N 95.97 2.02 192.18 N 122.82 1.85 152.17 N 152.55 1.Ob 173.54 N 184,30 1,39 195,83 N 6000.00 5805.93 5750.53 45 5 6100.00 5875.32 5819.92 46 29 6200.00 5944.14 5888.74 46 35 6300.00 6012.91 5957.51 46 30 6400.00 6081.73 6026.33 46 37 6500.00 6150.10 6094.70 47 12 6600.00 6217.72 6162.32 47 38 6700.00 6284.89 6229.49 48 1 6800.00 6351.45 6296.05 48 21 6900,00 6417.83 6362.43 48 25 N 46 52 E 218.53 N 47 50 E 256.18 N 48 15 E 296.83 N 48 34 E 340.90 N 49 14 E 389.21 N 50 57 E 441.42 N 52 6 E 497.24 N 52 56 E 556.52 N 54 0 E 619.03 N 54 53 E 684.88 7000.00 6484.00 6428.60 48 49 7100.00 6549.67 6494.27 48 14 7200.00 6618.14 6562.74 45 50 7300.00 6687.97 6632.57 45 40 7400.00 6757.77 6702.38 45 47 7500.00 6827.50 6772.10 45 56 7600.00 6896.87 6841.47 46 4 7700.00 6965.84 6910,44 46 42 7800.00 7034.49 6979.09 46 38 7900.00 7103.37 7047.97 46 15 N 55 33 E 754.03 N 55 42 E 825.82 N 56 13 E 898.13 N 56 36 E 970.44 N 57 0 E 1042.66 N 57 54 E 1115.22 N 58 30 E 1188.35 N 58 41 E 1261,82 N 58 51 E 1335.83 N 59 0 E 1409.96 N 59 8 E 1484.23 N 58 20 E 1558.94 N 52 49 E 1631.54 N 50 19 E 1703.10 N 50 6 E 1774.70 N 50 3 E 1846.36 N 49 59 E 1918,37 N 50 37 E 1990,76 N 50 54 E 2063.47 N 50 39 E 2135.96 40.81 W 76.53 N 32 13 W 38.53 W 79.29 N 29 4 W 32.46 W 83.40 N 22 54 W 23.38 ~ 89.34 N 15 10 W 12.36 W 99.36 N 7 8 W 1,06 E 114,11 N 0 31 P 17.07 ~ 133,28 N 7 21 ) 35,47 E 156.25 N 13 7 ~ 56,44 E 182,48 N 18 1 ~ 79.26 E 211.Z7 N 2Z 2 E 2.29 1.92 2.23 2.88 2.75 2.69 2.54 2.48 2.62 2.69 219.48 N 104.17 f 242.95 N 25 23 E 245.03 N 131.95 E 278.30 N 28 18 E 272.21 N 162.26 E 316.90 N 30 47 E 301.50 N 195.26 E 359.20 N 32 55 E 333.35 N 231,65 E 405.93 N 34 47 E 366.87 N 271.69 E 456.52 N 36 31 E 401,53 N 315,45 E 510,62 N 38 9 E 437.63 N 362.4~ E 568.25 N 39 38 E 474.86 N 412.75 E 629.17 N 40 59 E 513,19 N 466,43 E 693,48 N 42 16 ~ 2.35 0.42 0.15 0.29 0.57 0.93 0.35 0.67 0.22 0.73 552.68 N 523.39 E 761.18 N 43 26 E 593.33 N 582.81 E 831.69 N 4~ 29 E 633.89 N 642.97 E 902.90 N 45 24 E 674.08 N 703.43 E 974.27 N 46 13 E 713,83 N 764.12 E 1045,68 N 46 56 E 753.09 N 825.64 E 1117.51 N 47 37 E 791.82 N 888.31 E 1189.99 N 48 17 830.43 N 951.5Z E 1262.94 N 48 53 869,13 N 1015,35 E 1336,54 N 49 26 ~ 907.75 N 1079.40 E 1410.36 N 49 56 E 0.85 4.28 4.22 0.41 0.48 0.91 0.45 0.52 0.25 1.14 946.24 N 1143.73 E 1484.41 N 50 23 E 984.87 N 1208.51 E 1558.99 N 50 49 E 1025.83 N 1268.71 E 1531.55 N 51 2 E 1070.89 N 1324.31 E 1703.12 N 51 2 E 1116.71 N 1379.35 E 1774.72 N 51 0 E 1162.70 N 1434,33 k 1846,39 N 50 58 E 1209.02 N 1489.48 E 1918.41 N ~0 56 E 1255.34 N 1545.1~ E 1990.81 N 50 54 E 1301.21 N 1601.56 f 2063.52 N 50 54 E 1347.03 N 1657.73 f 2136.02 N 50 54 f COMPUTATION DATE: 8-APR-87 PAGE STANDARD ALASKA PRODUCTION CO. 3-35/L-36 SDI ENDICOTT NORTH SLOPE,ALASKA DATE OF SURVEY: Z-APR-87 KELLY BUSHING ELEVATION: 55.40 FT ENGINEER: SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEC MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEC MIN 8000.00 7172.66 7117.26 46 4 8100.00 7242.16 7186.76 45 56 8200.00 7312.09 7256.69 45 24 8300.00 7382.60 7327.20 45 5 8400.00 7453.45 7398.05 44 15 8500.00 7525.40 7470.00 43 52 8600.00 7597.77 7542.37 43 29 8700.00 7670.43 7615.03 43 25 8800.00 7742.88 7687.48 43 42 8900.00 7815.04 7759.64 44 4 N 50 6 E 2208.06 N 49 29 E 2279.93 N 49 3 E 2351.37 N 48 38 E 2422.22 N 48 36 E 2492.71 N 48 3 E 2562.06 N 47 57 E 2630.95 N 48 4 E 2699.55 N 48 10 E 2768.36 N 48 15 E 2837.49 0.37 0.44 0.93 0.93 1.13 0.98 0.41 0.22 0.20 0.92 1392.99 N 1713.29 E 2208.12 N 50 53 E 1439.40 N 1768.20 f Z280.00 N 50 51 E 1486.01 N 1822.40 E 2351.46 N 50 48 E 1532.76 N 1875.73 E 1422.33 N 50 44 E 1579.41N 1928.67 E 2492.85 N 50 41 E 1625.55 N 1980.51E 2562.24 N 50 37 1571.77 N 2031.81 E 2631.17 N 50 33 1717.76 N 2082.87 E 2699.82 N 50 29 1763.75 N 2134.20 E 2768.68 N 50 25 1809.89 N 2185.81E 2837.86 N 50 22 9000.00 7886.37 7830.97 45 2 9100.00 7955.98 7900.58 46 28 9200.00 8024.70 7969.30 46 42 9300.00 8093.22 8037.82 46 47 9400.00 8161.51 8106.11 47 6 9500.00 8229.19 8173.79 47 35 9600.00 8296.5~ 8241.14 47 49 9700.00 8363.40 8308.00 48 11 9800.00 8429.78 8374.38 48 36 9900.00 8495.86 8440.46 48 28 N 48 9 E 2907.48 N 48 29 E 2979.17 N 48 16 E 3051.72 N 48 16 E 3124.45 N 48 17 E 3197.41 N 48 30 E 3270.92 N 48 49 E 3344.77 N 49 16 E 3419.07 N 50 0 E 3493.83 N 50 38 E 3568.87 1.69 0.61 0.78 0.55 0.70 0.27 0.59 0.79 0.80 0.61 1856.59 N 2238.08 E 2907.91 N 50 19 E 1904.33 N 2291.68 E Z979.65 N 50 16 E 1952.53 N Z346.04 E 3052.25 N 50 13 E 2001.07 N 2400.33 E 3125.04 N 50 10 E 2049.66 N 2454.89 E 3198.06 N 50 8 E 2098.56 N 2509.91 E 3271.64 N 50 6 E 2147.40 N 2565o42 E 3345.55 N 50 4 E 2196.15 N 2521.56 E 3419.89 N 50 2 E 2244.61 N 2678.52 E 3494.68 N 50 2 E 2292.48 N 2736.33 E 5569.73 N 50 2 E 10000.00 8562.54 8507.14 47 51 10100.00 8630.32 8574.92 4b 59 10200.00 8699.03 8643.63 46 12 10300.00 8768.78 8713.38 45 12 10400.00 8839.82 8784.42 44 33 10500.00 8910.62 8555.22 45 22 10600.00 8980.17 8924.77 46 3~ 10700.00 9047.97 8992.57 48 5 10800.00 9113.63 9058.22 49 35 10900.00 9177.92 9122.52 50 3 N 50 49 E 3643.39 N 50 50 E 3716.91 N 50 44 E 3789.58 N 50 40 E 3861.21 N 50 24 E 3931.59 N 51 23 E 4002.20 N 52 7 E 4074.05 N 52 21 E 4147.56 N 53 2 E 4222.95 N 54 13 E 4299.~7 1.12 0.55 0.92 1.06 0.56 1.60 1.66 1.98 1.54 0.61 2339.60 N 2794.06 E 3644.25 N 50 3 E 2386.02 N 2851.08 E 3717.76 N 50 4 E 2431.96 N 2907.39 E 3790.42 N 20 5 k 2477.33 N 2962.83 E 3862.06 N 50 5 E 2522.11 N 3017.13 E 3932.44 N 50 6 E 2566.76 N 3071.83 E 4003.05 N 50 7 E 2611.10 N 3128.37 E 4074.87 N bO 8 ~ 2656.13 N 3186.49 ~ ~148.34 N 50 1I ~ 2701.93 N 3246.41 E 4223.69 N 50 13 E 2747.28 N 3308.11 E 4300.13 N 50 17 ~ 11000.00 9242.22 9186.82 49 51 11100.00 9306.81 9251.41 49 43 11200.00 9371.52 9316.12 49 36 11300.00 9436.81 9381.41 48 49 11400.00 9503.13 9447.72 48 4 11500.00 9570.34 9514.94 47 26 11600.00 9638.44 9583.04 46 43 11700.00 9707.43 96~2.03 ~5 56 11800.00 9777.83 9722.43 44 44 11900.00 9849.61 9794.21 43 38 N 54 30 E 4375.94 N 55 3 E 4452.14 N 55 23 E 4528.21 N 55 43 E 4603.74 N 56 20 E 4678.34 N 56 50 E 4752.06 N 57 13 E 4824.93 N 57 38 E 4896.89 N 58 26 E 4967.42 N 59 41 E 5036.41 0.5~, 0.47 0.77 1.01 0.93 0.99 0.73 1.52 0.92 0.84 2791.84 N 3370.41 E 4376.53 N 50 21 E 2835.91 N 3432.74 E 4452.65 N 50 26 E 2879.37 N 3495.38 E 4528.63 N 50 31 E 2922.15 N 3557.90 ~ 4604.08 N 50 36 ~ 2963.98 N 3619.97 ~ 4678.60 N 50 41 E 3004.73 N 3581.78 E 4752.25 N 50 ~6 E 3044.62 N 3743.19 ~ 48~5.06 N 50 52 E 3083.61 N 3804.17 E 4896.97 N 50 58 E 3121.17 N 3864.45 E 4967.46 N 51 4 E 3157.01 N 3924.14 E 5036.42 N 51 10 E STANDARD ALASKA PRODUCTION CO. 3-35/L-36 SOI ENDICOTT NORTH SLOPEsALASKA COMPUTATION DATE: 8-APR-87 PAGE DATE DF SURVEY: Z-APR-87 KELLY BUSHING ELEVATLON: 55.40 ENGINEER: SAR~ER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH 'TRUE SOB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET OEG MIN 12000,00 9922.44 9867.04 42 43 12100.00 9996.68 9941.28 41 13 12200.00 10072.72 10017.32 39 50 12300.00 10149.64 10094.24 39 55 12400.00 10226°09 10170.69 40 16 12500.00 10302.42 1024'7.02 39 42 12600.00 10379.28 10323.88 39 47 12640.00 10410.01 10354.61 39 47 N 60 30 E 5104.13 N 60 12 E 5170.23 N 59 2 E , 5234.49 N 58 38 E 52Y7.87 N 58 57 E 5361.76 N 59 39 E 5425.75 N 59 34 E 5489.06 N 59 34 E 5514.39 1.32 1.83 1.70 0.79 0.50 1.02 0.00 0.00 3191.17 N 3983.53 E 5104.13 N 51 18 E 3224.02 N 4041.92 E 5170.24 N 51 25 E 3256.82 N 4097.97 E ~234.53 N 51 31 E 3290.11 N w152.52 E 5297.95 N 51 36 E 3323.44 N 4207.68 E 5361.89 N 51 41 E 3356.52 N 4263.18 E 542~.95 N 51 47 F 3388.91 N 4318.35 E 5489.34 N 51 52 3401.87 N 4340.4Z E 5514.71 N 51 54 E COMPUTATION DATE: 8-APR-87 PAGE 5 STANDARD ALASKA PRODUCTION CO. 3-35/L-36 SDI ENDICOTT NORTH SLOPE~ALASKA DATE OF SURVEY: 2-APR-87 KELLY BUSHING ELbVATION: 55.40 FT ENGINEER: SARBER INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTM DEG MIN DEG MIN VERTICAL OOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET CEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 -55.40 ~0 0 1000.00 999.99 944.59 0 12 2000.00 1999.03 1943.63 I 39 3000.00 2998.71 2943.31 1 14 4000.00 3998.43 3943.03 1 50 5000.00 4970.79 4915.39 21 7 6000.00 5805.93 5750.53 45 5 7000.00 6484.00 6428.60 48 49 8000.00 7172.66 7117.26 46 4 9000.00 7886.37 7830.97 45 2 N 0 0 E 0.00 S 66 13 W -4.31 N 41 50 W -14.33 N 2 1 W -8.~2 N 13 14 E 6.63 N 46 52 E 218.53 N 55 33 E 754.03 N 59 8 E 1484.23 N 50 6 E 2208.06 N 48 9 E 2907.48 0.00 0.16 0.42 0.38 2.21 2.29 2.35 0.85 0.37 1.69 0.00 N 0.00 E 0.00 N 0 0 E 1.75 S 4.12 W 4.48 S 66 55 W 20.43 N 34.73 W 40.29 N 59 31 W 42,97 N 45,73 ~ 62.74 N 46 46 W 64.74 N 40.81 W 76,53 N 32 13 W 219.48 N 104.17 E 242.95 N 25 23 ~ 552.68 N 523.39 E 761.18 N 43 26 946.24 N 1143.73 E 1484.41 N 50 23 E 1392.99 N 1713.29 E 2208.12 N 50 53 f 1856.59 N 2238.0~ E 2907.91 N 50 19 E 10000.00 8562.54 8507.14 47 51 11000.00 9242.22 9186.82 49 51 12000.00 9922.44 9867.04 42 43 12640.00 10410.01 10354.61 39 47 N 50 49 E 3643.39 N 54 30 E 4375.94 N 60 30 E 5104.13 N 59 34 E 5514.39 1.12 0.54 1.32 0.00 2339.60 N 2794.06 E 3644.25 N 50 3 E 2791.84 N 3370.41 E 4376.53 N 50 21 E 3191.17 N 3983.53 E 5104.13 N 51 18 E 3401.87 N 4340.42 f 5514.71 N 51 54 E STANDARD ALASKA PRODUCTION CO. 3-35/L-36 SDI ENDICOTT NORTH SLOPE,ALASKA COMPUTATION DATE: 8-APR-87 PAGE 6 DATE DF SURVEY: Z-APR-BT KELLY BUSHING ELEVATION: 55.40 FT ENGINEER: SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMDTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0.00 0.00 -55.40 0 0 N 0 0 E 55.40 55.40 0.00 0 0 N 0 0 E 155.40 155.40 100.00 0 7 S 64 0 W 255.40 255.40 200.00 0 17 S 76 6 W 355.40 355.40 300.00 0 26 S 68 15 W 455.41 455.40 400.00 0 30 S 76 50 W 555.41 555.40 500.00 0 26 S 67 53 W 655.41 655.40 600.00 0 17 S 59 52 W 755.41 755.40 700.00 0 11 S 53 26 W 855.41 855.40 800.00 0 9 S 49 16 W 955.41 955.40 900.00 1055.41 1055.40 1000.00 1155.42 1155.40 1100.00 1255.46 1255.40 1200.00 I355.73 1355.40 1300.00 1455.95 1455.40 1400.00 1556.11 1555.40 1500.00 1656.22 1655.40 1600.00 1756.2~ 1755.40 1700.00 1856.32 1855.40 1800.00 0 11 S 54 51 W 0 16 S 81 49 W 0 46 N 60 23 W 3 5 N 47 9 W 4 18 N 52 29 W 3 23 N 56 42 W 3 i N 58 32 W 2 23 N 57 20 W 135 N 52 6 W 1 30 N 50 13 W 1956.35 1955.40 1900.00 2056.39 2055.40 2000.00 2156.44 2155.40 2100.00 2256.48 2255.40 2200.00 2356.52 2355.40 2300.00 2456.55 2455.40 2400.00 2556.59 2555.40 2500.00 2656.61 2655.40 2600.00 2756.64 2?55.40 2700.00 2856.66 2855.40 2800.00 1 36 N 45,45 W 1 41 N 37 59 W i 38 N 30 8 W i 37 N 27 48 W 1 38 N 25 52 W 1 36 N 24 42 ~ I 14 N 27 46 W 1 15 N 28 25 W I 16 N 22 44 W 1 13 N 17 6 iW 2956.69 2955.40 2900.00 3056.71 3055.40 3000.00 3156.75 3155.40 3100.00 3256.79 3255.40 3200.00 3356.83 3355.40 3300.00 3456.86 3455.40 3400.00 3556.88 3555.40 3500.00 3656.90 3655.40 3600.00 3756.91 3755.40 3700.00 3856.92 3855.40 3800.00 i 13 N 7 39 W 1 28 N 5 16 E 1 36 N 8 26 E 1 38 N 8 12 E I 38 N 9 56 E 1 19 N 13 14 E 1 0 N 17 58 i 0 52 N 22 6 E 0 51 N 25 20 E 1 2 N 20 50 E VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET OEG MIN 0.00 0.00 0.00 N 0.00 E 0.00 .0.00 0.00 N 0.00 E -0.04 0.23 0.01 N 0.06 W -0.37 0.38 0.I1 S 0.39 W -1.03 0.10 0.34 S 1.04 W -1.79 0.16 0.55 S 1.85 W -2.62 0,44 0.82 S 2.70 W -3.19 0.23 1.08 S 3.22 W -3.60 0.26 1.32 S 3.56 W -3.89 0.02 1.50 S 3.78 W 0.00 N 0 0 E 0.00 N 90 0 E 0.07 N 78 30 W 0.41 S 74 45 W 1.10 S 71 47 W 1.93 S 73 21 ~' 2.82 S 73 9 ) 3.39 S 71 24 ~ 3.80 S 69 40 W 4.07 S 68 18 W -4.16 0.07 1.68 S 3.99 W -4.52 0.30 1.82 S 4.34 W -5.00 0.86 1.60 S 5.13 W -5,49 4.91 0.18 N 7.18 W -7.03 0.67 4.77 N 12.83 W -8.85 0.88 8,70 N 18.31 W -10.67 0.41 11.61 N 22.98 W -12.28 1.04 14.12 N 27.04 W -I3.19 0.32 16.07 N 29.77 W -13,74 0,21 17,76 N 31.83 W 4.33 S 67 9 W 4.70 S 67 12 W 5.37 S 72 42 W 7.19 N 88 34 W 13.69 N 69 36 W 20.27 N 64 35 W 25.75 N 63 11 W 30.51 N 62 25 W 33.83 N 61 38 W 36.45 N 60 50 W -14.21 0.33 19.54 N 33.86 W -14.36 0.34 21.70 N 35.79 W -14.15 0.14 24.11 N 37.45 W -13.68 0.16 26.58 N 38.82 W -13.09 0.14 29.11 N 40.10 W -12.43 0.17 31.68 N 41.31 W -11.88 0.07 33.90 N 42.39 W -11.49 0.30 35.86 N 43.45 W -10.98 0.35 37.82 N 44.37 W -10.25 0.44 39.94 N 45.13 W 39.10 N 60 1 W 41.86 N 58 46 W 44.53 N 57 13 W 47.05 N 55 36 W 49.56 N 54 1 w 52.06 N 52 31 W 54.28 N 51 20 ' 56.34 N 50 27 ~, 58.30 N 4'9 33 W 60.27 N 4~ 29 W -9.3~, 0.27 42.05 N 45.65 W -7.94 0.37 44.31 N 45.67 W -6.01 0,14 46.98 N 45.34 i~ -3.90 0.10 49.83 N 44.92 W -1.72 0.40 52.72 N 44.44 W 0.27 0.63 55.27 N ~+3.93 W 1.84 0.34 57.15 N 43.4l w 3.21 0.17 58.6B N 42.9(3 W 4.54 0.12 60.04 N 42.28 W 5.91 0.90 61.43 N 41.65 W 62.06 N 47 21 W 63.63 N 45 51 W 65.29 N 43 59 N 67.09 N 42 I W 68.95 N 40 7 W 70.60 N 38 28 W 71.77 N 37 13 W 72.68 N 36 10 W 73,43 N 35 9 w 74.2l N 34 8 W COMPUTATION DATE: 8-APR-B7 PAGE 7 STANDARD ALASKA PRODUCTION CO. 3-35/L-36 SDI ENDICOTT NORTH SLOPEtALASKA DATE OF SURVEY: Z-APR-87 KELLY BUSHING ELEVATION: 55.40 ENGINEER: SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DOG MIN 3956.95 3955.40 3900.00 I 26 4057.02 4055.40 4000.00 3 1 4157.32 4155.40 4100.00 5 48 4258.03 4255.40 4200°00 7 40 4359.20 4355.40 4300.00 9 48 4461.02 4455.40 4400.00 12 15 4563.78 4555.40 4500.00 14 10 4667.37 4655.40 4600.00 16 4 4771.93 4755.40 4700.00 17 43 4877.28 4855.40 4800.00 18 55 N 10 33 E N 27 39 E N 39 5 E N 44 40 E N 41 30 E N 40 40 E N 41 39 E N 42 52 E N 44 46 E N 45 57 E 7.73 0.33 63.5~ N 10.72 2.71 66.99 N 18.02 3.56 73.21 N 29.82 2.85 82.08 N 44.97 1.27 93.26 N 63.74 2.89 107.60 N 87.04 1.67 125.43 N I13.72 1.96 145.46 N 143.99 1.33 167.43 N 176.92 1.35 190.69 N 41.05 W 75.67 N 32 50 W 39.93 W 77.99 N 30 47 W 35.56 W 81.38 N 25 54 W 27.54 ~ 86.58 :N 18 32 17.09 W 94.81 N 10 22 W 4.53 W 107.70 N 2 24 11.03 E 125.92 N 5 1 29.17 E 148.36 N 11 20 50.36 E 174.84 N 16 44 E 73.92 E 204.51 N 21 11 4983.51 4955.40 4900.00 20 45 5091.32 5055.40 5000.00 22 58 5200.75 5155.40 5100.00 24 59 5312.41 5255.40 5200.00 27 53 5427.25 5355.40 5300.00 30 54 5545.63 5455.40 5400.00 33 49 5668.25 5555.40 5500.00 36 49 5795.71 5655.40 5600.00 39 48 5929,46 5755.40 5700.00. 43 21 6071.06 5855.40 5800.00 46 21 N 46 43 E N 47 47 E N 48 16 E N 48 37 E N 49 37 E N 51 34 E N 52 37 E N 53 57 E N 55 7 E N 55 37 E 212.64 2.30 252.77 1.97 297.14 2.24 346.72 2.78 403.09 2.56 466.43 2.52 537.35 2.36 616.30 2.58 704.93 2.68 804.88 1.01 215.43 N 99.87 E 237.45 N 24 52 E 242.74 N 129.42 E 275.08 N 28 3 E 272.42 N 162.49 E 317.20 N 30 48 E 305.35 N 199.64 E 364.82 N 33 10 E 342.38 N 2~2.21 E 419.39 N 35 16 E 382.50 N 291.21 E 480.74 N 37 17 E 426.03 N 347.22 E 549.60 N 39 10 E 473.25 N 410.55 E 626.51 N 40 56 E 524.71 N 482.89 E 713.10 N 42 37 E 581.47 N 565.48 E 811.10 N 44 12 E 6216.39 5955.40 5900.00 46 35 6361.71 6055.40 6000.00 46 30 6507.81 6155.40 6100.00 47 16 6656.01 6255.40 6200.00 47 47 6805.95 6355.40 6300.00 48 21 6956.67 6455.40 6400.00 48 37 7108.69 6555.40 6500.00 48 1 7253.34 6655.40 6600.00 45 42 7396.60 6755.40 6700.00 45 47 7540.24 6855.40 6800.00 46 6 N 56 16 E 909.99 N 56 48 E 1014.99 N 57 58 E 1120.91 N 58 34 E 1229.44 N 58 51 E 1340.23 N 59 7 E 1451.99 N 58 4 f 1565.40 N 50 41 E 1669.70 N 50 7 E 1772.27 N 49 58 E 1875.35 0.20 0.44 0.86 0.47 0.18 0.49 5.11 1.36 0.48 0.60 640.51 N 652.87 E 914.60 N 45 32 E 698.64 N 740.84 E 1018.30 N 46 40 E 756.13 N 830.49 E 1123.14 N 47 40 E 813.44 N 923.65 f 1230.78 N 48 37 E 871.43 N 1019.15 E 1340.92 N 49 28 E 929.53 N 1115.80 E 1452.25 N 50 12 968.24 N 1214.10 E 1565.45 N 50 51 1049.59 N 1298.58 E 1669.71 N 51 3 1115.15 N 1377.48 E 1772o29 N 51 0 E 1181.34 N 1456.54 E 1875.39 N 50 57 7684.77 6955.40 6900.00 46 38 7830.46 7055.40 7000.00 46 29 7975.10 7155.40 7100.00 46 9 8119.03 7255.40 7200.00 45 51 8261.57 7355.40 7300.00 45 4 8402.73 7455.40 7400.00 44 14 8541.54 7555.~0 7500.00 43 37 8679.31 7655.40 7600.00 43 23 8817.33 7755.40 7700.00 43 44 8956.42 7855.40 7800.00 44 33 N 50 30 E 1979.69 N 50 50 E 2085.62 N 50 15 E 2190.12 N 49 24 E 2293.60 N 48 41 E 2395.10 N 48 35 E 2494.61 N 47 56 E 2590.74 N 48 1 E 2685.35 N 48 10 E 2780.33 N 48 12 E 2876.87 0.77 0.96 0.74 0.64 1.07 1.13 0.49 0.15 0.05 0.42 1248.30 N 1536.5~ E 1979.73 N 50 54 ~ 1315.19 N 1618.73 E 2085.67 N 50 54 E 1381.49 N 1699.52 f 2190.18 N 50 53 ~ 1448.29 N 1778.59 E 2293.67 N 50 50 E 1514.83 N 1855.34 E 2395.20 N 50 46 E 1580.67 N 1930.10 E 2494.75 N 50 41 E 1644.79 N 2001.91 E 2590.94 N 50 35 E 1708.25 N 2072.29 E Z685.61 N 50 30 ~ 1771.73 N 2143.13 f 2780.65 N 50 25 E 1836.14 N 2215.26 E 2877.27 N 50 20 E STANDARD ALASKA PRODUCTION CO. 3-35/L-36 SDI ENDICOTT NORTH SLOPEmALASKA COMPUTATION DATE: 8-APR-87 PAGE 8 DATE OF SURVEY: 2-APR-87 KELLY BUSHING ELEV~ATION: 55.40 PT ENGINEER: SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATkS HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORIH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN 9099.16 7955.40 7900.00 46 28 9244.84 8055.40 8000.00 46 43 9391.01 8155.40 8100.00 47 2 9538.88 8255.40 8200.00 47 38 9688.02 8355.40 8300.00 48 9 9838.79 8455.40 8400.00 48 39 9989.32 8555.40 8500.00 47 56 10136.70 8655.40 8600.00 46 42 10280.96 8755.40 8700.00 45 26 10421.90 8855.40 8800.00 44 42 10564.14 8955.40 8900.00 46 4 10711.14 9055.40 9000.00 48 19 10864.89 9155.40 9100.00 50 5 11020,42 9255.40 9200.00 49 47 11175.07 9355.40 9300.00 49 39 11328.17 9455.40 9400.00 48 37 11477.87 9555.40 9500.00 47 33 11624.71 9655.40 9600.00 46 33 11768.34 9755.40 9700.00 45 1 11908.00 9855.40 9800.00 43 37 12044.73 9955.40 9900.00 42 11 12177.40 10055.40 10000.00 40 6 12307.53 10155.40 10100o00 39 57 12438.46 10255.40 10200.00 40 22 12568.93 10355.40 10300.00 39 47 12640.00 10410.01 10354.61 39 47 DEG MIN FEET DEG/IO0 FEET FEET PEET OEG MIN N 48 29 E 2978.56 N 48 10 E 3084.36 N 48 17 E 3190.83 N 48 37 E 3299.62 N 49 12 E 3410.16 N 50 19 E 3522.94 N 50 49 E 3635.45 N 50 46 E 3743.70 N 50 42 E 3847.66 N 50 29 E 3946.98 N 52 I E 4048.13 N 52 24 E 4155.85 N 53 52 E 4272.58 N 54 34 E 4391.52 N 55 19 E 4509.24 N 55 54 E 4624.83 N 56 42 E 4735.80 N 57 18 E 4842.80 N 58 12 E 4945.25 N 59 47 E 5041.87 N 60 45 E 5133.95 N 59 21 E 5220.11 N 58 40 E 5302.68 N 59 4 E 5386.46 N 59 34 E 5469.39 N 59 34 E 5514.39 0.62 0.33 0.79 0.26 0.61 0.54 0.62 1.11 1.25 0.89 1.15 2.19 1.03 0.61 0.43 0.91 0.51 0.91 1.12 0.67 1.84 1.78 0.72 0.40 0.00 0.00 1903.93 N 2291.12 E .2979.03 N 50 16 f 1974.31 N 2370.40 E 3084.92 N 50 12 E 2045.28 N 2449.97 E 3191.48 N 50 8 E 2117.57 N 2531.45 E 3300.35 N 50 5 E 2190.33 N 2614.81 E 3410.98 N 50 2 E 2263.26 N 2700.89 e 2523.80 N 50 2 F ~, 2334.58 N 2787.92 E 3636.31 N 50 3 } 2402.96 N 2871.84 E 3744.55 N SO 4 E 2468.74 N 2952.34 E 3848.5! N 50 5 E 2531.92 N 3028.99 E 3947.83 N 50 6 E 2595.17 N 3107.92 E 4048.96 N 50 8 E 2661.19 N 3193.06 ~ 4156.63 N 50 11 E 2731.49 N 3286.31 E 4273.27 N 50 16 E 2800.89 N 3383.11 E 4392.09 N 50 22 E 2868.55 N 3479.74 E 4509.68 N 50 29 E 2934.05 N 3575.3~ E 4625.15 N 50 37 E 2995.79 N 3668.11 E 47~6.01 N 50 45 E 3054.34 N 3758.30 E 4842.92 N 50 53 E 3109.44 N 3845.44 k 4945.30 N 51 2 E 3159.79 N 3928.91 E 5041.88 N 51 11 E 3205.94 N 4009.91 ~ 5133.95 N 51 21 E 3249.40 N 4085.50 E 5220.14 N 51 30 E 3292.63 N 4156.66 E 5302.76 N 51 36 E 3336.29 N 4229.04 f 5386.61 N 51 43 E 3378.84 N 4301.20 E 5469.64 N 51 50 E 3401.87 N 4340.42 E 5514.71 N 51 54 k STANDARD ALASKA PRODUCTION CO. 3-35/L-36 SDI ENDICOTT NORTH SLOPE,ALASKA MARKER COMPUTATION DATE: 8-APR-87 PAGE 9 DATE OF SURVEY: Z-APR-87 KELLY BUSHING ELEVATION: 55.40 PT ENGINEER: SARBER INTERPOLATED VALUES FOR CHOSEN HORIZONS MEASURED DEPTH BELOW KB SURFACE LOCATION AT ORIGIN: 2508 SNLt 680 WELT SEC 8t TllN~ R17E 'TVD RECTANGULAR COORDINATES FROM KB SUB-SEA NORTH/SOUTH EAST/WEST TOTAL DEPTH 125~0.00 10410.01 10354.61 3401.87 N 4340.42 E STANDARD ALASKA PRODUCTION CO. 3-35/L-$6 SDI ENDICOTT NORTH SLOPE,ALASKA COMPUTATION DATE: 8-APR-87 PAGE 10 DATE OF SURVEY: Z-APR-BZ KELLY BUSHING ELEVATION: $5°40 FT ENGINEER: SARBER ***~*~***~** STRATIGRAPHIC SUMMARY MARKER TOTAL DEPTH MEASURED DEPTH BELOW KB 12640.00 FROM KB 10410.01 SURFACE LOCATION AT ORIGIN: 2508 SNLs 680 WEL, SEC 8, TlIN, R17E TVD RECTANGULAR COORDINATES SUB-SEA NORTH/SOUTH EAST/WEST 1035~.61 3~01.87 N 4340.~2 E FINAL WELL LOCATION AT TO: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 12640.00 10410.01 10354.61 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG 5514.71 N 51 54 E SCHLUMBERGER O I RECT [ ONAL SURVEY COMPANY STANDARD ALASKA PRODUCTION CO HELL 3-35/L-36 SDI FIELD ENDICOTT COUNTRY USA RUN ONE DATE LOOOED 02-APR-87 REFERENCE F$ ! A. WELL' ~o SDI (2508' ~NL~'680' WEL, SEC 8, TllN, R17E) hORIZONTAL NORTM GO00 4000 ~0o0 ..-,-4-4-4-.4..4-.4-- .-4.-¢.4.-4.-4--4--.4-4-.- IO00 -1000 SOIJTH -2000 WEST WELL' 3-35/L-36 SDI (2508' SNL, 680' WEL, SEC 8, TllN, R17E) ..~{T I CAL PROJECT ~..,, -]000 0 0 I000 L~)O0 9000 4000 ~000 6000 7000 PROJECTION ON VERTICAL PLANE SI. - 291. SCALED IN VERTICAl_ OEPTHS HORIZ SCALE : l/ 1000 IN/FT SOHIO ALASKA PETROLEUM CO~ PAD. L (:54.4-II -17) L'36 Controlled Drilling Consultants, Inc. LES HENDERSON 333.1552 CONTROLLED DRILLING'CONSULTANTS, INC. 4234 KINGSTON DR. Anchorage, Alaska' 99504 (907) 333-1552 April 3, 1987 Hr. Brian Rose Standard Alaska Production Co. Pouch 6-612 Anchorage, AK 99502 RE: Magnetic Single Shot Survey Job No. 0287-028 Well L-36 (34-4-11-17) Endicott North Slope, Alaska Date of Survey February 28 to >Iarch 23, 19~7 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 calculating this survey was Radius of Curvature. The depth of the survey was 254.to 12006. Thank you for giving us this opportunity to be of service. Yours' very truly, Controlled Drilling Consultgqts, Inc. ~rry ~. Henderson Directional Supervisor TANDARD AL'""" ,. ...... Roi<.A PRODUCT I0~'4 AGNETIC SINGLE SHOT SURVEY RDiUS OF CURVATURE N~INEER T, HENDERSON OMPUTED FOR CDC BV OCEANTECH !,;ELL L --... :...,...: ,~, :..-:,~, 4,. 0 FT, SURVE",' OATE 02/':28,."87 P E 0 P 0 S E [." D l R N 5 ! - :'-: (: K TRUE iEAS, DRIFT VERTICAL iEPTH ANGLE DEPTH D M ~SSUMED VERTICRL TO 254 0 I5 254,00 ~80 O 45 499,99 t050 O: t5 t049,97 ~233 ~ ~5 12~2,9~ 198I t 4~ !979~95 2597 i I2 2595,72 2877 i 6 2875,66 3358 ~ ~6 3437 I ~8 ~435,49 '~'7~7 O 54 ~7~5,44 ~954 ~ ~8 4076 3 42 4074,27 S E R [:' i RE'C 'TOTAL 0 FT: -55 I98 44,,i, 625 809 994 1177,55 1236 ~47 1454,9~ t 579,7~ 1924,. 55 2433,35 254 O, 32 2820,, 2:~3 318i , ~8 ~66 O. O4 ~896,99 4018,8'7 54 71 74 77 80 :OHIO WELL KE: EL. E9 IEAS, DRIFT VED.'T]CRL DEPTH ANGLE DEPTH b M 4180 6 7,6 4264 7 48 4564 14 I2 4754 ~ 7 30 4847 ~8 3~ 4947 2 0 O 5040 22 O '5428 31 O $7~5 30 0 5808 40 t2 5904 ~.'2 30 -'59'98 45 ~2 ~444 ~4-6 42 '6635 47 48 693~ 48 36 ~024 49 O 73~2 45 5~ 7576 46 6 4t77 84 ~. ~.,,..~ 04 ~464 88 4555 ~4 4647' 08 4738 07 4S26,49 4920,87 5007,69 5097,96 5~84 52-724 ~ 7 5355 64 5435 27 55I ~ ~O 559i 9~ 5664 08 5736 i 4 59 (~3 93 5979 29 S~42, l t 6674,~3 6744,72 6979,48 · --, U~ SEA 4t2.2,44 4-205,78 4299,64 4409,48 4499,94 459t. SS 4682, 477i . 09 4865,47 4952.29 5 042,56 5~28.80 52~ 7.77 5300 5379, $7 5608,68 5748 592J, 89 6384,0 O ~445 6619, O~ 6824. %'.2:?SPF> O~ SURVEY r; f;~ T F T C, I P. EC 86 ~ 0 N ~' ~-' l~.'xO H i ,:47' i48,42 H 28,58 ........ :' 2 '~ f4 9 0 , 4,. 2E, I 28 N ~9, 288,,20 N 172. .... :,19.02 H 205, ~' ,242 .~.,;, O N 24 t , O 4 4~7,7'8 N 322-,9 ,4~;2' 80 N 367 8 0 H 4 6'4 .;~ ..:, ~ 07 H (517 O'~ 945 ~t N t f}::3'~ ,..,,¢,6I N it42,7, u .... o,67 o~ N i S4.8 ,. E E E E E E E E E E E ! 75, 200 69 i'4 19 '~ 41 297 74 ¢~o ?O "~"~ ~2 4'} ,:4o 4k2,,,o~ 529,~ N ..,, J..o,~ 2 ,,IbLL OHiO~'- TRUE IEAS, DRIFT VERTICRL )EPTH ANGLE DEPTH 7670 46 4~ 6944,25 7~52 46 48 7060,84 ~043 46 10 7200~19 ~4~ 46 ~ 7~70,79 0432 44 24 7472,9t 8705 900~ 45 24 9095 46 48 7946~f2 9~90 47 9464 47 48 8~ 96 , 52 9756 49 0 ~9,~9 0 , 68 10035 47 48 8575,07 10123 47 0 86:g4,6,4 10223 46 24 10404 44 48 8829,85 10504 45 42 8980,25 I0600 46 48 8966,64 ~0695 48 24 9030,69 10797 49 42 9097,54 . SEA 70t~,44 7t44, ?9 72i5.~9 7280092 74t7,5¢ 76ij. r ~ 54,59 7825,54 789 8,72 7955.45 8 074,24 8i4~,~2 8~72,58 85t 9, ~7 8579,24 8647,82 8774 , 45 $844.85 89 i 1 ,, 24 '~ 042, I4 9 ~ 56, ~4 N 0 A - 0 ;2 :.::, =' -- 0 ;28 S:::B Ei..E~;: 55 40 8?' ,..,' ,", ! F 7 C'EO, T- '-" ='~ . .TE LiTAL L. OU,~,D I,NA S 1...b': 85 [4 14,5i r.&.~ N '~5i0 09 N !649 4~ N '~ 695,35 S i 779', 99 N 1877. i 5 N i 921 , 78 N .T, 015 7 O N ~:3 i 03 99 N '? ~x 01 50 N 2438,64 N 2660, i4 N ~703,92 N )~.ao 40 2880, 1.~ N 1976,69 N 49 "' Oq. '"'" H 4 ,-.~ ! .. , 22417,, O0 H 4? 232i 2525, t9 N 49 ;27i 4,76 N 2786,20 N 48 295~,00 N 49 292'1,42 ~¢ 48 2989,09 N 40 3 ~,, 8, .., ~477,99 36il ,g~6 N 40 ot..:,~ 12 H 4025,22 N 49 4094,'~i N .4,8 4164 424~,60 N 48 4377,78 N 4S TRUE ~EAS, DRIFT VERTICAL )EPTH ANGLE DEPTH D M SEA [:' '~ P-E C TOTAL. COORC: l ::"4ATES !1264 49 36 '.9397 II~60 48 30 9460 ;!460 48 0 952;;' II7~8 45 24 97~7 ! I 069 49 54 92.72 07 ':'.'121 6,67 .."-."$S , 6 {:':'.{[ 2923,3i '}q 3754 06 9~8'~ ,."B6 ;"~.53:.'3(iE 2969,35 N 34'iS,87 74 9342 34 65 9405,25 O 5 'B 527, '" = I103~ 44 ~6 9784,~5 9720,95 {,~5',::',25E 3249.,65 N 38!7,47 11943 4'3 24 986~,,47 9eoe,07 i,458,ooE ~29,,.~,08 N 388~ file FOLLOWING IS EXTRAPOLATED 12086 4~ 24 9909,25 '9853,85 BOTTO~ HOLE CLOSURE ~13't ,64 FEE'/ A'T H 49 47 50 E C L 0 S U ',~ a .~ STANCE A?..iGLiZ % ?.! ':: 4670 4744 4806 487S 4946 60i~ 5088 .688 ,.606 , :,,~{, 79 ,917 IEA::;LR~D DEPTH Pt, t:)OTHEE' i:;*ATH F:OF--: ': :-'" :: :~ :,' '~'~...~:'~-' ~On CEET OF SUB SEA DEPTH TRUE MEASURED VERT I F':.¢,~.., .._. SUB I'"i D.-- -'' ~''''. , , ,. '~:'D T I CF:L,, :_,,. DEPTH DEPTH Ac 0 0 -.55 255 25.5, '2 0 0 ~55 J55, 30 O 455 455. 4 555 55.5. 50 O "=~ 655 ~E, n O 755 755, 700 95~, 855. 900 955 955, 9 O O I 055 i 055, I OOO 1255 1255, 1200 135~ I ~5... i ~80 1456 J455, 1400 2056 2055, 2008 2t57 2155, 2I 08 2257 2255, 2208 2357 235~ 2457 2455, 24 O 0 ~557 255~, 25 O O 2657 2655 .. 2~ 00 2757 2755, 27 O 8 ~,, r 2855, 28 00 2957 ~955, 29 O 0 ~]57 3~)5 .... 3080 3157 3155, 3~ OO 3257 3255, 32 O 0 ~457 3455 C 0 i'i ? L! T' G; ? -- tEASURED DEPTN ANC, I'!ERoURED DEPTH 3557 3657 3757 3857 7957 4 057 4157 4258 435.9. 446.'I 4564 466,9 4772 4984 5892 520~ 5428 5546 5669 5797 Dg~O 62~5 6955 754~ OTHER DA'f~ ............. b ...... . SUG'. :_4~,'40EPTH TRUE VERTICAL OEPTH VERTICAL CORRECTION T.OTAL C:OO RD i !',i~ TES 3555, 3'5 O 8 3755 "'" ~ ' ~85~ ~8u8 3a=~ 3~OO 4055, 4 O O 8 4155, 4 t 08 4255, 4200 ~55 . .,~OO 4455, 44O0 4555, 450 O 4655 4600 4755, 4;?00 5 055, 5 O 0 O 5~55~ 5'! O0 5455, 54 O 0 57~5, ~ ' 6355 ~ '~ , o,~ 0 O 6455, ~408 0 0 O ~9,93 i 76 ~2 O 85,55 i '** 73 2 ii 4 I50,21 4 '(7'~ 56 9 248.8~ 9 27~ 9 i 12 312,60 i 5 35 O, 22 i ~ SgO 88 23 4S5.~ 54 28 484, ~5 46 7~ 5,01 4 E, 774, ~ ~x 48 834,48 S O 894,71 52 i 018, i5 47 i 084,51 4~ '~ i 52~ 85 44 'i 22 i, 18 4S 1290,47 H N N N N N N N iEAsUREC DEPT~ AN[:, OTHER TRUE HEASURED : ;c-,', " VER T i C g. L. ~,,.~T iCAL SU6 fib DEPTH DEPTH S~::F~ L~, ~-:~.~.~: ............... l~J ~i_ 7832 7055, 7000 ',:" 7 E, 46 ~ .36 0.47 "'"' "' ' , ;?;22 , ,, ~,,'~ 7155 71 O0 46 8123 7255, 72 0 O :ii: E, 7' 45 '; 5 00, i 7 8266 7J55 7E~ 0 O S:; -'~ "'" '~ " , ". ~.~ 84 07 7455, 7400 ??52 42 8547 7==~ '::'q * 39 ~,.., ... 7500 ~ 6 S 6. 7655, 7 E, 0 O ';, f'* ..... S O ee25 7755, 7700 i os9 59 t s:'37', oo 9i 09 7955 7900 ~ i'~' 9256 8055, SOOO I ,:2 C,~O 9403 8155 8i O0 i pz':' 47 9552 8255, ~o . *. ' , . 9854 ~ ~ ~':~ 52 ":"'~ · 5;:> 0006 8~=5, ~ ~ 4 5~ , 8~08 ~ bO 2424 45 0153 8655, ~{~OO ~ 497 a~98 875S 8700 I ~=;42 O.~.. , 9 0 0 O , (; 4 88e7 9~55 9i ¢0 ~ 77 =~ ..... ,., . , '.::, ~ agaa, 4'2 ! 1649 9655, 9~88 ~ 99.::, I 1792 9755 97 O 0 '* .... ; ' ''~ ~OHIO 5.1ELL L .... 36 ~. NTERPOL ¢~ TEE:: NECiSLtRED [.~EF'TH 0 ~OOO ,~ 00 O 4000 500.0 6000 70(I 0 8 00 O 9000 00 O 0 ttOOO ~2000 TRUE "v"E R T I DEP, h 1006, 1999, 2999, 497 0 .. 5805,. 6485, 7'171. 855'2, 9905: 9909~ :E: 6; ¢:~ 'T ..-',': "i' ;:, L :C 00 R C, l; i'-i ¢~ T E S: ! HORIZONTAL VIEW i ~STANDARD ALASKA PRODUCTION CO. WELL L-36 ' i - . - RADIUS OF CURVATURE ~ ~ . -~-- - MA~IE-T-IC StNGLE-~tOT ,-- - - ~ ...... 4--.-~-.-:.* : - - ' [ ; . . ' ........... : ---~ ' ' . SCALE:I~'=1000': ; .... I i ....... ; .......... '~ - ; .... MARCH 6, t987 ...... : · ' L ;_:_ ..................... ~ ...... : ........ :.' .-- .:4, ' ' ' ' '. .... ~. .... :--4~: ;--.[ ~ : II . ~: !- - .!-'_:_:' __-:_.~;:-;| .., :-'- - ' . ' -' -.;:_ ::-- : '::;:;:- :..:;'::-:5'-:'~ ....... , _ t ! ':: :'::';' ': ' i'i ! _. . . Standard AIo~o PO ~ 19~12 Anchorage, Alaska ~519-~12 (~7) 561-511 ~ March 3, 1988 STANDARD ALASKA PRODUCTION John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Boyle: The following cased log information for Endicott wells is enclosed: 1 sepia and 1 bluellne print for: 3-49/j-40 Run 1 February 1. 1988 * SPINNER 3-33/K-37 Run 1 January 26, 1988 * FLCWMETER 3-35/L-36 Run 1 January 30, 1988 * TEMPERATURE * CONTINUOUS FLOWMETER 1-29/M-25 Run 2 February 3, 1988 * DUAL SPACING TDT * SPINNER (Run 1, t-31-88) 3-27/M-3~ January 17, 1988 * SPIMNER Standard Ala ska~ Production Con 900 East Benson ,levard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 AUG 31, 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: L-36 Run 1 August 15, 1987 * GR Positio]~ing Log Received by Da t e ~/' Alaska 0il & G~s Cons. Commission Anchorage A unit of the or,gmol Standard O;I Company Founded in Cleveland Ohio in 1870. Standard Alaska Production Compar,. 900 East Benson Boulevard P.O, Box 196612 Anchorage, Alaska 99.519-6612 (907) 564-511 I APR 6, 1987 STANDARD ALASKA PRODUCTION William Van Alen Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Van Alert: The following log information for Endicott wells: 1 sepia and 1 blueline print for: 0-29 Run 2 March 24, 1987 * HP Gradient Log,// J-22 Run 1 March 25, 1987 * DLL/MSFL J * CNL.J March 29, 1987 * CBT * CBT L-36 Run 1 March 26, 1987 * DLL/MSFL~' Oil & Gas Cons. //~'Bruce St. Pierre Received by A u-H of lhe original Standard Oil Co,'npony Founded in Cleveland. Ohio. in 1870 Standard Alaska Production Compan~ 900 East Benson Boulevard P.O. Box 196612 Anchorage, AIoska 99519-6612 (907) 564-51 I 1 APR 6, 1987 STANDARD ALASKA PRODLJCTION William Van Alen Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Amchorage, Alaska 99501 Dear Mr. Van Alen: The following log information for Endicott wells: 1 sepia and 1 blueline print for: L-36 Run 1 April 2, 1987 * CNL~/~ * CBT~/ * CET J-22 Run 1 April 2, 1987 March 29, 1987 * GCT ~-- * CBT * CET K-37 Run 1 April 2, 1987 * CET~- P-27 (Gearhart) Run 1 February 25, 1987 * CNL .- A unit of the or,ginal Standard Oil Company Founded in Clevelond~ Ohio, in 1870 Standard Alaska Production Company 900 East Benson Boulev, P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 564-5111 STANDARD ALASKA PRODUCTION APR 24, 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: ! gcpia ~rint and ! b!ua!inc ~rint,~cr:, Magnetic tapes and listings for: Run 1 March 26, 1987 * EDIT LIS (Unshifted) * EDIT LIS (Shifted) (~ska 0it & Gas Cons, Commission Anchorage Sincerely, /// / Bruce St. Pierre Received by ^ ., .~ ,b~ _~:~:~ c,~_~.,~ r'-.:~ Company Date in Cleveland, Ohio, in 1870. ~' STATE OF ALASKA ALAS. OIL AND GAS CONSERVATION COMM,SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well F_~ Alter casing I'l Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order El Perforate t ] Other 2. Nameof Operator 5. Datum elevation (DF or KB) Standard Alaska Production Company KBE = 55.40 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 2508' SNL, 680° WEL, Sec. 8, TllN, R17E At top of productive interval 4529' SNL, 1835' WEL, Sec. 4, TllN, R17E At effective depth At total depth 4386' SNL, 1620' WEL, Sec. 4, TllN, R17E 7. Well number 3-35/L-36 SDI 8. Permit number 87-20 9. APl number 50-.029-21701 10. Pool E~dicott Pool 11. Present well condition summary Total depth: measured true vertical 12640 feet 10410 feet Plugs (measured) Effective depth: measured true vertical feet feet Junk (measured) Casing Length Structural Conductor 30 ' Surface 2503 ' Intermediate 11989 ' Production 903' Liner Perforation depth: measured true vertical Tubing (size, grade and measured depth) 1 Jt 4-1/2" 12.6# L-80 TDS Packers and SSSV (type and measured depth) None Size Cemented Measured depth Structural Drive Pipe 13-3/8" 3720 cu.ft. Permafrost 9-5/8" 575 cu.ft. Class G 161' 2503' 11989' 7" 315 cu.ft. Class G 12640' True Vertical depth 161' 2503' 9841' 10410' RECEIVED Alaska 0il & 6as Cons. 60mmissior~ Anch0race 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch 13. Estimated date for commencing operation July 1987 14. If proposal was verbally approved Name of approver Date approved 15. I her~,b~/certify Signed j(_, ~--~, that the foregoing is true and correct to the best of my knowledge ~~ TitleDivision Drillinq Enqineer Commission Use Only Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Commissioner Approved by ~ ~"~ ~° ~] Form 10-403 Rev 12-1-85 Approval No. 7- the commission Date / "%,. Submit in triplicate WELL 3-35/L-36 ($DI) Permit Number: 87-20 Approval Date: 2-27-87 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 CNL GCT, CBT, CET, DLL/MSFL in 7" liner and gyroscopic survey from PBTD to surface and downsqueeze the 13-3/8" x 9-5/8" annulus with 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. k sub surface safety valve will be installed below base of permafrost. Install and test tree. Release rig. JGV/pm/1730D SAPC Daily Drilling Report -- ENDICOTT March 2, 1987 at 0600 hours Rig' PAA #7 Well' 3-35/L-36 (SDI) AFE # 717528 API 50-029-21701 0600 Depth' 229' Day- -1 24-Hour Ftg- ll9' Current Operation- Drilling. Accept rig at 2400 hrs. on 3/1/87. Spud well at 0400 hrs. on 3/2/87. Drill 17-1/2" hole to 229 ft. MUD TYPE-Spud mud WT'8.7 VIS-300 PV- yp- FL- SOLIDS- TEMP-°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1517h- SAPC Daily Drilling Report -- ENDICOTT March 3, 1987 at 0600 hours Rig: PAA #7 Well' 3-35/L-36 (SDI) AFE # 717528 API 50-029-21701 0600 Depth: 1511' Day: 1 24-Hour Ftg: 1282' Current Operation' Drilling. Drill 17-1/2" hole to 1243 ft. Trip bit. Drill to 1511 ft. MUD TYPE-Spud mud WT-8.9 VIS'200 PV-15 YP:45 FL' SOLIDS'8 TEMP'57°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES 1 51 7h' DLS SAPC. Daily Drilling Report -- ENDICOTT March 4, 1987 at 0600 hours Rig' PAA //7 Well- 3-35/L-36 (SDI) AFE # 717528 API 50-029-21701 0600 Depth' 2520' Day' 2 24-Hour Ftg- 1238' Current Operation' Cementing 13-3/8" casing. Drill 17-1/2" hole to 2520 ft. Short trip. Circulate. RUn 13-3/8" casing, shoe at 2503 ft. Mix and pump cement. MUD TYPE- WT:9.7 VIS:166 PV:IO YP-58 FL- SOLIDS:lO TEMP:67°F POH. SURVEY "~ MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1517h' SAP(i Daily Drilling Report -- EtJDICOTT March 5, 1987 at 0600 hnurs Rig' PAA #7 Well' 3-35/L-36 (SDI) AFE # 717528 API 50-029-21 701 0600 Depth' 7520' Day- 3 24-Hour Ftg' ' Current Operation' POH. Cement 13-3/8" casing. POH. N/D riser. Install starting head. N/U BOP's and test same. RIH and tag cement at 2227 ft. Test casing to 3000 psi. Stripped threads on double pin niDple of starting head. P/U BOP. POH. MUD TYPE-Gel WT:8.6 VIS-52 PV-14 YP'12 FL- SOLIDS' TEMP' °F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1517h- SAPC Daily Drilling Report -- ENDICOTT March 6, 1987 at 0600 hours Rig' PAA #7 Well' 3-35/L-36 (SDI) AFE # 717528 API 50-029-21701 0600 Depth' 3760' Day' 4 24-Hour Ftg' 1240' Current Operation' Drilling. POH. Remove starting head from BOP. Cut 5" off 13-3/8" nipple. InStall and weld slip-on starting head. N/U BOP. RIH. Test casing, to 3000 psi - OK. Drill cement from 2227'. Drill out float and shoe. Conduct FIT to 12.2 ppg EMW. Drill 12-1/4" hole to 3760 ft. MUD TYPE-Gel WT-9.3 VIS'40 PV-6 YP:ll FL'lB.6 SOLIDS'5 TEMP'68°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1 51 7h' SAPC Daily Drilling Report -- ENDICOTT March 7, 1987 at 0600 hours Rig' PAA #7 Well' 3-35/L-36 ISDI) AFE # 717528 API 50-029-2170! 0600 Depth- 4550' Day- 5 24-Hour Ftg' 790' Current Operation' Drilling. Drill and survey 12-1/4" hole to 4000 ft. POH. RIH w/dynadrill. Dynadrill to 4465 ft. Trip BHA. Drill to 4550 ft. ' MUD TYPE-Gel WT'9.3 VIS:35 PV:7 YP-5 FL'14.2 SOLIDS'5 TEMP'72°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 18 3717 22 4264 0.9 N32.6E 3715 5.77 N61.67 ~/41.69 7.8 N45.9E 4261 33.37 ~86.25 ~25.97 1.63 1517h' SAPC Daily Drilling Report -- ENDICOTT March 8, 1987 at 0600 hours Rig: PAA #7 Well: 3-35/L-36 ISDI) AFE # 717528 API 50-029-21701 0600 Depth: 6049' Day: 6 24-Hour Ftg: 1499' Current Operation- Ttrippi~ng~ Drill and survey 12-1/4" hole to 6049 ft. Trip bit. MUD TYPE-Gel-CLS WT:9.6 VIS:40 PV:9 YP:7 FL:ll.4 SOLIDS:7 TEMP:86°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 27 4754 1 7.5 N43.5E 4738 142 ~d168 ~ 47 · 36 5621 35.9 NS1.2E 5517 51 3 ed 41 8 ~ 323 40 5998 45.8 N54.7E 5804 757 ~S 565 ~E 51 7 1517h: Rig: PAA #7 Well: 3-35/L-36 (SDI) SAP¢ Daily Drilling Report -- ENDICOTT March 9, 1987 at 0600 hours AFE # 717528 API 50-029-21 701 0600 Depth: 7087' Day: 7 24-Hour Ftg: 1038' Current Operation:-RIH w/dynadrtll. RIH. Drill and survey 12-1/4" hole w/dynadri 11. MUD TYPE-Gel-CLS WT:9.2 VIS:38 PV:6 YP:6 FL:lO.6 to 7087 ft. SOL I DS: 8 POH. RIH TEMP:84°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 42 6635 47.8 N57.2E 6242 45 7024 49.0 N57.5E 6501 1218 Id 827 6898 O. 79 1507 ~ 984 ~ 1143 O. 46 1517h: SAPC Daily Drilling P. eport -- ENDIC. OTT March 10, 19F~7 at 0600 hours Rig: PAA //7 Well: 3-35/L-36 ISDI) AFE # 717528 API 50-029-21701 0600 Depth: 7760' Day: 8 24-Hour Ftg: 673' Current Operation' Drilling. RIH. Dynadrill 12-1/4" hole to 7240 ft. POH. RIH w/bit. Drill to 7760 ft. MUD TYPE-Gel-CLS WT:9.6 VIS:38 PV:7 YP:6 FL:8 SOLIDS:7 TEMP:84°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS ., 47 7382 45.9 N48.7E 6745 1768 49 7670 46.8 N~8.7E 6944 1976 146 ~ 1348. 283 e~ 1505 0.27 0.43 1517h: SAPC Daily Drilling Report -- ENDICOTT March ll, 1987 at 0600 hours Ri g: PAA #7 Well: 3-35/L-36 (SDI) AFE # 717528 API 50-029-21701 Current Operation- Drilling. Drill and 8650 ft. 0600 Depth.' 8650' Day: 9 24-Hour Ftg: 799' survey 12-1/4" hole to 7851 ft. Trip bit. Dri 11 to' MUD TYPE-Gel-CLS WT:9.7 VIS:38 PV:7 YP:7 FL:6.2 SOLIDS:8 TEMP:°F SURVEY ND ANGLE DIRECTION TVD SECTION COORDINATES DLS 51 8043 46,3 N48E 7199 2247 53 8239 45.5 N47E 7335 2388 55 8528 44 N46E 7541 2590 462 557 686 708 ~1812 961 1 51 7h: SAPC Daily Drilling P, eport -- ENDICOTT March 12, 1987 at 0600 hours Rig: PAA #7 Well: 3-35/L-36 (SDI) AFE # 71 7528 API 50-029-91701 0600 Depth.' 9000' Day: 10 24-Hour Ftg: 250' Current Operation: Drilling. Drill 12-1/4" hole to 8652 and Survey to 9000 ft. ft. POH. Test BOPE. RIH. Drill MUD TYPE-Gel -CLS WT:9.6 VIS:39 PV:16 YP:8 FL:6.6 SOLIDS:7 TEMP:°F SURVEY )~ ANGLE DIRECTION TVD SECTION COORDINATES DLS 56 8705 43.9 N46.6E 7668 57 8808 44.1 N47.9E 7742 2713 278a 780 ~ 2050 829 L~ 2102 1 5! 7h: SAPC, Daily Drillinq Report -- F. NDICOTT March 13, 1987 at 0600 hours Rig: PAA #7 Well- 3-35/L-36 (SDI) AFE # 717528 API 50-029-21701 0600 Depth' 9~66' Day' 11 24-Hour Ftg' 266' Current Operation' POH. Drill and survey 12-1/4" hole to 9266 ft. Lost pump pressure. POH. Lost 3 cones and 1 extended nozzle. P/U RCJB. RIH and workover cones. POH. MUD TYPE-Gel-CLS WT-9.7 VIS:43 PV'14 YP-8 FL-6.4 SOLIDS-8 TEMP'°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES 59 9001 45.4 N46.5E 7880 291 9 61 9190 47.3 N46.6E 8010 3056 ~Y1922 ~2201 1~/2016 ~ 2300 DLS 1 51 7h' SAP{] Daily Drilling Report -- ENDICOTT March 14, 1987 at 0600 hours Rig: PAA #7 Well: 3-35/L-36 (SDI) AFE # 71 7528 API 50-029-21701 0600 Depth: 9275' Day: 12 24-Hour Ftg: 9' Current Operation: RIH.. POH. Recovered 1 cone. RIH w/RCJB. Work over cones. POH. Recovered 2 cones. RIH w/bit and junk sub. Drill junk from 9262-9275 ft. POH. RIF! w/bit. MUD TYP£-Gel-CLS WT:9.8 VIS:38 PV:13 YP:6 FL:6.4 SOLIDS:9 TEMP:80°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1 51 7h: Rig: PAA #7 Well: 3-35/L-36 !SDI) SAPC, Daily Drilling Report -- EI~P. IC, OTT March 15, 1987 at 0600 hours AFE # 71 7528 API 50-029-21701 0600 Depth: 9715' Day: 13 ~4-Hour Ftg: 440' Current Operation: Drilling. RIH. Drill and survey 12-1/4" hole to 9715 ft. MUD TYPE-Gel-CLS WT:9.7 VIS:39 PV:ll YP:9 FL:6.6 SOLIDS:9 TEMP:94°F SURVEY MD ANGLE DIRECTION TVD SECTION 63 9464 47.8 N47E 8196 3256 64 9569 48.2 N47.3E 8266 3334 COORDINATES 2154 ~ 2447 ~/2207 ~ 2504 DLS 1517h: Rig: Well: PAA #7 3-35/L-36 ( SD I ) AP I SAPC Dai 1.v Drilling March 16, 1987 Report-- ENDICOTT at 0600 hours AFE # 717528 50-029-21 701 Current Operation: Drilling. Drill and 9910 ft. 0600 Depth: 9910' Day: 14 24-Hour Ftg: 195' survey 12-1/4" hole to 9876 ft. Trip bit. Drill to MUD TYPE-Gel WT:9.8 VIS:43 PV:14 YP:12 FL:6.2 SOLIDS:lO TEMP: °F SURVEY MD ANGLE DIRECTION TVD SECTION 66 9758 49 N48.4E 8390 3474 COORDINATES /¥2302 ~ 2608 1 51 7h: DLS Rig: PAA #7 Well: 3-35/L-36 (SDI) SAPC Daily Drilling Report -- ENDICOTT March 17, 1987 at 0600 hours AFE # 717528 API 50-029-21 701 0600 Depth: 10,250' Day: 15 24-Hour Ftg: 340' Current Operation: Drilling. Drill and survey 12-1/4" hole to 10,250 ft. MUD TYPE-Gel-CLS WT:9.7 VIS:37 PV:ll YP:7 FL:6.4 SOLIDS:9 TEMP:g8°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES 68 10035 42.8 N49.4~ 8574 3683 ': ~'-~':~ 69 10123' 47:0 N49,1E 8634 '~ '3748 N2439 4'-2766 2481 l~"281 5 DLS 1 517h: SAPC Daily Drilling Report -- ENDICOTT March 18, 1987 at 0600 hours Rig' PAA //7 Well: 3-35/L-36 (SDI) AFE // 717528 API 50-029-21701 0600 Depth: 10,400' Day: 16 24-Hour Ftg: 150' Current Operation: Drilling. Drill and survey 12-1/4" hole to 10.366 ft. POH. Test BOP's. RIH. Drill to 10,400 ft. MUD TYPE-Ligno Sal WT'9.9 VIS:40 PV:14 YP:IO FL'lO SOLIDS'lO TEMP'IOO°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS i 70 10,223 46,4 N48.7E 8702 3820 2529 1517h: 2870 Ri g: PAA #7 Well: 3- 35/L-36 ISDI) SAPC Daily Drilling Report -- ENDICOTT March 19, 1987 at 0600 hours AFE # 717528 API 50-029-21701 Current Operation: 'Drilling. Dri 11 0600 Depth: 10,735' Day: 17 24-Hour Ftg: 335' and survey 12-1/4" hole to 10,735 ft. MUD TYPE-Ligno-Sol WT:IO/O VIS:38 PV:15 YP:9 FL:5.6 SOLIDS:Il 'TEMP: 106°F SURVEY MD ANGLE DIRECTION TVD SECTION 72 10504 45.7 NSO. 5E 8899 4021 73 10600 46.8 NS1.2E 8966 4090 COORDI NATES I0 2660 /,/2704 t~3021 ~3075 1 51 7h: DLS 1.56 1.26 Rig: PAA #7 Well- 3-35/L-36 ISDI) SAPC Daily Drilling Report -- ENDICOTT March 20, 1987 at 0600 hours AFE # 717528 API 50-029-21701 0600 Depth' 10,935' Day' 18 24-Hour Ftg- 200' Current Operation' Drilling 12-1/4" hole. Drilling; trip for bit; drilling. MUD TYPE-Ligno Sol WT:IO.O VIS:40 PV-15 YP-IO FL-5.6 SOLIDS'Il TEMP- 109°F SURVEY MD ANGLE DIRECTION TVD 74 10695 48.4 NSO. 1E 9030 75 10797 49.7 Ns1.gE 9097 SECTION 4160 4237 COORDINATES N2749 N2797 E3129 E3189 1 517h' DLS 1.88 1.84 Rig: PAA #7 Well: 3-35/L-36 (SDI) SAPC Daily Drilling Report -- ENDICOTT March 21, 1987 at 0600 hours AFE # 717528 API 50-029-21 701 0600 Depth: 11,305' Day: 19 24-Hour Ftg: 370' Current Operation: Drilling. Drill and survey 12-1/4" hole to 11,306 ft. MUD TYPE-Ligno-Sul WT:IO.2 VIS:40 PV:12 YP:IO FL:6.2 SOLIDS TEMP:IO6°F SURVEY MD ANGLE DIRECTION TVD SECTION 77 11069 49.9 ..... 78 -- 11170'~'~50.0 N53.6E 9271 4446 N53.3E 9336 4523 COORDINATES ~2924 ~v2970 23355 c~'3417 1 51 7h: DLS .... 0.78 0.25 Rig- PAA #7 Well' 3-35/L-36 ISDI) SAPC Daily Drilling Report -- ENDICOTT March 22, 1987 at 0600 hours AFE # 71 7528 API 50-029-21 701 0600 Depth' 11,551' Day- 20 24-Hour Ftg- 246' Current Operation' RIH. Drill and survey 12-1/4" hole to 11,551 ft. Trip bit. MUD T~PE-Ligno-Sul WT:IO.2 VIS:46 PV:16 YP-12 FL:5.8 SOLIDS-12 TEMP- 11 2°F SURVEY MD ANGLE DIRECTION TVD SECTION 80 11360 48.5 N54.7E 9460 4667 .... 81 11460 ~48,0 N55.1E 9526 4742 COORDINATES A/3056 ~ 3533 3099 ~ 3594 1 51 7h- DLS 2.01 O. 58 SAPC Daily Drilling Report -- ENDICOTT March 23, 1987 at 0600 hours Rig- PAA #7 Well: 3-35/L-36 (SDI) AFE # 717528 API 50-029-21 701 0600 Depth: 12,006' Day: 21 24-Hour Ftg: 455' Current Operation: Prepare to POH. Drill and survey 12-l/4" hole to 12,006 ft. CBU. MUD TYPE-Ligno-Sul WT:IO.2 VIS-39 PV:IO YP'8 FL-6 SOLIDS:12 TEMP'IO8°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 82 11543 47.5 -~,~ 84 ..... 11738 45j4~ 86 11943 43.4 N55.4E 9582 4803 N56.5E 9716 4944 N 58.9E 9863 5087 31 34 ~- 3644 .66 3213 ~-~-3761 1.37 3290 ~.f 3882 1.53 1517h: Rig: PAA #7 Well: 3-35/L-36 (sDI) SAPC API Daily Drilling Report -- ENDICOTT March 24, 1987 at 0600 hours AFE # 717528 50-029-21 701 Current Operation: Circulate and POH to shoe. Circulate and 0600 Depth: 12,006' Day: 22 24-Hour Ftg: ' condition mud. Replace over-riding condition mud. clutch. MUD TYPE-Ligno-Sul WT:IO.3 VIS:52 PV:19 YP:IO FL:5.8 RIH to SOLIDS:!4 bottom. TEMP:92°F SURVEY MD ANGLE DIRECTION TVD SECTION ,., COORDINATES DLS 1 51 7h: Rig: PAA #7 Well: 3-35/L-36 (SDI) SAPC Daily Drilling Report -- EHDICOTT March 25, 1987 at 0600 hours AFE # 71 7528 API 50-029-21701 0600 Depth: 12,006' Day: 23 24-Hour Ftg: ' Current Operation: N/U tubing spool. Short trip. POH. Run 9-5/8" casing. Shoe at 11,989 ft. Mix and pump cement. Install pack-off. N/D BOP. Install tubing spool. MUD TYPE-Ligno-Sul WT:IO.4 VIS:50 PV:16 YP:12 FL:6 SOLIDS: TEMP: °F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1517h: SAPC Daily Drilling Report -- ENDICOTT March 26, 1987 at 0600 hours Rig: PAA #7 Well: 3-35/L-36 ISDI) AFE # 717528 API 50-029-21701 0600 Depth: 12,400' Day: 24 24-Hour Ftg: 394' Current Operation: Drilling. N/U tubing spool and BOP's. Test pack-off to 3000 psi. Test BOP's. RIH to FC. Drill FC and cement. Test casing to 3000 psi. Drill FS and l0 ft. of new hole. Perform FIT. Drill 8-1/2" hole to 12,400 ft. MUD TYPE-Ligno-Sul WT:9.9 VIS:37 PV:IO YP:8 FL:6.8 SOLIDS:9 TEMP:92°F SURVEY MD ANGLE DIRECTION' TVD SECTION COORDINATES DLS 1517h: SAPC Daily Drilling Report -- ENDIC(3TT March 27, 1987 at 0600 hours Rig: PAA #7 Well: 3-35/L-36 (SDI) AFE # 717528 API 50-029-21701 0600 Depth: 12,643' Day: 25 24-Hour Ftg: 243' Current Operation: POH for logs. Drill 8-1/2" hole to 12,543 ft. Trip bit. Drill to 12,643 ft. POH to shoe. Rig repairs, RIH to bottom. CBU. POH to run open hole logs. MUD TYPE-Ligno-Sul WT:9.9 VIS:37 PV.IO YP-7 FL-5.9 SOLIDS:9 TEMP:96°F SURVEY MI) ANGLE DIRECTION TVD SECTION COORDINATES DLS 1517h: SAPC Daily Drilling Report -- ENDICOTT March 28, 1987 at 0600 hours Rig' PAA #7 Well' 3-35/L-36 (SDI) AFE # 717528 API 50-029-21701 0600 Depth' 12,640' Day' 26 24-Hour Ftg' ' current Operation- Open hole logging~ POH. Run open hole logs. Couldn't get deeper than 12,157 ft. R/D Schlumbergerj Wiper trip to bottom. Run open hole logs. MUD TYPE-Ligno-Sul WT'IO VIS:40 PV:13 YP-9 FL'5.7 SOLIDS:lO TEMP:96°F SURVEY ~ ANGLE DIRECTION TVD SECTION COORDINATES DLS 1517h' SAPC Daily Drilling Report -- ENDICOTT March 29, 1987 at 0600 hours Rig: PAA #7 Well: 3-35/L-36 ISDI) AFE # 717528 API 50-029-21701 0600 Pepth: 12,640' Day: 27 ! 24-Hour Ftg: Current Operation: Ci rcul ate/reci procare 1 i ner. Unable to run logs past 12,159 ft. R/D Schlumberger. Wi per trip' Run 7" liner. Circulate prior to cementing. Shoe at 12,640 ft; hanger at 11,737 ft. MUD TYPE-Ligno-Sul WT:IO VIS:39 PV:14 YP:8 FL:5.6 SOLIDS:lO TEMP:96°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1517h: SAPC Daily Drilling Report -- ENDICOTT March 30, 1987 at 0600 hours Rig' PAA #7 Well' 3-35/L-36 (SDI) AFE # 717528 API 50-029-21701 0600 Depth: 12,640' Day' 28 24-Hour Ftg' ' Current Operation' RIH~ Circulate and reciprocate liner. Mix and pump cement. Release liner and POH tools, RIH w/ 8-1/2" clean-out assy. Tag cement at 11,530 ft. Drill cement to liner top. POH. RIH w/ 6" cl ean-out assy.. MUD TYPE-Ligno-Sul WT'lOjl VIS:40 PV:13 YP-7 FL'6 SOLIDS:Il TEMP'82°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1517h' SAPC llaily Drilling Report -- ENF)ICOTT March 31, 1987 at 0600 hours Rig: PAA #7 Well' 3-35/L-36 (SDI) AFE # 717528 API 50-029-21701 0600 Depth' 12,548' Day' 29 24-Hour Ftg' ' Current Operation' POH L/D drillpipe. Test liner lap to 3000 psi - OK. RIH. Drill LC and cement to FC. Displace well to 9.6 ppg NaC1. Test liner to 3000 psi - OK. POH. MUD TYPE-Brine WT' 9.6 VIS' PV- YP- FL' SOLIDS' TEMP' SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 1517h' Rig: PAA #7 Well: 3-35/L-36 (SDI) SAPC Daily Drilling Report -- ENDICOTT April l, 1987 at 0600 hours AFE # 717528 API 50-029-21701 Current Operation- 0600 Depth: 12,548' Day: 30 24-Hour Ftg: ' POH. Run tubing hanger with 1 joint 4-1/2" tubing. N/U and test.tree to 5000 psi. Fill tree w/diesel. Release rig at 1700 hrs. on 3/31/87. Move rig to 3-21/L-34. MUD TYPE- WT: VIS: PV: YP: FL: SOLIDS: TEMP: °F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES 'DLS 1517h: Standard Alaska Production Company 900 Eost Benson Boulevara P.O. Box 196612 Anchorage, Alaska 99519-6612 /907) 561-51! 1 April 3, 1987 Mr. Lonnle Smith Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Duck Island Unit/Endicott Wells STANDARD ALASKA ~RODUCTIC;~bl 0C~,,,',,,i M .... :.Z ", ~.'-t::(" I "' ,1 · We are requesting that the AOGCC adopt dual designation for all futureJ~.~" ¢...-,¢(-,.' ~ll well n~es in the Duck Island/Endicott Unit for operational and safety reasons. Dua1 desig~a~io~ lis~s ~be ~er&c sur[ace loca~&o~ [oZlowed b$ 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) 1-2g/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/L-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) Lt- ~o/-rzq \~ ,,~..~'/~nit of the original Standard Oil C .... 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 questions, give me a call at 564-5007. Yours very truly, RSA/MAW/pm/1664D cc: R H. Reiley_ J. G. Vidrine I. R. Robertson D. Huxley B. Ross File 16.4 Endicott Development R. S. Allan Division Drilling Engineer MEMORAN ")UM Stat - of Alaska ALASKA ,~-£L AND GAS CONSERVATION COi~,.ISSION TO' C V ~ ~ ~erton DATE' March 13, 1987 FILE NO.: D .BDF. 16 THRU: FROM: Lonnie C. Smith Commissioner Bobby Foster Petroleum Inspector TELEPHONE NO.: SUBJECT: BOP Test Standard DIU L-36 Permit #87-20 Endicott Oil Pool Wednesday, March 4, 1987: The BOP test began at 7:30 p.m. and was "C~llid~ed at 9~.Jjo ~.~] As the attached BOP test report shows, there were no failures. In summary, I witnessed the BOP test on Standard's Endicott well L-36. Attachment STATE OF AI3~KA OIL & C~3 COKSEP, VATZON CO.-~2~SS/ON E.O.?.E. Inspection ~eport Location, ~eneral Uell S~ ~ ACC~TOR 5YST~ ' Mud Svs~s V~sual AUdio Pu~p ~ncr. c!os. pres. 200 ps!~ ~ ~In~sec. Trip Tank Pit CauEe Cas Deteczors . BOPE Stack Test Pressure - Ch e ck V~ve ~ { Upper Kelly Lover Ke!/y Ball T)~e inside BOP Test Pressure Test Pressure ~o'~0 Test Pressure. Test Pressure Choke ¥~uifoid_~Test Pressure ~ ~20r(~ no. va!.,s' /-3' ~djuszsbie ~nokes.., ~ Evdrau~c~!!v o~er~:ed choke ~ Tes~ Resu~zs:, Failures Tes; Time ~ hrs. Repair or P. ep!acamenZ of failed equ!pmenz so be made ~iuhin --~ ~a)'~ and inspecsor/ . Co~ssio~. office noz~ied. -- . - Disz_--!b~zion ~-- or!~. - AO&GCC cc - Supervisor February 27, 1987. Mr. R. S. Allan District Drilling Engineer Standard Alaska Production Company P.O. Box 196612 Anchorage, AK 99519-6612 Re: Telecopy: (907) 276-7542 Duck Island Unit/Endicott L-36 SDI Standard Alaska Production Company Permit No. 87-20 Sur. Loc. 2508'SNL, 680'WEL, Sec. 8, TllN, R17E, UM. Btm~ole Loc. 432'1'SNL, I5]3'WEL, Sec. 4, TllN, R17E, UM. Dear Mr. Allan: 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. Where 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. Ch~'~rt6n Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE CO~ISSION jo Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CUMMISSION PERMIT TO DRILL 20 AAC 25.005 L-36]~SDI ':; Row 3 Slot 35 [~ la. Type of work Drill I~ Redrill ~] lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil i'.. Re-Entry © Deepen~, Service [] Developement Gas ~ Single Zone~, Multiple Zone i 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Standard Alaska Production Company 56 feet Endicott Field 3. Address 6. Property Designation Endicott Oil Pool P.O. Box 196612, Anchorage, AK 99519-6612 ADL 47503 4. Location of well at surface 7. Unit or property Name 11. Type Bond lsee 20AAC 25.025) 2508' SNL, 680' WEL, Sec. 8, TllN, R17E Duck Island Unit/Endicoi:t At top of productive interval 8. Well nu .mber Number 4600' SNL, 1890' WEL, Sec. 4, TllN, R17E L-36 SDI K00683449-G-14 At total depth 9. Approximate spud date Amount i4321' SNL, 1513' WEL, Sec. 4, TllN, R17E February 28r 1987 $200r000.00 !: 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(MD a,d TVD) i property line 12785' MD ADL 47502 3390 feet Surface -10 feet 2560 10546' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 A^c 25.035 Kickoff depth 4OQ~) feet Maximum hole angle 45 0 Maximum surface 3900 psig At total depth rrvD)9855 4840psig i~ 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~lctura] Driv .~ .Pipe ~urfac¢ '.t61' 161' Drive '17-1/2" 13-3/8" 68~ L~80 Butt. 2444' ~urface 2500' 2500' 3700 cu. ft- Pcrm~frQst 12-1/4" 9-5/8" 47# NT80S NSCC 9828' ~urface 9884' 8500' 320 cu. ft. Permafro. 12-1/4" 9-5/8" 47# NT95H~ NSCC 1909' 9884' 8500'11793' 9846' 575 cu. ft. Class G 8-1/2" 7" 29~ SM-11) Butt. 1042' [1743' 9811'12785' 10546' 475 cu. ft. Class 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural ~ , ; Conductor ' ; : i ~," 'i ! ,, , Surface ; -.:...,:... Intermediate Production ~ : ~' '"'' Liner Perforation depth: measured i::?:.;:?:?~ ~i'i:~ ;i~ (~::3 ';~'~::,, i', '.~.':'. true vertical 20. Attachments Filing fee [] Property plat ~ BOP Sketch [] DiverterSketch [] 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 Signe~'~~-' ~. ~, ~ Title Division Drilling Engineer Date Commission Use Only Permit Number_ ! APl number I Approv,~j~d,a,{% ~ / See cover letter ,~',,~-~0 J 50--O~t'~- ~%/'~1 j uz://-//87 for other requirements Conditions of approval Samples required [] Yes ~ No Mud Icg required Lq Yes,~ No Hydrogen sulfide measures [] Yes ~...No Directional survey,[¢quired ~ Yes [] No Required working pressure for B~OP.,,F~;~.~¢~ 31V~ []/~M; J~ 10M; [] 15M Other: ~ /).~~/f ~_.t~Y/'-~/""" - / by order of . .~~,7./~ App[ovedby ~ / ,~. ~_~~~~"~ Comm,ss,oner the commission Date STATE OF ALASKA L-36 SDI. ALASKA OIL AND GAS CONSERVATION COMMISSION Row 3 PERMIT TO DRILL Slot 35 20 AAC 25.005 la. Type of work Drill I~ Redrill Fll lb. Type of well. Exploratory [] Stratigraphic Test C] Development Oil Re-Entry [] DeepenE}I Service ~ Developement Gas [_3 Single Zone J~ Multiple Zone E] "2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Standard Alaska Production Company 56 feet Endicott Field 3. Address 6. Property Designation Endicott Oil Pool P.O. Box 196612, Anchorage, AK 99519-6612 ADL 47503 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 2508' SNL, 680' WEL, Sec. 8, TllN, R17E Duck Island Unit/Endico:t At top of productive interval 8. Well nu ,mber' Number I 4600' SNL, 1890' WEL, Sec. 4, TllN, R17E L-36 SDI K00683449-G-14 At total depth 9. Approximate spud date Amount 4321' SNL, 1513' WEL, Sec. 4, TllN, R17E February 28r 1987 $200r000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 12785' MD ADL 47502 3390 feet Surface 10 feet 2560 10546' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) [;ili Kickoff depth 4000 feet Maximum hole angle 45 0 Maximum surface 3900 psig At total depth (TVD)9855 4840Psig 18. Casing program Settin~l Depth size Specifications Top Bottom Quantity of cement , Hole Casing Weightl Grade Coupling Length MD TVD MD TVD (include stage data) i 30" Str~lctura~ Driv.~ .Pipe ~urfac¢ :.]',61' 161 ' Drive I' !17-1/2" 13-3/8" 68~ L~80 Butt. 2444' ~urface 2500' 2500' 3700 cu.ft. Permafrost "12-1/4" 9-5/8" 47~ NT80S NSCC 9828' ~urface 9884' 8500' 320 cu.ft. Permafro~, 12-1/4" 9-5/8" 47# NT95H,~ NSCC 1909' 9884' 8500' 11793'I 9846' 575 cu. ft. Class G 8-1/2" 7" 29# SM-11!) Butt. 1042' 11743' 9811'12785' 10546' 475 cu. ft. C. las.~ G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor ' i' ;'.' ~. ~.: ~, Surface Intermediate . ~ , ~ .~., . Production Liner ..... ;:.: .... i~. ~ ;:.; :; ~...~; :; '; Perforation depth: measured true vertical 20. Attachments Filing fee ~ Property plat ~ BOP Sketch [] DiverterSketch [] 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 Signe~'~~' ~. ~, ~~___~ Title Division Drilling Engineer Date~¢, Commission Use Only I ISee c°ver letter APl numbe6 2 9- Appro~,¢~:t~ / 8 7 Permit Numbe~° 7 - 2 0 50-- 21 7 01 for other requirements Conditions of approval Samples required [] Yes ,~ No Mud Icg required L-] Yes J~ No Hydrogen sulfide measures [] Yes [] No Directional survey required ~1~ Yes [] No Required working, Off, sure for~BO~2_,M; ~ 3M; /,~ 5M; [] 10M; [] 15M Other: / / d/~ ~/~ byorderof Approved by~,.~ ~' "" ~",, % /,~.,~,/¢~~ Commissioner the commission Date PROPOSED DRILLING AND COMPLETION PROGRAM WELL 3-35/L-36 Objective Well L-36 will be drilled as an oil production well. Zone 3A is the primary objective. The completion will be run in mid-1987. Operation Execute a rig move from slot 4-8 to slot 3-35 and rig-up. Vertically drill 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 4000 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. 'Nipple down BOPE. Install xmas tree 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 packer tailpipe completion. A sub surface safety valve will be installed below base of permafrost. Install and test tree. Release rig. ENDICOTT PROPOSED DIAGRAM WELL 3-35/L-36 ~SDI) NON-FP~d~3,,~ FLUID TVD CBKB) MD (BKB) 30' DRIVE PIPE 161 FT 161 FT SSSV 13-3/8' 68#/FT L-80 BUTT 1600 FT 1600 FT (ESTIMATED 2000 FT) 2500 FT 2500 FT BOTTOM OF DOWN SQUFFTF CEMENT (ESTIMATED 3000 FT) KOP ( DIR: N 51.5 E; ANGLE: 45 DEG ) 4000 FT 4-1/2', 12.6#/FT L-80 TDS TUBING W/3-1/2' TAILPIPE 9-5/8' 47#/FT NT80S NSCC TOP OF 9-5/8' CEMENT 8500 FT 9884 FT (ESTIMATED 10113 F'I') 7" LINER TOP 9811 FT 11743 FT 9-5/8' 47#/FT NTg5HS NSCC 9846 FT 11793 FT 7" TIW PACKER W/PBR PLUG BACK TD 7" 2g#/FT L-80 BUTT LINER 10546 FT 12705 FT 12785 FT IRR/2-19-87 §.O.P. STACK CONF I GURAT I ON 13-5/8 IN. TRIPLE RAM STACK SO00 PSI WI) DRILLING ANNULAR PREVENTER I I I PIPE RAMS ! ! I 1 BLIND RAMS I ! DRILLING SPOOL GATE GATE J I i 4 IN. CHOKE LINE GATE GATE PIPE RAMS I ! v/¢/#/ rv -- 35 ~ 31 32 33 Main Productio~ Isla~l (MPI) · ~L . T. 12 N. I . 5 ''4 T. IIN. .. IZ 8 Satellife Drilling I=land(SDI) ~ ~e Isle nd . .. ~ I~land ' : ~ .;: ~- ~k ~:~'~ ~- /::..,:... ~~ ~ ~::~-. . .... .:. PLAT OF PROPOSED WELL LOCATIONS MPI Wells Located In Sac.;~6, T.I?N-~R.16E-,UmiaI M. SDI Wails Located In Se-c. 8,T.IIN.,R.17E.,Um'~at M. PREPARED FOR SOHIO ALASKA PETROLEUM CO. DRW NO. 116- 85 SHEET I of I0 REV. 0 PREPAR ED BY F.R. BELL 8~ ASSO.C. PRUDHOE BAY OFFICE PRUOHOE BAY, ALASKA DATE: NOV. 13, 1985 SCALE: I''1 MILE DRAWN eY: RJLT. CHECKED' BY ' ooooooooooooo oo ooo ~~~~ a 0000000000000 Z8303Z 0000 O0 C I heathy certify tttQt I Om Properly ri AlelkQ end tkQt fkls t Iocifmn For the w.,,PI_Qt reprelentl he S/a_re of lurveyi# --',, NUMb · .~_ ell Propole er. -nOWh eL- I /ii 4ohe k~ or uoVt. "' "°' '" '~-'"...'.., ::;:,~:, are cot rec/. 0 IhAicetel well I~dtce/li C~llctletid llctie#cef#ir ( ~n/icul~ tliteKe ~eriN f~ eech ~dl ) PLAT OF SDI PROPOSED WELLLOCATIoNs DRW.~o. 116-85 SHEET 7' of I0 REV. 0 SOHIo ALASKA PETROLEUM CO. F'R~- 8ELL & ASSoc. PRUDHOE 84¥ OFFICE PRUDHOE BAy~ ALASi DATE: NOV. 13. ItlS SCALE' I". I0' I I I I L I I III I I , ll;LL ~8P Zoll~ I YT~ JN( & LATITU~ L~ ;UK lB tll I Y-'l170tiS,47 710il70.H 70 ' t'20. 40 ·14P '41.27tt' X- Z701&3.!O E- 4&7~4~.0! 2 Y- 5970796,40 N- 78~1819.43 700i9"~B,~842· X' 270181.37 Em 467~47.32 3 ~y. ~970966.~ ~H' 7802-8-7~.22 7071~'20.2~42'**'~'~47~1'48.9908~ '~ 2~.9~ ~ 8~.~4 ' X- 27017~,75 ~ E- 4~7544.08 4 'Y- ~970797,44 N- 7801819.80 '70~19'1B.5975" X- 270191.~1iE" 467~0.34 ~ 5 Y- ~970967.56 N- 7801871,~9 X- 270183.69 E- 467~47.11 & Y- ~97~798.49 N- 780'1820.1~ "70o~9'~8.~:08" 147o51'4B.0321" ''2701;02 835.78 X- 270201.46 E- 467~3.37 7 Y- b97096B.&o N. 7802i7 :' "7'0 :9'20.2808· 147o~1'48.4124· 2~31.23 B4B.3t X" 270193.64 E" 467~0.13 B Y" ~97'0799,~4 N" 7801820,~4 7'0~1~'18,'6240" 147c~1'47,7429" 2699,67 B2~,86 X" 27021t,4~ E' 467~6,39 9 Y" ~97096.9,65 N" 7~01872,32 70°~9'20'2940" ~47'°'~'48,~232" 2529,87 138,40 X" 270203,~8 E" 467~3,~& 10 Y" ~70800.~8 N- 7801820,90 70~19'JB,'637"~" ~47o~1'47,4~37' 2698,32 X" 27022~,35 E' 467~9,42 ~1 Y' ~970970,69 N" 780~872.69 70~9'20,3073' ~47~1'47',8340' 2528.~2 82~,49 X' 2702t3,~3 E' 467~6,~8 ~2 Y' 5970801,63 N' 7801821,27 70°19'~8,6506' ~47°~1'47,164~" ~ 2696.97 806'04 X" 270231,30 E' 467~62,44 13 'Y; 5970971,74 ' N' 7801873.06 700~9"20,3206" 147c~1"47,5448" 2~27.17 81'8.~7 X" ~7022~,47 E' 467~9,2~ t4 Y"~970802,67 N' 7801821,64 70°19'18.6639" ~47°'51'46.B7~4'" 269~,62 796,13 X" 270241,24 E" 467~6~.47 1~ Y' ~970972,'79 N" 7801873~43 70'~9'20.3338" ~'47°5~'47.2~' 2~2~.82 808,'66 X" 270233,42 E" 467~62,23 X6 "Y' 5970803.'72 N' 7801822,01 70~i"9'tB,677X' 147°~1'46.~862'' 2694.27 786.21 X' 2702~,~9 E' 467~68,49 ~7 Y' 5970973.83 N' 7801873.80 70°~9'20.347t' 147°~'46.9664' 2~24.47 798.7~ X" 270243,36 E' 467~6~.26 , 18 Y- ~970804.76 N- 780~822.38 70°19'1"8.6904" 147°~1'46.2970" 2692.91 776.30 X- 270~6~,~3 E- 46,7~71,~2 19 Y- 5970974.88 N- 7801874,16 70°~'9'20.3604, 147°~1'46,6772" 2523.12 ' 788,83 X~ 270253.31 E- 467~68.28 20 Y- ~97080~.81 N- 7801822.7~ 70~9'~8.7037' ~47°~1'46.0078'' 2691.~6 7&6,39 X- 2702.71,08 E- 467~74,~4 21 Y-'5970975,~2 N- 7801174.53 70°19"20.3736"''' 147°5~'46.3880" 2521.7~ ~78.92 X- 270263.2~ E- 46757t,30 .........., I II ~~~~ LOC&TED IN SEC.", T. IIN., E.17E. UMIAT M. ~;~ ~%~ "~ PREPARED FOR '?~'~ :~:~;~':;:? SO H I0 A L ASKA PETROLEUM CO. ~~~Z~~~ F.R BELL & ASSOC ~i_~~.~.~ ~ SHEET 8 of IO ' * SCALE ' N/A ~ ~.~ss~~ ~ PRU DHOE BAY OFFICE · C HECKEO ' i i i i i i ii ii ii i ii W ZONE 3 UTS ;NE 6 LATZTUDE [IJ~E BZlT 21 Y- 1970106.15 N- 710112'3.1i' 7~19'11. 7169' 14~11'41.7116· Zig. Il 7k.47 ~ Xe ~70211.02 E- 46~77,~ . . 2~ Y- 5970976.97 N- 7801674.90 70~19 ' 20. 3669· ]47°~'46.09B9· 2520.4~ 769.01 X- 270273.20 E- 447574.33 "' 24 * Y- 5970807.90 ~ N- 7801823.48 170~9'28'~30-~"14-7~-5~';4~.4294' -.-2686.86 X- 270290,97 ~ E- 467560 59 ~ 2~ ~i ~6,~2~'-i ~ ~o1~:~o~,.~o.~oo~, ~*~'~.~o,~' ~,.o~ X- 27028~.14 [ E- 467577.3~ 26 ~ Y- s970808.94 tN- 780~82~.8S 7'O~'-~9~-~b:~4~S" ~7~S-i"4~:-i~O~" h 2687.S~- X' 270300.9t E- 467583.6t 27 Y- S970982. t9 N- 7BOi'B76.74 70c19'2'0.4~'3~~ t47°St'44.i529' 25~'~-&~ 719.44 [- 270322.~2 E- 4&7589.45 28 Y- S9708t3. t2 N- 7BOiB25.32 70°i9'tB.7966' t47°St"43.t135' 2il2','10 X- 270340.69 E- 46759~.7t 29 Y- 5970983.24 N- 7BOt877.tt 70°t9'20.4665' t47°St'44.3&37' 25t2.30 ~ 70t. S3 X- 270332.B7 E- 467592.48 I 30 Y- 59706~4.17 N- 760'~B25.i9 70o19'16.109B~ 14~5t'43.6943' 2&10.7S &IT.OB X- 2703S0.64 E- 467~98.74 , , 3~ Y- S970984.28 N- 780~877.48 7~29'20.479B' ~47°S~'44.074S' 2~0.9~ 699.62 X- 270342.B1 E- 467~9S.S0 ~ 32 Y- S97081~.21 N- 7801826.06 70o19'~8.B231· ~47°5~'43.40~2' 2679.40 677.17 X- 270360.58 E- 46760~.76 33 Y- ~97098~.33 N' 780~877.8~ 7'0o19'20.4931' ~47°51'43.7B~3' 2~09.60 6i9.7~ X- 2703~2.76 E- 467~98.~3 . 34 Y- ~9708X6.26 N- 7802826.43 70~X9'18.8364" ~47°S~'43.~60' 2678.04 . 667.26 X- 270370.S3 E- 467604.79 . 3~ Y- S970986'37 N- 7801878.2~ 70°~'9'20.~063' 147°51'43.496-1' 2'~0B.2~ ~ 679.79 X- 270362.70 E- 46760~.~ 36 Y- ~970817.3~ N- 780~826.80 70~9'~8.8496' ~47°5~'42.8268' 2676.69 X- 270380.47 E- 467607.8~ , 37 Y' ~970987.42 N' 7801878.~8 70c~9'20.~196" 147°51'43.2069' 2~06.19 669.18 X" 270372.6~ E- 467604.~8~ 38 Y' ~9708~8.3S N- 7802827.16 70~9'~8.8629" ~47051'42.~376' 267S.34 647.43 X- 270390.42 E- 467640.84 39 Y' 597098B.46 N' 7B0~878.9~ 70°~9'20.S329' 147°S1'42.9171' 2S05.54 659.97 X- 270382.S9 E' 46~607.60 ~-~0 Y~""59708i9.40 N' 780~827.~3 70°lg'li.i762' 147° 51' 42. 2484~ ..... ~.~9'~~637.S2 X' 270400.36 E' 4676X~.86 4~ Y" ~970989.~1 N' 7801879.32 70°19'20.~46~' 147°5X '42.6286' 2S04.19 6SO.O~ X- 27039~2.~4 E" 4676~0.6~ 42 Y' 5970820.44 N' 7i0~827.90 70°19'11.1894" 14~5~'4~.9~92' 2672'64 X" 270410.31 E" 4676~6.B8 .... i ii i i ii SDI ~O~SED WELL L~ATION LIST .......... ...... :::~.~. ,. ; ~. ...... / LOCATED IN SEC. I ,.T. II N., R. ITE. UMIAT c.-~--.~:--~ ............ ~;~ ~ {:;:~;; (;:~t:~., ~;~?~:::,; ~.~ SOHIO ALASKA PETROLEUM CO. - DRW. NO. IIG'l~ PREPARED BY OATE:NOV. I], 1185 ~ ..'~'~~'~~:....~~__ SHit, , o~ ~0 F.R. BELL & ASSOC. sclc[; t~L~ss,~~ PRUDHOE BAY OFfiCE ORAWN BY' R.G.T. -~~~ REV. 0 PRUDHOE UY, ALASKA C,[CKEO BY: I.[ ii iiii i ~ i iiii i iii Il[ HI[Ill[ I I [ [ I I[[ I [ [ [I [ [1[[ I lit , ~_ , ,11 ., 41 ~ Y' S970990.91 N- 710il79.69 70°i9'20.~5t'~' j4~1~'42.3394' 2S02.B4 64..t4 l' 270402.49 1- ~ 44 T~ B~70121.4' N' 7101l~l.~7 "70Glt"ll'.9027' S4~°Sl'4~'.&7~' 2671.2t X- 270420.2S E- 45 Y- S970991.60 N- 710il80.0& 70c19'20.572~" i470~1'42.0~02' 250~'.49 630.23 X- 2704t2,43 E' 4676t6.67. + ........... 46 Y" ~970822.~3 N" 7801828,&4 70~19'18.9~60" ~147~1'41.3009" ~ 2669.93 607,78 ; l- 270430.20 E" 467622.93 [ '. ~- 47 Y~ 59709~2.65 N~ 7~010B0.42 70~19'20.586'0' ' ~47051'41.7610' 2500.~4 ~20.32 l~ 270422,3B E~ 4676~9,70 X~ 270440,15 Em 4~7J25.~ 4~ ' y" 5t70~93,~ N- 7101180,79 70°1t;20,599'2' 14~o~1'41,47ll' '24~i,71 i10,40 1- 270432,32 E' 467~22.72 S0' y. 5970824,&2 N- 7801829,37 70c19'1B.9425' 147°51'40,1025" 2667,23 l" 270450.09 E- 467628.9B . i i i i i SDI ~OPOSED WELL LOCATION LIST ~&~~-- LOCATED IN SEC. t ,T. liN., R.17E. UMIATM. ....... ~J~. ~19~ ~ DRW. NO. 116-85 PREPARED BY DATE'NOV. 13,198~ -, mt~o~.,~.~ F.R. BELL S A~OC ~.~ESSi~AL~ SHEET ~of I0 · SCALE ' N/A ~%%%~~- ~ PRUDHOE BAY OFFICE ~AWN BY' R.G.T. eEV. 0 PRUDHOE BAY, ALASKA CHECKEDBY' i I I i i i ENDICOTT DEVELOPMENT WELL 3-35/L-36 (SDI} SLOT 3-35 SURFACE LOCATION X = 270,363 FT ; Y = 5,970,986 FT 2508 FT SNL; 680 FT WEL SEC 8 , T11N , R17E DEPARTURE TO BHL: 5626 FT 12785 FT MD 10546 FT TVD BKB TRUE NORTH GRID N 51° 30' E DEPARTURE TO TARGET: 5155 FT 12123 FT MD 10079 FT TVD BKB NOTE: THE NEAREST WELL TO L-36 IS K-37 LOCATED 10 FT WEST AT SLOT 3-33 IRR/2-19-87 Search Radius= 1000 COURSE L£igE Fo? proposed well' SIL.36 [34-4--i1-17] Location = W-E S-N TVD(SBS) Top 270363.00 5970986.00 -56.00 Bottom 274886.44 5974328.94 10490.00 Note' All depths in ~eet Below Keilg Bushing (BKB) Closest Approach WELL IDENT /PROPOSED\ TVD DEPART TVD 999999999 SI-P27 3199. 6 O. A000-0000025 SI-25 O. 0 O. A000-0000026 SI-26 O. 0 O. A000-0000028 SI-28 O. 0 O. A000-0000049 SI-4~ O. 0 O. AO00--O000050 SI-50 O. 0 O. A029--2028000 SI-DIi 5314. 5 414. AO~. -~0~8001 Of-Df2 6768. 1 1825 A0~9--~ 1 ~6900 o~, I --:~3~ 4757. 4 12°., . A029-2 ! 58600 S I-M33 2963. 4 0. A,3"~o-~ 162400 51--029 2944. 1 O. A029--2i 64000 Si-T34 400.0. 0 O. A027-2164001 SI-M35 3201 . 5 O. A02~-2164500 SI-N32 3542 2 O. AC ~9--~_ 166800 5i-K37 0 6 O. AO~--q ~ 67800 c: J--N2?_. 1400. 7 O. /NEARBY\ CLOSEST DEPART DISTANCE 3199.6 94.6 220,8 0.0 0.0 80.4 0.0 0.0 O. 0 187. 5 O. 0 174. 4 0.0 0.0 69.5 0.0 O. 0 183. 0 5933.0 1454.8 1175.2 6572. 7 3512. 4 595. 2 4,75'6::: 4 2943.9 75.4 105.6 3998.7 36.0 185.3 3199.6 12.9 192.6 3541.7 34.0 75.6 0.0 0.0 ,ilo '~iO0 0 I 5 199. 7 o;;MMARY Thp, ......... ~eli u~hich come~ clo,-:e~,t to +he prop~:sed t~,~i'.~ is' Vertical /PROPOSED\ TVD DEPART -) Intersection /NEARBY\ TVD DEPART VERTICAl_ DI~TANC2 RECEIVED FEB £ 4 1987 & C .s. Closest approach distz~nce = "TF'~-~ r~'"-J:';'- .l~ ~-:'r· ~h 'i -- -r-t,~ -- Search Radios= 1000 7 DEGREE LEAD LINE For proposed yell' SIL36 [34- 4--ii--17] Closest App~omch Anaigsis ..... Date' ~¥-FE~-87 Time~ lO'lO~44 ~ '~ Location = W-E S-N I'VD(SBS) Top ~:. , ,_, ,_. ,_, .., . O0 59709B6. O0 -3,~-, O0 Bottom 274445. 32 5974855. 29 10490. O0 Note- All depths in Peet Below Keilg Bushing (BKB) WELL IDENT 999999999 Si-P27 A000-0000025 SI-25 A000-0000026 SI-26 A000-0000028 SI-~8 A000-0000049 SI-49 AO00-O000050 SI-50 A029--2028000 SI-DII A02~-2028001 SI-DI2 Ao2~-~156~o SI-835 A0~-~158600 SI-M33 A029-2162400 SI:-O~ A02~-2164000 SI-T34 A02~-21~4001 SI-M35 A0~9-2164500 SI-N3~ A0~9-~166800 SI-~37 A0~9-~167800 SI-N2~ ~,iosest Approach /PROPOSED\ /NEARBY\ TVD DEPART TVD DEPART 3]99.6 0.0 3199.6 94.6 0.0 0.0 0.0 0.0 0.0 0.0 0.0 O. 0 O. 0 O. 0 O. 0 Vertical CLOSEST /PROPOSED\ DISTANCE TVD DEPART 174. 4 0.0 0.0 0.0 0.0 69.5 0.0 0.0 0.0 0.0 5314. 5 414. 5 5951. 2 1468. 4 6588, 0 1644, 2 6453. 7 3354. 2 4739. 8 123.= ~ 4738. 7 79. 2 2~63. 4 O. 0 2962. 4 26. 0 2944. I -' 0'.0 ~943.?-- 75.4 4000.0 0.0 3998.7 35.0 3201.5 0.0 3I~.6 12.9 3542.2 0.0 3541.7 34.0 lea. o 798.4 55.1 is.i 105. 6 185.3 192. 6 75. 6 0.6 0.0 0.0 0.0 11.0 1400.7 0.0 1400.0 1. 5 199 7 In 'be rsec t: on ,/" ,'~EARB - \"\ VE:RT ICA~ TVD DEPART D I STANC~: 9405.5 4477.5 7603.8 4486.3 -1801. 1 SUMMARY The well ,-hich comes A029-2166800 closest to the SI--~37 proposed well is' Closest appr,>ach .dist-:~nce =: KICK OFF ~or this run = 4000. 0 ~eet RECEIVED FEB 2 4 i987 Alaska Oil &-Gas Cons. Co.~,~jssio,~ Anchorag~ ENDICOTT MUD PROGRAM SATELLITE DRILLING ISLAND WE'LL 3.35/L-36 Interval 0-2500 2,500- 11,793 11,793- 12,785 Mud Weight ViscOsity (sec/qt) Fluid Loss (ml/30min~ pH Mud Type/ Components 8.8-9.8 100-200 20-15 8.5-9.0 Generic Mud #5 Seawater Fresh water Gel Soda Ash Set 13-3/8" casing 9.2-10.2 40-45 15-16 9.5-10.0 Generic Mud #7 Set 9-5/8" casing Seawater Fresh water Gel Caustic Soda Soda Ash Barite Lignosulfonate Drispac Lignite 9.6-10.2 4045 6-8 9.0-10.0 Generic Mud #7 RECEIVED FEB 2 4 1987 Alaska Oil & Gas Cons. Commission ~, Anchorage Hang 7" Liner Seawater Fresh water Gel Caustic Soda Soda Ash Barite Lignosulfonate Drispac Lignite POOL ARCTIC ALASKA RIG NO. 7 Mud Tank/Trip Tank Flonttor~ino-Recordin~q TOTCO, PITUMETER UNIT L-8 (PNEUMATIC) DRILLING RECORDER SYSTEH TOTCO, MODEL DR8WPT (E) RS (2) F DRILLER'S CONSOLE TOTCO "COMMAND" RECEIVED FEB 2 4 1987 Alaska Oil & Gas Cons. Comm.~,,bn Anchorage POOL ARCTIC ALASKA RIG NO. 7 MUD AND SOLIDS CONTROL E~UIPMENT EquiPment Hanufacturer HodeX Nominal Capacity Shaker Brandt Dual Double lO00 gpm Desanders Tri Flow/Pioneer Mann-Design 2 each - TFI-126 screens 4 each - Pioneer 12" EconomasCer Cones 1000 gpm (each) Hudcleaners Brandt Double 8 each - 4** Cones 400 Spm (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. FEB 2 4 Alas×~ ~Tcr/./,.nnn97 C. I i ,,, ISSUED FEB 2 4 '"~°-"i~o, ~ "'" · ~,~. Alaska Oil & Gas Cans. Anchorage FOR INFOR/V~TION ONLY OIr P..A,J~ W OF THIS OE~IGN IS PER. II~dBtE ONLY iF LENGTH 1~t::2 t~I~L. ,'XC. TIVE::: MUP 5'fST~.M F LIMP., Ig I ~ P~MP s I ,o , . r'! I , FEB 2 4 ~g87 ------ ['. ' Naska Oil & Gas Cons. Commissbn / Anchorage N~TION ~(~ ........ TESTING THE B.O.P. STACK 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 low6r 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: Al-1 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 (T~RU-BORE) · TEST PLUG THIS END UP I- - . FMC P.-N. 48-261-082 . REQ' D PART N0'~ DESCRIPTION 1 ·48-261-268 Test Plug , 1 -".48-261-673 ::. '-.COmpression Ring 4 '79-040'2'074 :: ~.-~set Screws 1 51~002-001 i 2- Ball Check Figure # 7 ~. i{Part, nUmber-48-261'-0'82 Continued on next page) · FMC P.N. 48-261-082 continued' REQ~D. PART NO. 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 3-5/8" 3000 WP TESTING THE B.O.P. STACK WITH THE 13½" X 4½" IF BOX X BOX, (UPPER), TEST PLUG (FIG. 19) 1.) Make up the 13%" x 4½" 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 lockdown 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 L 1 48-261-067 Body 1 ~48-261-'671 Compress£on Ring' '"4 '79-040-074:~ Set Screw 'i '82-74i':1{7 .,'Packing ' I 51.-09,2-001 2" Ball Check 1 1 ..1~_505~.66~.. C~il Spring ,,, 1" 25-411-356 Retaining Plate · 1 25-411-357 Circ.-O-Lox Ring ,. - ,,, 2' ','48-100-027 -'PiPe Plug t , ,,,,, HIS END UP Figure % 1'9 ILLUSTRATION# 13 :5/8" 5000 13-5/8" 3000 WP TESTING THE B.O.P. STACK WITH THE 10" X 4-1/2" IF' BOX X BOX (COMBINATION), TEST PLUG (FIG. 22A) 1.) Make up the 10" x 4½"'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 be 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" COMBINATION TEST PLUG AND BOWL PROTECTOR RUNNING/RETRIEViNG TOOL THIS END UP FMC PART NO. 48-261-503 REQ'D PART NO. DESCRIPTION 1 48-261-504 BODY ,,, 1 48-085-833 BELT PACKING · i.~ 1 ....48'180-025 ·PLUG, 1~ L.P. · . 1 .48-180-025 :.:.', 'PLUG, 1~ L~P. , , ,, 4 48-'i80-015-. PLUG, ½ L.P. 1 48-010=009 WRENCH , , ,, , , , , (Figure %22A) ~ B.O.P. STACK 1" 5000 W? 13-5/8" 3000 STACK 5000 WP 11" 5000 WP 13-5/8" 3000 WP CHECK LIST FOR NEW W~ J. PERMITS ITEM APPROVE DATE YES (1) Fee ~ ~-J-f'--~'? 1. Is the permit fee attached .......................................... ~ (2 thru 8) (8).., (3) Admin ~ ~ -; ~-~7 9. 13) 10. . .. ~-¢¢-~9 11. (10 and 1]) 12. 13. (4) Casg (14 thru 22) (23 thru 28) Lease & Well No. NO 2. Is well to be located in a defined pool ............................. ~, 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ 7. 8. Is operator the only affected party ................................. Can permit be approved before fifteen-day wait ...................... Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval-needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... Is enough cemmnt used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will c_~mant cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Is a diverter system require~d ....................................... Is the drilling fluid program schematic and list of equipmmnt adequate Are necessary diagrams and descriptions of ~ee~z~-~ BOPE attached. Does BOPE have sufficient pressure rating - Test to 3oo~oo psig .. Does the choke manifold comply w/AP1 RP-53 (May 84)....~ .............. 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 For 29. 30. 31. L-.Y z.p./? (6) Add: Geologyz Eng'%ncering: -- 01/28/87 32. Additional requirements ............................................. INITIAL GEO. UNIT DN/OFF POOL CLASS STATUS AREA NO. SHORE ,, 1 -otc t o ¢>/j Additional Remarks: ? ,/ Well HiStorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To impmVe the roadability 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. · sea (13A!3~3~ LIS TAPE VERIFICATION LISTING VP OlO.H02 VERIFICATION LISTING PAGE 1 $ REEL HEADER $~ ERVICE NAME :EDIT ATE :87104120 RIGIN : EEL NAME :72249 ONTINUATION # :01 REVIOUS REEL : OMMENTS :LIS TAPE, STANDARD ENDICOTT 3-35/L-36~ API 50-029-21701 ~ TAPE HEADER ~x~ ERVICE NAME :EDIT ATE :87/04/20 RIGIN :7224 APE NAME : ONTINUATION # :01 REVIOUS TAPE : OMMENTS :LIS TAPEr STANDARD ENDICOTT 3-35/L-36, ~PI 50-029-2170I · FILE HEADER ~ ILE NAME :EDIT .001 ERVICE NAME : ERSION ~ : ATE : AXIMUM LENGTH : 1024 ILE TYPE : REVIOUS FILE : INFORMATION RECORDS.,-.,-"'"' NEM CONTENTS UNIT TYPE CATE SIZE CODE N : STANDARD ALASKA PRODUCTION COM 000 000 030 065 N : 3-35/L-36 000 000 010 065 N : ENDICOTT 000 000 008 065 ANG: i?E 000 000 004 065 OWN: liN 000 000 004 065 ECT: 8 000 000 OOZ 065 OUN: NORTH SLOPE 000 000 012 065 TAT: ALASKA 000 000 006 065 TRY: USA 000 000 003 065 'NEM CONTENTS UNIT TYPE CATE SIZE CDDE RES: E 000 000 001 065 :~ COMMENTS-,-'~'~.- ...... .,o.,..,..,...~..,..,..,..,..,.., .... .,..,.., .... .,.., ........... ~,~..,~ ~-..-',~,~,.,..,.., .... . -,..,. -,. ..,..,..,..,. .,.-,. -,--,,. -,-.,.-,- ,q~ ;:.~'"' .... .,. .,...-. .,. ~ .... .,..,,..,..,,.,,.~.,,~.,~,,,,~.,,.-,~ ~P OIO.HOZ VERIFICATION LISTING PAGE 2 SCHLUMBERGER ALASKA COMPUTING CENTER 2MPANY = STANDARD ALASKA PRODUCTION CO ELL = 3-35/L-36 IELD = ENDICOTT OUNTY : NORTH SLOPE BOROUGH TATE = ALASK~ OB NUMBER AT AKCC: 72Z~9 UN ~1, PEN HOLE DUAL LATEROLOG DATE LOGGED: Z6-MAR-8? ASED HOLE COMPENSATED NEUTRON LOGGED: 02-APR-8? DP: RICK KRUWELL ASING ASING = 9.625" @ 11989' - BIT SIZE : 12,25" TO 11989' : 7.000" @ 12640' - BIT SIZE : 8.5" TO 12643' TOP OF ?" LINER @ 11744' PEN HOLE MUD INFORMATION: YPE FLUID : LIGNOSDLFONATE ENSiTY : 10 LB/G ISCOSITY = 37 S H : RM RMF RMC = 1.52 @ 65 DF : 1.28 @ 65 DF = 2.41 @ 65 DF VP OlO.H02 VERIFICATION LISTING PAGE 3 LUID LOSS : 5.9 C3 RM AT SHT : °5? @ .185 DF ATRIX SANDSTONE -~..-,.-,. THIS OATA HAS NOT BEEN DEPTH SHIFTED - OVERLAYS FIELD PRINTS ~-***~ , .,. ,,,~, .,..*,. ,,N~, .~ ,q~, .~,.... ,q. :~ =~ .~, :~ ~k ~'~: =,~ ~k ~ ~..''' ''' ''' ''~ ~' 'v '~' ~' ~t'' ~' '~ ~'~ ~ ~''' ~' ~' ''' '~ ~' ~ ''' ~' ~' '~ ''' '~,~. ~- ~ ~ -,- -~ .q,- -,- -~ ~- -~ -~ ~.~ ~ ~' ~ ~- -~- ~ -~' .~ ~ ~ ~ ~ -,- ,~ ..... ,~ ~- ~*J~ ~"' '~ ~, ~'4~ .'~ ~ ~ ~'~. ~,~ ~'J: ~,'~ ~'.4~.~ ~ ~4~ ~,~ ~: ~'~ ~ ~ ~ ~ ~ ~ ~ ~ ~ *~ ,q~ SCHLUMBERGER LOGS INCLUDED WITH THIS MAGNETIC TAPE: OPEN HOLE DATA: DUAL LATERLOG (DLL) DATA AVAILABLE: 12160' TO 11984' CASE HOLE CATA: COMPENSATED NEUTRON LOG (CNL) DATA AV'AILABLE: 12521' TO 11586' VP OlO.HO2 VERIFICATION LISTING PAGE 4 DATA FORMAT NTRY BLOCKS RECORD TYPE 2 9 t6 0 ATUM SPECIFICATION NEM SERVICE SERVICE ID ORDER # EPT LS DLL LD DLL ALS DLL AL1 DLL P DLL R DLL VO DLL IO DLL VO DLL IO DLL Vl DLL RES DLL TEM DLL ENS DLL ENS CNL EVI CNL B CNL R CNL NRA CNL CNL CNL CNL CNL RAT CNL PHI CNL SIZE 1 1 4 4 1 1 BLOCKS UNIT API API API LOG TYPE CLASS FT O0 000 O0 OHMM O0 220 og OHMM O0 220 10 IN O0 000 O0 iN O0 280 01 MV O0 010 01 GAPI O0 310 01 MV O0 000 O0 UA O0 000 O0 MV O0 000 O0 UA O0 000 O0 MV O0 000 O0 OHMM O0 823 50 DEGF O0 660 50 LB O0 635 21 LB O0 635 21 DEG O0 620 01 DEG O0 631 O1 GAPI O0 310 O1 O0 000 O0 CPS O0 330 30 CPS O0 330 31 O0 420 O1 PU O0 890 O0 REPR CODE 66 66 73 65 66 66 ENTRY 0 1 60 .liN 1 0 AP1 FILE SIZE SPL MOD NO. 0 0 4 1 0 0 4 0 0 4 1 0 0 4 1 0 0 4 1 0 0 4 1 0 0 4 1 0 0 4 1 0 0 4 1 0 0 4 1 0 0 4 1 0 0 4 1 0 0 4 1 0 0 4 t 0 0 4 1 0 0 4 1 0 0 4 1 0 0 4 1 0 0 4 1 0 0 4 1 0 0 4 1 0 0 4 1 0 0 4 0 0 4 1 REPR CODE 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 PROCESS (OCTAL) 00000000000000 00000000000000 00000000000000 O0000000OO0000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 OO000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000.000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 DATA EPT AL1 IO RES EVI CNL 12605.5000 LLS -999.2500 SP -999.2500 SVO -999.2500 MTEM 9.6484 RB 1027.0000 NCNL EPT AL1 IO RES EVI CNL 12600.0000 LLS -999.2500 SP -999.2500 SVO -999.2500 MTEM 8.5703 RB 1027.0000 NCNL -999.2500 LLD -999.2500 GR -999.2500 SIO -999.2500 TENS 44.2813 GR 2336.0000 NRAT -999.2500 LLD -999.2500 GR -999.2500 SlO -999.2500 TENS 41,6563 GR 2336.0000 NRAT -999. -999. -999. -999. 17. 2. -999. -999. -999. -999. 17. 2. 250O 2500 2500 2500 9375 1680 2500 2500 250O 2500 9375 1680 CALS OVO DV1 TENS RNR.A NPHI CALS D¥O DV1 TENS RNRA NPHI -999.2500 -999.2500 -999.2500 1575.0000 2.2734 15.3809 -999.2500 -999.2500 -999.2500 1890.0000 2.2734 15.3809 VP OlO.H02 VERIFICATION LISTING PAGE 5 EPT 12500.0000 LLS AL1 -999.2500 SP IO -999.2500 SVO RES -999.2500 MT~M EVI 8.8516 RB CNL 826.0000 NCNL EPT 12400.0000 LLS AL1 -999.2500 SP I0 -999.2500 SVO RES -999.2500 MTEM EVI 34,3750 RB CNL 826.0000 NCNL EPT 12300.0000 LLS AL1 -999'2500 SP IO -999.2500 SVO RES -999.2500 MTEM EVI 34.3750 RB CNL 1171.0000 NCNL EPT 12200.0000 LLS AL1 .-999.2500 SP IO -999.2500 SVO RES -999.2500 MTEM EVI 34.3750 RB CNL 800.0000 NCNL EPT 12100.0000 LLS AL1 8.7031 SP I0 560.0000 SVO RES 0.5176 MTEM EVI 34.3750 RB CNL 312.0000 NCNL EPT 12000.0000 LLS AL1 9.9922 SP IO 499.2500 SVO RES 0.5273 MTEM iEVI 34.3750 RB CNL 190.6250 NCNL ,EPT 11900.0000 LLS ,AL1 -999.2500 SP ~IO -999.2500 SVO IRES -999.2500 MTEM ~EVi 34.3750 RB ~CNL 208.7500 NCNL tEPT 11800.0000 LLS ,AL1 -999.2500 SP ~I0 -999.2500 SVO IRES -999.2500 MTEM -999.2500 LLD -999.2500 GR -999.2500 SIO -999.2500 TENS 10.9844 .GR 1852.0000 NRAT -999.2500 LLO -999.2500 GR -999.2500 SIO -999.2500 TENS 322.7500 GR 2052.0000 NRAT -999.2500 LLD -999.2500 GR -999.2500 SIO -999.2500 TENS 308.2500 GR 2370.0000 NRA'T -999.2500 LLD -999.2500 GR -999.2500 SIO -999. 2500 TENS 200.8750 GR 2029.0000 NRAT 5.7486 LLD -21.3906 GR 2.6934 SIO 185.5000 TENS 14.2344 GR 1097.0000 NRAT 8.5445 LLO -44.5938 GR 3.5117 SIO 183.8750 TENS 305.7500 GR 971.5000 NRAT -999.2500 LLD -999.2500 GR -999.2500 StO -999.2500 TENS 174.0000 GR 1062.0000 NRAT -999.2500 LLD -999.2500 GR -999.2500 SIO -999.2500 TENS -999.2500 -999.2500 -999.2500 -999.2500 58.6875 2.5156 -999.2500 -999.2500 -999.2500 -999.2500 18.9219 2.4004 -999.2500 -999.2500 -999.2500 -999.2500 12.7578 2.0742 -999.2500 -999.2500 -999.2500 -999.2500 15.8047 2.4863 6.2706 121.7500 679.5000 5592.0000 82.1250 3.3320 8.9350 114.6250 596.0000 5740.0000 64.9375 4.4961 -999.2500 -999.2500 -999.2500 -999.2500 77.1250 4.6016 -999.2500 -999.2500 -999.2500 -999.2500 C ALS DVO DV1 TENS RNRA NPHi CALS DVO OVl TENS RNRA NPHI CALS DVO DV1 TENS RNRA NPHI CALS DVO DY1 TENS RNRA NPHI CALS DVO DV! TENS RNRA NPMI CALS D¥O DVI TENS RNRA NPHI CALS DVO DV1 TENS RNRA NPHI CALS DVO OV1 TENS -999.2500 -999.2500 -999.2500 2574.0000 2.2402 20.4590 -999.2500 -999.2500 -999.2500 2520.0000 2.4824 18.7012 -999.2500 -999.2500 -999.2500 2520.0000 2.0234 14.0625 -999.2500 -999.2500 -999.2500 2534.0000 2.5352 20.0195 8.1641 3.9473 0.0083 2434.0000 3.5156 35.1562 10.3203 5.0117 0.0083 2470.0000 5.0938 56.3477 -999.2500 -999,2500 -999.2500 2514.0000 5.0859 58.3008 -999.2500 -999.2500 -999.2500 2434.0000 VP OIO.HO2 VERIFICATION LISTING PAGE 6 EVI. 34.3750 R5 CNL 208.7500 NCNL EPT 11700,0000 LLS AL1 -999.2500 SP IO -999,2500 SVO RES -999,2500 MTEM EVI 34.3750 RB CNL 172.5000 NCNL EPT 11600.0000 LLS AL1 -999,2500 SP IO -999,2500 SVO RES -999.2500 MTEM EVI 34.3750 RB CNL 281,2500 NCNL EPT 11583,5000 LLS AL1 -999,2500 SP I0 -999,2500 sro ~RES -999.2500 MTEM EVI 34.3750 RB CNL 272.5000 NCNL 5.4453 GR 953.0000 NRAT -999.2500 LLD -999.2500 GR -999,2500 SIO -999.2500 TENS 295.2500 GR 853,5000 NRAT -999.2500 LLO -999.2500 GR -999.2500 StO -999.2500 TENS 294.?500 GR 1044,0000 NRAT -999.2500 LLD -999.2500 GR · -999.2500 SIO -999.2500 TENS 295,2500 GR 1036,0000 NRAT 75.5625 4.6016 -999.2500 -999.2500 -999.2500 -999.2500 108.9375 4.3555 -999.2500 -999.2500 -999..2500 -999.2500 85.9375 3,7461 -999,2500 -999.2500 -999'2500 -999.2500 62.6875 3.5195 RNRA NPHI CALS DY 0 OVl TENS RNRA NPHI CALS OVO DV1 TENS RNRA NPHI CALS DVO DV1 TENS RNRA NPHI 4.5625 58.3008 -999.2500 -999.2500 -999.2'500 2340.0000 4.9453 53.8086 -999.2500 -999.2500 -999.2500 2384.0000 3.7109 42.6758 -999.2500 -999.2500 -999.2500 2324.0000 3.8008 38,5742 ~ FILE TRAILER ~* ILE NAME :EDIT .GO1 ERVICE NAME : ERSION ~ : ATE : AXIMUM LENGTH : 1024 ILE TYPE : EXT FILE NAME : ', FILE HEADER ILE NAME :EDIT .002 ERVICE NAME : ERSION # : ATE : AXIMUM LENGTH : 1024 ILE TYPE : REVIOUS FILE : DATA FORMAT RECORD ,~ NTRY BLOCKS TYPE 2 4 9 SIZE 1 1 4 4 REPR CODE 66 66 73 65 ENTRY 0 1 20 .lin VP 010.H02 VERIFICATION LISTING PAGE 7 16 1 66 I 0 1 66 0 ATUM SPECIFICATION BLOCKS NEM SERVICE SERVICE UNIT API APl API API FILE SIZE SPL REPR PROCESS ID ORDER ~ LOG TYPE CLASS MOD NO. CODE (OCTAL)' EPT FT O0 000 O0 0 0 4 i 68 00000000000000 SFL DLL DHMM O0 270 04 0 0 .4 1 .68 00000000000000 DATA EPT 12190.8320 MSFL 306.2500 EPT 12100.1660 MSFL 4. 5977 EPT 12000.1660 MSFL 1.6270 EPT 11960.5000 MSEL 0.1963 FILE TRAILER .~ ILE NAME :EDIT .002 ERVICE NAME : ERSION # : E : AXIMUM LENGTH : 1024 ILE TYPE : EXT FILE NAME : ~ FILE HEADER ~$ ILE NAME :EDIT .003 ERVICE NAME : ERSION ~ : ATE : AXIMUM LENGTH : 1024 ILE TYPE : REVIOU$ FILE : DATA FORMAT RECORD ~ NTRY BLOCKS TYPE SIZE REPR CODE ENTRY 2 I 66 0 4 1 66 1 8 4 73 5 9 4 65 .lin 16 i 66 1 0 1 66 0 ATUM SPECIFICATION BLOCKS NEM SERVICE SERVICE UNIT API API API APl FILE SIZE SPL REPR ID ORDER ~ LOG TYPE CLASS MOD NO. CODE PROCESS (OCTAL) VP OlO.H02 VERIFICATION LISTING EPT FT O0 000 TEN DLL L& O0 000 O0 O0 PAGE 1 68 00000000000000 1 68 00000000000000 EPT 12190.9570 HTEN -38.5000 EPT 12100.2910 HTEN 1009.0000 EPT 12000.2910 HTEN 994.0000 EPT 11960.5000 HTEN 984.0000 ~ FILE TRAILER ILE NAME :EDIT .003 ERVICE NAME : ERSION # : ATE : AXIMUM LENGTH : 1024 ILE TYPE : EXT FILE NAME ;~ FILE HEADER ILE NAME :EDIT ERVICE NAME : 'ERSION # : ATE : IAXIMUM LENGTH : 10Z4 ,ILE TYPE :REVIOUS FILE : DATA FORMAT RECORD ~"~ ;NTRY BLOCKS TYPE SIZE REPR CODE ENTRY Z 1 66 0 4 1 66 1 8 4 73 10 9 4 65 .liN 16 1 66 1 0 1 66 0 IATUM SPECIFICATION BLOCKS INEM SERVICE SERVICE UNIT API API API API FILE SIZE SPL REPR PROCESS ID ORDER ~ LOG TYPE CLASS MOD ND. CODE (OCTAL) )EPT FT O0 000 O0 0 0 4 i 68 00000000000000 ;CL CNL O0 150 01 0 0 ~ 1 68 00000000000000 DATA VP 010.H02 VERIFICATION LISTING EPT EPT EPT EPT EPT EPT E PT EPT EPT EPT EPT EPT EPT 12605,9160 CCL 12600,2500 CCL 12500.2500 CCL 12400.2500 CCL 12300.2500 CCL 12200.2500 CCL 12100.2500 CCL 12000.2500 CCL 11900,2500 CCL 11800.2500 CCL 11700.2500 CCL 11600.2500 CCL 11583.5000 CCL -0.0410 -0.0410 0,1260 -0.0347 0.0620 0.0063 0.0059 0.0791 -0.0596 -0,0176 -0.0146 0.0391 -0.0342 ~ FILE TRAILER ~ ILE NAME :EDIT .004 ERVICE NAME : ERSION # : ATE : AXIMUM LENGTH : 1024 ILE TYPE : EXT FILE NAME : :~ TAPE TRAILER ~ ERVICE NAME :EDIT ~ATE :87/04/20 'RIGIN :7224 APE NAME : ONTINUATION # :01 iEXT TAPE NAME : OMMENTS :LIS TAPEr STANDARD ENDICOTT 3-35/L-36, APi 50-029-21701 REEL TRAILER ~-~ .ERVICE NAME :EDIT ~ATE :87/04/20 tRIGIN : PAGE ~P OlO.H02 VERIFICATION LISTING PAGE 10 EEL NAME :72249 )NTINUATION # :01 EXT REEL NAME : DMMENTS :LIS TAPEr STANDARD ENDICOTT 3-35/L-36, AP1 50-029-21701 ~ .... SCHLOMBERGER----~ LIS TAPE VERIFICATION LISTING VP OlO.H02 VERIFICATION LISTING PAGE I ~ REEL HEADER ¢~ ERVICE NAME :EDIT ATE :87/04/20 RIGIN : EEL NAME ONTINUATION # :O1 REVIOU$ REEL : OMMENTS :LIS TAPE, STANDARD ENOICOTT 3-35/L-36, API ¢ TAPE HEADER ~¢ ERVICE NAME :EOIT ATE :8T/04/20 RIGIN :7224 APE NAME : ONTINUATION ~ REVIOUS TAPE : OMMENTS :LIS TAPE, STANgARD ENDICOTT 3-35/L-36, ~PI :, FILE HEADER *~ ILE NAME :EDIT .001 ERVlCE NAME : ERSION ~ : .ATE : .~XIMUM LENGTH : IOZ4 ILE TYPE : REVIOUS FILE : INFORMATION RECORDS ,NEM CONTENTS UNIT TYPE CATE SIZE CODE N : STANDARD ALASKA PRODUCTION COM 000 000 030 065 N : 3-35/L-36 000 000 010 065 N : ENDICOTT 000 000 008 065 ANG: I?E 000 000 004 065 OWN: llN 000 000 004 065 .ECT: 8 000 000 002 065 OUN: NORTH SLOPE 000 000 012 065 .TAT: ALASKA 000 000 006 065 TRY: USA 000 000 003 065 tNEM CONTENTS UNIT TYPE CATE SIZE CODE 'RES: E 000 000 001 065 :~ COMMENTS ~ ~P OlO.H02 VERIFICATION LISTING PAGE SCHLUMBERGER ALASKA COMPUTING CENTER 2MPANY : STANOARD ALASKA PRODUCTION CO ELL = 3-35/L-36 IELD : ENDICOTT DUNTY = NORTH SLOPE BOROUGH TATE = ALASK~ OB NUMBER AT AKCC: 72249 UN *1, PEN HOLE DUAL LATEROLOG DATE LOGGED: Z6-MAR-8? ASED HOLE COMPENSATED NEUTRON LOGGED: 02-APR-87 DP: RICK KRUWELL ASING ASING : 9.625" @ 11989' - BIT SIZE : 12.25" TO 11989' : ?.000" @ 12640' - BIT SIZE : 8.5" TD 12643° TOP OF 7" LINER @ 11744' PEN HOLE MUD INFORMATION: YPE FLUID , = LIGNOSOLFONATE ENSITY = 10 L6/G ISCOSITY = 37 S H : 11 RM RMF RMC : 1.52 @ 65 DF : 1.28 @ 65 DF : 2.41 @ 65 DF YP O10oH02 VERIFICATION LISTING PAGE LUID LOSS : 5.9 C3 RM AT BHT : .57 @ 185 DF ATRIX SANDSTONE OTE: DUAL LATEROLOG (DLL) CHANNELS HAVE BEEN DEPTH SHIFTED TO CASED HOLE COMPENSATED NEUTRON (CNL) DUE TO THE NUMEROUS PULLS IN THE DUAL LATEROLOG. THIS WAS DONE SO AS NOT 'TO CORRUPT THE CNL DATA~ WHICH WOULD HAVE OCCUREO IF THE CNL DATA HAD BEEN SHIFTED TO THE DLL. ~..~.~ ~..,.~...,.~.~..,.~.~.~..,. .,..~.. ~.~.~.~ , ~. ~.~ -~.~ - ~- ~..~.~ .,..,.~..,.~.~k~~~~ SCHLUMBERGER LOGS INCLUDED WiTH THIS MAGNETIC TAPE: OPEN HOLE DATA: DUAL LATERLOG (DLL) DATA AVAILABLE:' 12160' TO 11984' CASE HOLE DATA: COMPENSATED NEUTRON LOG (CNL) DATA AVAILABLE: 12521' TO 11586' VP OlO.H02 VERIFICATION LISTING PAGE 4 ~ OATA FORMAT RECORD NTRY BLOCKS TYPE SIZE REPR CODE ENTRY Z 1 66 0 ~ 1 66 8 4 73 60 9 4 65 .lin 16 1 66 1 0 1 66 0 ATUM SPECIFICATION BLOCKS NEM SERVICE SERVICE UNIT API API API API FILE SIZE SPL REPR ID ORDER # LOG TYPE CLASS MOD NO. EPT FT O0 000 O0 0 0 4 LS DLL OHMM O0 220 09 0 0 4 LD DLL OHMM O0 220 10 0 0 4 ALS DLL IN O0 000 O0 0 0 4 AL1 OLL IN O0 280 01 0 0 4 P DLL MV O0 010 01 0 0 4 R DLL GAPI O0 310 01 0 0 4 VO DLL MV O0 000 O0 0 0 4 IO DLL UA O0 000 O0 0 0 4 VO DLL MY O0 PO0 O0 0 0 4 IO DLL DA O0 000 O0 0 0 4 Vl DLL MY O0 000 O0 0 0 4 RES DLL OHMM O0 823 50 0 0 4 TEM DLL DEGF O0 660 50 0 0 4 ENS DLL LB O0 635 21 0 0 4 ENS CNL LB O0 635 21 0 0 4 EVI CNL DEG O0 620 O1 0 0 4 B CNL DEG O0 631 O1 0 0 4 R CNL G~PI O0 310 O1 0 0 4 NRA CNL O0 000 O0 0 0 4 CNL CNL CPS O0 330 30 0 0 4 CNL CNL CPS O0 330 31 0 0 4 RAT CNL O0 420 01 0 0 4 PHI CNL PU O0 890 O0 0 0 4 PROCESS CODE (OCTAL) 68 00000000000000 68 00000000000000 68.00000000000000 68 00000000000000 68 0000000000'0000 68 00000000000'000 68 00000000000000 68 O0000000OO0:O00 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 DATA EPT AL1 IO 12605.5000 LLS -999.2500 SP -999.2500 SVO -999.2500 LLD -999.2500 GR -999.2500 SIO -999.2500 CALS -999.2500 DVO -999.2500 DV1 -999.2500 -999.2500 -999.2500 VP O10.HO2 VERIFICATION LISTING PAGE 5 :RES -999.2500 MTEM EVI 9.6484 RB CNL 1027.0000 NCNL EPT 12600.0000 LLS AL1 -999.2500 SP IO -999.2500 sro :RES -999.2500 MTEM EVI 8.5703 RB CNL 1027.0000 NCNL EPT 12500.0000 LLS AL1 -999.2500 SP ~IO -999.2500 SVO ~RES -999:.2500 MTEM ~EVI 8.8516 RB CNL 826.0000 NCNL EPT 12400.0000 LLS AL1 -999.2500 SP ~IO -999.2500 SVO ,RES -999.2500 MTEM EVI 34.3750 RB CNL 826.0000 NCNL .EPT 12300.0000 LLS ALi -999.2500 SP IO -999.2500 SVO RES -999.2500 MTEM EVI 34.3750 RB CNL 1171.0000 NCNL IEPT 12200.0000 LLS AL1 -999.2500 SP IO -999.2500 SVO RES -999.2500 MTEM EVI 34.3750 RB CNL 800.0000 NCNL ,EPT 12100.0000 LLS AL1 8.7031 SP ~IO 555.8125 SVO IRES 0.5178 MTEM )EVI 34.3750 RB :CNL 312.0000 NCNL )EPT 12000.0000 LLS ;ALI 10.1719 SP )IO 493.5000 SVO iRES 0.5313 MTEM )EVI 34.3750 RB :CNL 190.6250 NCNL -999.2500 TENS 44.2813 GR 2336.0000 NRAT -999.2500 LLD -999.2500 GR -999.2500 SIO -999.2500 TENS 41.6563 GR 2336.0000 NRAT -999.2500 LLD -999.2500 GR -999.2500 SIO -999.2500 TENS 10.9844 .GR 1852.0000 NRAT -999.2500 LLD -999.2500 GR -999.2500 SIO -999.2500 TENS 322.7500 GR 2052.0000 NRAT -999.2500 LLD -999.2500 GR -999.2500 SIO -999.2500 TENS 308.2500 GR 2370.0000 NRAT -999.2500 LLD -999.2500 GR -999.2500 SIO -999.2500 TENS 200.8750 GR 2029.0000 NRAT 5.7830 LLD -21.2830 GR 2.7290 SIO 185.4253 TENS 14.2344 GR 1097.0000 NRAT 8.5874 LLD -41.7188 GR 3.4551 SIO 184.1250 TENS 305.7500 GR 971.5000 NRAT -999.2500 TENS 17.9375 RNRA 2.1680 NPHI -9'99.2500 CALS -999.2500 OVO -999.2500 -999.2500 TENS 17.9375 RNRA 2.1680 NPHI -999.2500 CALS' -999.2500 DVO -999.2500 DV1 -999.2500 TENS 58.68?5 RNRA 2.5156 NPHI -999.2500 CALS -999.2500 DVO -999.2500 OVl -999.2500 TENS 18.9219 RNRA 2.4004 NPHI -999.2500 CALS -999.2500 DVO -999.2500 DV1 -999.2500 TENS 12.7578 RNRA 2.0742 NPHI -999.2500 CALS -999.2500 OVO -999.2500 DV1 -999.2500 TENS 15.8047 RNRA 2.4863 NPHI 6.4355 CALS 126.0000 OVO 684.4688 OVl 5593.6250 TENS 82.1250 RNRA 3.3320 NPHI 8.9186 CALS 118.9375 ' DVO 583.5000 OVl 5904.0000 TENS 64.9375 RNRA 4.4961 NPHI 15'75.0000 2.2734 15.3809 -999.2500 -999.2500 -999.2500 1890.0000 2.2734 15.3809 -999.2500 -999.2500 -999.2500 2574.0000 2.2402 20.4590 -999.2500 -999.2500 -999.2500 2520.0000 2.4824 18.7012 -999.2500 -999.2500 -999.2500 2520.0000 2.0234 14.0625 -999.2500 -999.2500 -999.2500 2534.0000 2.5352 20.0195 8.1641 4.0186 0.0083 2434.0000 3.5156 35.1562 10.5078 4.9453 0.0083 2470.0000 5.0938 56.3477 )EPT 11900.0000 LLS -999.2500 LLD -999.2500 CALS -999.2500 /P OiO.HOZ VERIFICATION LISTING PAGE 6 ~L1 -999.2500 SP [0 -999.2500 SVO ~ES -999.2500 MTEM fYI 34.3750 RB :NL 208.7500 NCNL EPT 11800.0000 LLS ~L1 -999.2'500 SP IO -999.2500 SVO RES -999.2500 MTEM EVI 34.3750 RB CNL 208.7500 NCNL EPT 11700.0000 LLS AL1 -999.Z500 SP I0 -999.2500 SVO RES -999.2500 MTEM EVI 34.3750 RB CNL 172.5000 NCNL EPT 11600.0000 LLS AL1 -999.2500 SP t0 -999.Z500 SVO RES -999.2500 MTEM EVI 34.3750 R8 CNL 281.2500 NCNL EPT 11581.0000 LLS AL1 -999.2500 SP I0 -999.2500 SVO RES -999.2500 MTEM EVI -999.2500 RB CNL -999.2500 NCNL * FILE TRAILER iLE NAME :EDIT ERVICE NAME : ERSION # 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