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193-170
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, July 25, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC 3-43 DUCK IS UNIT SDI 3-43 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/25/2025 3-43 50-029-22416-00-00 193-170-0 W SPT 9624 1931700 2406 2136 2144 2103 2110 5 5 4 5 4YRTST P Kam StJohn 6/7/2025 4 year 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 3-43 Inspection Date: Tubing OA Packer Depth 334 2698 2629 2610IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS250607162957 BBL Pumped:4 BBL Returned:4 Friday, July 25, 2025 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor I , 7I VI �� DATE: Tuesday, June 22, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp Alaska, LLC 3-43 FROM: Guy Cook DUCK IS UNIT SDI 3-43 Petroleum Inspector Src: Inspector Well Name DUCK IS UNIT SDI 3-43 Insp Num: mitGDC210622120526 Rel Insp Num: NON -CONFIDENTIAL Reviewed By: P.I. Supry Comm API Well Number 50-029-22416-00-00 Inspector Name: Guy Cook Permit Number: 193-170-0 Inspection Date: 6/22/2021 ✓ Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min PTD Well I93� oo T e Test I � g � - ` y YP J 2291 _ 2234 -TVD 9624 Tubing 2291 2292 YP SpT Test psi 2406 IA 724 �000 2977 - 2960 BBL Pumpet� 2.9 - ,BBL Returned: 3.1 OA o o� o - Interval � aYtzTST �P/F� P Notes: Testing done with a tripex pump, bleed trailer and calibrated gauges. ✓ Tuesday, June 22, 2021 Page 1 of I i MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,June 29,2017 TO: Jim Regg P.I.Supervisor SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC 3-43 FROM: Lou Laubenstein DUCK IS UNIT SDI 3-43 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 15 -- NON-CONFIDENTIAL Comm Well Name DUCK IS UNIT SDI 3-43 API Well Number 50-029-22416-00-00 Inspector Name: Lou Laubenstein Permit Number: 193-170-0 Inspection Date: 6/26/2017 Insp Num: mitLOL170627055826 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3-43 - Type Inj W -TVD 9624 • Tubing 2300 2188 ' 2168 - 2175 - PTD 1931700 - Type Test SPT Test psi 2406 - IA 411 2614 ' 2574 - 2560 _ BBL Pumped: 3 - BBL Returned: 3.1 - OA 10 20 • 20 . 20 _ Interval 4YRTST P/F P ✓ Notes: Wte, 2011 SCANNED AUG 2 2201:: Thursday,June 29,2017 Page 1 of 1 • • Post Office Box 244027 y Anchorage,AK 99524-4027 Hilcorp Alaska,LLC JUL 3 0 201.j 3800 Centerpoint Drive Suite 100 OGCC Anchorage,AK 99503 Phone: 907/777-8300 Fax: 907/777.-8301 July 29, 2015 Commissioner Cathy Foerster Alaska Oil & Gas Conservation Commission 0 333 West 7th Avenue, Suite 100 317 Anchorage, AK 99501 N 4- cAN S �.P aa/b Re: Duck Island Unit Well Renaming Request S 59 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 "/" followed by an obsolete bottom hole location designator. HAK would like to retain the well number as well as the "A, B, C...." sidetrack designations but remove the "/suffix". For example, "DUCK IS UNIT SDI 1-09A/L21" would become "DUCK IS UNIT SDI 1-09A". The attached spreadsheet includes original and new names for all Duck Island wells. While performing the review of Duck Island well names, HAK found a single well, "DUCK IS UNIT SDI 4-20/M35" (PTD# 1861730), that should also be modified to include an "A" label to reflect the fact that the well is a sidetrack from the original "DUCK IS UNIT SDI 4-20/T34" (PTD # 1861500). The original wellbore, abandoned 10/13/1986, was sidetracked to a new bottom hole location completed on 9/9/1987. This well appears to be one of the first sidetracks performed at Endicott. While the bottom hole code was changed, no letter was added to reflect the sidetrack. "DUCK IS UNIT SDI 4-20A" is also included on the attached spreadsheet. Sincerely, Wyatt Rivard Well Integrity Engineer Hilcorp Alaska, LLC CC Dave Roby Victoria Loepp . Orig • New I API_WeilNo I PermitNumberl 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 3-39/139 3-39 50029217640100 1970910 DUCK IS UNIT SDI 3-39A/137 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/J40 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/Q28 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/Q32 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 XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. 1 ~ ~" /'F~O File Number of Well History File PAGES TO DELETE RESCAN Complete [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original - Pages: Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs'of various kinds . [] Other COMMENTS: Scanned by; iann~Vincent Nathan Lowell [] TO RE-SCAN Notes' Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ ( ) -4 3 41) 6 1g317oo ;Regg,'James B (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWelllntegrityCoordinator @bp.com] -e,�,�6 ( ,A,li3 Sent: Friday, June 14, 2013 8:30 AM (� To: AK, OPS END OIM; AK, OPS END Facility& FieldO&M TL; AK, OPS END Board Operator; AK, OPS END AES Drillsite Lead; AK, OPS END Operations Lead Tech; AK, RES END Production Optimization Engineer; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; Cinelli, Steven; Regg, James B (DOA); Schwartz, Guy L(DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; Climer, Laurie A Subject: UNDER EVALUATION: Injector END3-431P-36 (PTD#1931700) Ready for Injection Attachments: 3-43 wellbore schematic.pdf All, Injector END3-43/P-36 (PTD# 1931700) underwent a rig workov_e_r_completed on 04/13/2013 to repair a surface casing leak. The well passed a MIT-IA to 4000 psi on 04/13/2013 during rig operations. The well is reclassified as Under Evaluation and injection can commence. Plan forward: 1. Endicott Operations: Place well on injection 2. Fullbore: Perform AOGCC witnessed MIT-IA after well is thermally stable - A copy of the wellbore schematic has been included for reference. Please call with any questions. Thanks, Laurie Climer SCANNED FEB 2 0 2014 (Alternate:Jack Disbrow) BP Alaska - Well Integrity Coordinator rniu I t�;t �, t CStgar+mt.on WIC Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinator @BP.com 1 TREE= 4-1/16"DRY HOLE SP 'NOTES:H2S READINGS AVERAGE 230- oD= 10-3/4 C EN D3-43 260rr'MONA/L&GAS INJECTORS"••WELL NfTIA'L KB.ELEV- 56' REQUIRES A 555V BF.ELEV= 14.50' I 11 *11 l KOP= 322' 11 1 AMI 1503' —4-112"HES XXO SSSV NP,D=3.813' Max Angie= 11°@ 8232' I* © �•' Datum MD= 10143' •11• •�� 1812' -7-5/8"HES ES f1 RAeJT>R• Datum ND= 10000 SS I. �1*/ I 1835' I 7-5/8'LNR PATCH,29.7#,L-80 VAM TOP, --{ 1857' -7-5/8"t50ZONE IXT CSG PKf�D=6.83' .0569 bpf,13=6.94' 10-3/4"CSG,45.5#,NT80 BTRS,ID=9.950' - 2740' Minimum ID = 3.725" @ 9818' 4-1/2" HES XN NIPPLE I 9680' —{4-1/2"HES X NP,D=3.813' Krill 9710' H7-5/8'X 4-1/2'HES TNT FKR,ID=3.856' ' 9745' -4-1/2"t-ES X NP,D=3.813" ' 9818' —4-1/2'HES XN NP,ID=3.725" 4-112'TBG,12.6#,L-80 TCII, H 9834' - D=.0152 bpf,D=3.958' 9836' - W 4-112" LEG(9 CR), 3.958' PERFORATION SUMMARY ? -EL MD TT NOT LOGGED REF LOG: SLB on 05/02/94 ANGLE AT TOP PE RE:2°@ 10010' Note:Refer to Production DB for historical pert data SIZE SPF NT1 RVAL Opn/Sqz SHOT SQZ ' 2' 4 10010-10080 0 03/22/99 r 2-1/2 4 10106-10114 0 10/27/95 ' 2-1/2" 4 10108-10112 0 04/04/95 2-1/8" 4 10132-10140 S 05/25/94 02/03/95 2-1/2" 4 10132- 10140 0 10/27/95 2-1/8" 4 10132- 10140 0 02/06/95 1,..„...-4 10190' —FILL(TAGGED 04/10/13 RIG) 2-1/8" 4 10154- 10156 S 05/25/94 02/03/95 gv• vvir•• 10198' —{TOP OF CBNENT CAP(02/07/10) 2-1/8" 4 10162-10164 S 05/25/94 02/03/95 1111111111111111111111 2' 4 10170- 10190 0 03/22/99 l����l �.ea 10220' -SAND PLUG(02/05/10) 2-1/8" 4 10222-10245 S 05/25/94 02/03/95 r 2-5/8 4 10228-10245 C 03/01/95 2-1/2" 4 10228-10245 C 10/27/95 2-1/8' 4 10287- 10291 S 05/25/94 02/03/95 10386' —POST SQZ TD(02/04/95) 2-1/2' 6 10287- 10307 C 06/02/05 ' —10386' 1--FISH-CENTRALIZER ARM(07/24/94) 2112" 6 10315 10335 C 06/02/05 • 2-1/8" 4 10108-10112 S 05/25/94 02/03/95 10413' -ELM TD(05/26/94) ..1 1111111111 11/ • ♦1111 A V 1.1.1.1.1.1.1.1.1.1.1.1; PBTD H 10478' 1 •1.......•F1• 1111111111111111111111 7-5/8'LNR,29.7#,NT95HS NSCC, —I 10558' ).��1.��1�... 1� .0459 bpf,ID=6.875" DATE REV BY COMENTS DATE REV BY COMANTS E DICOTT UNT 05/25/94 D-15 INITIAL COMPLETION WELL 3-43/P-36 12/20/94 D-15 RWO FERMI No: 1931700 04/13/13 D-14 RWO AR No: 50-029-22416-00 04/18/13 PJC DRLG HO CORRECTIONS SEC 8,T11 N,R17E,2503'FNL&640'FEL 05 101/13 JNL/JMD DRAWNG CORRECTIONS 05/08/13 DB/JM) DRLG HO COMR-EIE BP Exploration(Alaska) 1 ' STATE OF ALASKA RECEIVED S KA OIL AND GAS CONSERVATION C MISSION REPORT OF SUNDRY WELL OPERATIONS MAY 0 7, 2013 1. Operations Performed: AOUCC„r ❑ Abandon ® Repair Well ❑ Plug Perforations ❑ Perforate ❑ Re -Enter Suspended Well ® Alter Casing IS Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Stimulate - Other ❑ Time Extension 2. Operator Name: .. 4. Well Class Before Work: ✓ 5. Permit To Drill Number: ,, BP Exploration (Alaska) Inc. ❑ Exploratory ❑ Stratigraphic 193 - 170 3. Address: ❑ Development ® Service 6. API Numbe ✓ P.O. Box 196612, Anchorage, Alaska 99519 - 6612 50 029 - 22416 - 00 - 00 7. Property Designation (Lease Number): J 8. Well Name and Number: ✓ ADL 047502 & 047503 3 - 43/P - 9. Logs (list logs and submit electronic and printed data per 20AAC25.071): 10. Field / Pool(s): ✓ USIT Endicott Field / Endicott Pool 11. Present well condition summary: Total depth: measured 10565' feet Plugs:(measured) 10198' feet true vertical 10478' feet Junk: (measured) 10386' feet Effective depth: measured 10478' feet Packer: (measured) 1503', 9710' feet true vertical 10391' feet Packer: (true vertical) 1496', 9624' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 87' 30" 44' - 131' 44' - 131' Surface 2697' 10 -3/4" 43' - 2740' 43' - 2731' 5210 2480 Intermediate 10516' 7 -5/8" 42' - 10558' 42' - 10471' 8180 5120 Production Liner SCPJt ..�u� 02 3 Perforation Depth: Measured Depth: 10010' - 10335' feet True Vertical Depth: 9923' - 10248' feet Tubing (size, grade, measured and true vertical depth): 4 -1/2 ", 12.6# L -80 9836' 9750' Packers and SSSV (type, measured and true vertical depth): 4 -1/2" HES XXO SSSV Nipple 1503', 9710' 1496', 9624' 7 -5/8" x 4 -1/2" HES TNT Packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Pull 3 -1/2" Tubing, Cut and pull 7 -5/8" Casing at 1856', Run 7 -5/8 ", 29.7 #, L -80 Casing to 1857', Cement with 116 Bbls (557 sx) Class 'G' and Run 4 -1/2 ", 12.6 #, L -80 Tubing. 13 Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 750 795 Subsequent to operation: 0 150 0 14. A ttac hm e n ts : ❑Copies of Logs and Surveys run 15. Well Class after work: ✓ ❑ Exploratory ❑ Stratigraphic ❑ Development ® Service IS Daily Report of Well Operations 16. Well Status after work: ✓ ❑ Oil ❑ Gas ❑ WDSPL ® Well Schematic Diagram ❑ GSTOR IS WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact: David Bjork, 564 -5683 Email: David.Bjork @bp.com 313 - 020 Printed Na • Jo LIjrI , - Title: Drilling Technologist RBDMS MAY - 9 20 Signature: \ 1 I ' Phone: 564 - 4091 Date: 5!i! /3 Form 10-404 Revised 10/2012 Vi—F 7//// 3 ' / ,Submit Original Only • • ' f,:, A ; ¢ z - �, ,, r E� , j ¢`� � ?' = � � v� � � � � ��� � � • � e g- a p ` 2 181 1 1 tl .R �" °,i.�� `sr� _ �` +. '„ ?. - '`` - ' F w - . Common Well Name: 3-43 AFE No Event Type: WORKOVER (WO) Start Date: 3/31/2013 End Date: 4/13/2013 X4- 00X5N -E:RIG (5,417,000.00 ) Project: Endicott Site: End SDI Rig Name/No.: DOYON 14 Spud DateTme: 4/15/1994 12:00 :00AM Rig Release: 4/13/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: 48 : 43 4/15/1994 00:00 @56.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 3/31/2013 07:30 - 08 :30 1.00 MOB P PRE SKID RIG FLOOR INTO MOVING POSITION. -PJSM, SKID FLOOR. 08:30 - 09:30 1.00 MOB P PRE MOVE RIG OFF OF WELL 1 -63. -PJSM, JACK UP RIG AND PULL OFF. 09:30 - 14:00 4.50 MOB P PRE RIG MOVE. -PJSM, MOVE RIG FROM ENDICOTT MPI PAD TO ENDICOTT SDI E3 -43I. 14:00 - 15:00 1.00 MOB P PRE MOVE RIG OVER WELL E3 -431. -PJSM, SPOT RIG OVER WELL E3-43I AND SHIM UP. *FUNCTION TEST MOVING SYSTEM EMERGENCY SHUTDOWN. GOOD. ** AOGCC BOB NOBLE WAIVED WITNESS OF TEST AT 14:56 3/31/31 VIA EMAIL. 15:00 - 18:00 3.00 MOB P PRE SKID RIG FLOOR AND SPOT RIG EQUIPMENT INTO LOCATION. -PJSM, SKID FLOOR. -SPOT ROCKWASHER INTO POSITION. -MAKE UP HIGH PRESSURE MUD LINES AND SERVICE LINES TO RIG FLOOR. -MOVE DDI BREAK TRAILER INTO POSITION. -MOVE LEPD TANK INTO POSITION. 18:00 - 20:00 2.00 MOB P PRE SPOT EQUIPMENT. -SPOT FLOW BACK TANK -SPOT CHOKE SKID. -RIG UP HARD LINE TO FLOWBACKTANK * DOYON 14 RIG ACCEPTED ON 3/31/2013 AT 18:00 HOURS. 20:00 - 20:30 0.50 MOB P PRE HOLD RIG EVACUATION /H2S DRILL. -ALL PERSONAL MUSTERED AT SAFE AREA IN 3 MINUTES 30 SECONDS. - CONDUCT AFTER ACTION REVIEW. 20:30 - 21:00 0.50 WHSUR P WHDTRE PREP TO CIRCULATE DIESEL FROM WELL. -PJSM, RIG UP CIRCULATING LINES IN CELLAR. 21:00 - 23:00 2.00 WHSUR P WHDTRE PICKUP LUBRICATOR. -PJSM, PICK UP LUBRICATOR TEST TO 250/4000 PSI. FOR 5 MINUTES EACH. 23:00 - 23 :30 0.50 WHSUR P WHDTRE PULL BACK PRESSURE VALVE. -INNER ANNULUS 0 PSI, OUTER ANNULUS 0 PSI, TUBING 0 PSI. - REMOVE LUBRICATOR FROM TREE 23:30 - 00:00 0.50 WHSUR P WHDTRE RIG UP TREE WITH MANIFOLD TO PUMP BOTH WAYS. -PJSM, RIG UP TO PUMP DOWN INNER ANNULUS AND TUBING TAKING RETURNS TO THE SLOP TANK -OUTER ANNULUS PRESSURE = 0 PSI 4/1/2013 00:00 - 01:30 1.50 WHSUR P WHDTRE PREPARE TO CIRCULATE DIESEL OUT OF WELL. -PJSM, RIG UP CIRCULATING LINE IN THE CELLAR. -TEST HARD LINE TO 250/4000 PSI. -HOLD EVACUATION /H2S DRILL WITH RIG CREW, TOUR PUSHER, WSL WITH AFTER ACTION REVIEW. Printed 4/22/2013 10:26:38AM • 3' } r z:JK •W(f4a# Common Well Name: 3-43 AFE No Event Type: WORKOVER (WO) Start Date: 3/31/2013 End Date: 4/13/2013 X4- 00X5N -E:RIG (5,417,000.00 ) Project: Endicott Site: End SDI Rig Name/No.: DOYON 14 Spud Date/Time: 4/15 /1994 12:00:00AM Rig Release: 4/13/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: 48 : 43 4/15/1994 00:00 ©56.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) usft 01:30 - 03:00 1.50 WHSUR P WHDTRE FLUID PACK AND TEST SURFACE LINES. -PJSM FLUID PACK AND TEST SURFACE LINES TO 250/4000 PSI FOR 5 MINUTES EACH. 03:00 - 04:30 1.50 WHSUR P WHDTRE CIRCULATE DIESEL OUT OF TUBING AND INNER ANNULUS. -PJSM, CIRCULATE 10 BARRELS 120 DEGREE 1% KCLAT 2 BARRELS PER MINUTE AT 1200 PSI DOWN THE INNER. ANNULUS TAKING RETURNS OUT OF THE TUBING. - CIRCULATE 50 BARRELS 120 DEGREE 1% KCLAT 2 BARRELS PER MINUTE AT 1340 PSI DOWN THE TUBING TAKING RETURNS OUT OF THE INNER ANNULUS. -BLOW DOWN SURFACE LINES USED FOR CIRCULATING OUT DIESEL. -REMOVE LINES FROM TREE USED TO CIRCULATE OUT DIESEL. 04:30 - 06:30 2.00 WHSUR P WHDTRE INSTALL TWO WAY CHECK -PJSM, INSTALL LUBRICATOR AND TEST TO 250/4000 PSI FOR 5 MINUTES EACH. - INSTALL TWO WAY CHECK 06:30 - 09:00 2.50 WHSUR P WHDTRE PRESSURE TEST TWO WAY CHECK -PJSM, PRESSURE UP ON TWC FROM BELOW THROUGH INNER ANNULUS TO 4000 PSI. AND HOLD FOR 30 MINUTES. - PRESSURE TEST FROM ABOVE 250 PSI LOW, AND 4000 PSI HIGH FOR 5 MINUTES, BOTH TESTS GOOD. 09:00 - 10:30 1.50 WHSUR P WHDTRE NIPPLE DOWN THE TREE. -PJSM, NIPPLE DOWN TREE AND ADAPTER FLANGE. -DE- ENERGIZE THE VOID. -CAP THE CONTROL LINE. - INSPECT HANGER NSCT THREADS (8-1/2 TURNS). 10:30 - 13:30 3.00 BOPSUR P WHDTRE NIPPLE UP BOPE. -PJSM, NIPPLE UP BOPE, TORQUE BOLTS, TIGHTEN TURNBUCKLES. -OUTER ANNULUS PRESSURE = 0 PSI 13:30 - 15:30 2.00 BOPSUR P WHDTRE RIG UP TO TEST BOPE. -MAKE UP CROSSOVERS FOR HANGER. -MAKE UP FULL OPENING SAFETY VALVE WITH DART AND MAKE UP 4-1/2" IF FULL OPENING SAFETY VALVE. WELL CONTROL DRILL, 60 STROKES TO FILL GAS BUSTER - RESPONSE TIME: 2 MINUTES AND 35 SECONDS, AAR HELD AFTER DRILL 15:30 - 00:00 8.50 BOPSUR P WHDTRE TEST BOPE. -TEST BAG WITH 3-1/2" TEST JOINT TO 250 PSI LOWAND 3500 PSI HIGH FOR 5 MINUTES. -TEST REST OF EQUIPMENT TO 250 PSI LOW AND 4000 PSI HIGH FOR 5 MINUTES, WITH 3-1/2" AND 4-1/2" TEST JOINTS. " AOGCC BOB NOBLE WAIVED WITNESS OF TEST AT 14:56 3/31/31 VIA EMAIL. -OUTER ANNULUS PRESSURE = 0 PSI 4/2/2013 00:00 - 02:00 2.00 BOPSUR P WHDTRE CONTINUE TO TEST BOPE. -PJSM, CONTINUE TO TEST BOPE WITH 4" TEST JOINT. Printed 4/22/2013 10:26:38AM • Common Well Name: 3-43 AFE No Event Type: WORKOVER (WO) Start Date: 3/31/2013 End Date: 4/13/2013 X4- 00X5N -E:RIG (5,417,000.00 ) Project: Endicott Site: End SDI Rig Name/No.: DOYON 14 Spud Date/Time: 4/15/1994 12:00:00AM Rig Release: 4/13/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: 48 : 43 4/15/1994 00:00 ©56.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 02:00 - 03:00 1.00 BOPSUR P ■ - WHDTRE RIG DOW BOPS TEST EQUIPMENT. -PJSM, RIG DOWN TEST EQUIPMENT, BLOW DOWN CHOKE AND KILL LINES. 03:00 - 05:30 2.50 DHB P DECOMP PULL TWO WAY CHECK VALVE. -PJSM, RIG UP DUTCH RISER AND CLOSE ANNULAR. -FILL WITH WATER AND INSTALL LUBRICATOR. -TEST LUBRICATOR TO 250 PSI LOW AND 3500 PSI FOR 5 MINUTES EACH. - REMOVE TWO WAY CHECK FROM TUBING HANGAR. 0 PSI ON TUBING. -RIG DOWN LUBRICATOR AND DUTCH RISER. 05:30 - 08:00 2.50 MOB P DECOMP MOBILIZE TOOLS TO FLOOR FOR PULLING 3.5" TUBING WITH CONTROL LINE. -PJSM, BEAVER SLIDE OPERATIONS. -BRING SPOOLER, HANDLING EQUIPMENT AND HYDRAULIC TONGS UP TO RIG FLOOR. - INSTALL BAILS, INSTALL 4" ELEVATORS. -MAKE UP 1 JOINT 4" DRILL PIPE WITH CROSSOVERS TO SCREW INTO HANGER. 08:00 - 09:00 1.00 BOPSUR P DECOMP VACUUM OUT BOPE STACK IN PREPARATION TO PULL HANGER. 09:00 - 10:00 1.00 PULL P DECOMP PULL HANGER. -PJSM MAKE UP LANDING JOINT TO HANGER. -BACK OUT LOCK DOWN SCREWS. -PULL HANGER TO RIG FLOOR, PULLED 140K. -DE- MOBILIZE CONTROL LINE AND CUT 30' TO MAKE SLICK PIPE TO CLOSE BAG. -SLACK OFF, SLACK OFF WEIGHT 128 K. -LINE UP FOR CIRCULATION. 10:00 - 11:30 1.50 PULL P DECOMP CIRCULATE BOTTOMS UP THROUGH CHOKE. -PJSM, CLOSE BAG. - CIRCULATE BOTTOMS UP THROUGH THE CHOKE MANIFOLD AT 6 BARRELS PER MINUTE AT 710 PSI INITIAL CIRCULATING PRESSURE, 750 PSI FINAL CIRCULATING PRESSURE. -MAKE UP FLOOR SAFETY VALVE. 11:30 - 12:00 0.50 PULL P DECOMP LAY DOWN LANDING JOINT AND HANGER. -PJSM, REMOVE HANGER, MAKE UP SAFETY JOINT AND LAY DOWN TO PIPE SHED. -BLOW DOWN TOP DRIVE, CHOKE LINE AND MANIFOLD. - CHANGE OUT ELEVATORS. 12:00 - 13:30 1.50 PULL P DECOMP PULL AND LAY DOWN 3.5" 9.5 PPF L-80 8 -ROUND TUBING. -PJSM, PULL OUT OF THE HOLE FROM 9,745' TO SUB SURFACE SAFETY VALVE. -OUTER ANNULUS PRESSURE = 0 PSI AT 13:00 13:30 - 14:30 1.00 PULL P DECOMP CAP LINES ON SUB SURFACE SAFETY VALVE AND LAY DOWN SPOOLING UNIT. *47 BANDS RECOVERED 1 BAND MISSING. DISCUSSED WITH ENGINEER AND NO ACTION TO BE TAKEN TO RECOVER THE MISSING BAND. Printed 4/22/2013 10:26:38AM • • • f = �:..�r f r �' �. $ .� s � b :.s x � t,,✓� g��o � s .ham ��'�vx" =� .u" .�� *�.s?�. '' f } 5 �a 's �x x - ' �` , f; , f� . °i 5 r y, , 3 r-3C,s . + .at?'..,: ...- x , .. . .,t ., _ a_.,._ ,.., ¢ , a Common Well Name: 3-43 AFE No Event Type: WORKOVER (WO) Start Date: 3/31/2013 End Date: 4/13/2013 X4 -00X5N -E:RIG (5,417,000.00 ) Project: Endicott Site: End SDI Rig Name/No.: DOYON 14 Spud DateTme: 4/15/1994 12:00:00AM Rig Release: 4/13/2013 Rig Contractor. DOYON DRILLING INC. UWI: Active datum: 48 : 43 4/15/1994 00:00 @56.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14:30 - 22:00 7.50 PULL P DECOMP CONTINUE TO PULL AND LAY DOWN 3.5" 9.5 PPF L -80 8 -ROUND TUBING. -304 JOINTS OF 3.5" 9.5 PPF L -80 8 -ROUND TUBING, 1 CUT 6'3" JOINT OF 3.5" 9.5 PPF L -80 8 -ROUND TUBING(CLEAN CUT -TUBE FLARED TO 4" OD AT CUT), 6 GAS LIFT MANDRELS, 1 SUB SURFACE SAFETY VALVE RECOVERED 22:00 - 23:00 1.00 PULL P DECOMP RIG DOWN TUBULAR HANDLING EQUIPMENT. -PJSM, BEAVER SLIDE OPERATIONS, LAY DOWN STACK TONGS AND TUBULAR HANDLING TOOLS. 23:00 - 23:30 0.50 WHSUR P DECOMP INSTALL WEAR RING. -PJSM, INSTALL WEAR RING ID 8.75" OD 13.375 ", LENGTH 12.5 ". -OUTER ANNULUS PRESSURE = tr PSI AT 23:00 HOURS. 23:30 - 00:00 0.50 CASING P DECOMP PICK UP E -LINE TOOLS AND EQUIPMENT. -PJSM WITH SLB E -LINE CREW AND BRING _TOOLS TO RIG FLOOR. 4/3/2013 00:00 - 05:00 5.00 EVAL P DECOMP USIT LOGGING. -PJSM, MAKE UP LOGGING TOOLS, TEST LOGGING TOOLS AT SURFACE. -START RUN IN HOLE AT 0130 HOURS TO A DEPTH OF 2950. -LOG UP WITH REPEAT PASS AND PULL OUT OF THE HOLE. -PJSM, LAY DOWN LOGGING TOOLS AND DOWNLOAD LOGS. -SEND LOGS TO RIG WORKOVER ENGINEER. 05:00 - 08:00 3.00 EVAL P DECOMP ANALYZE LOG DATA. PJSM, MOBILIZE HALLIBURTON RETRIEVABLE BRIDGE PLUG TO RIG FLOOR. 08:00 - 10:00 2.00 DHB P DECOMP RUN IN THE HOLE WITH RETRIEVABLE BRIDGE PLUG. -PJSM MAKE UP HES RETRIEVABLE BRIDGE PLUG AND RUN IN THE HOLE TO 1984'. 10:00 - 12:00 2.00 DHB P DECOMP SET AND TEST RETRIEVABLE BRIDGE PLUG. -PJSM, CIRCULATE 3 BARRELS PER MINUTE AT 50 PSI. -WORK PACKER THROUGH TO SETTING DEPTH AT 1976'. -PICK UP FOR OVER PULL 10K, PICK UP WEIGHT AT 81K, SLACK OFF WEIGHT 83K. -CLOSE BAG, TEST AT 250 PSI LOW AND 3500 PSI HIGH -TEST FAILURE. -BLEED PRESSURE OFF AND CIRCULATE 30 MORE BARRELS TO CHECK FOR AIR. -CLOSE MANUAL IBOPAND LINE UP THROUGH KILL LINE. -CLOSE BAG TEST 250 PSI LOW AND 3500 PSI HIGH -TEST PASS. "KICK WHILE TRIPPING DRILL HELD, RESPONSE TIME 1 MINUTE AND 5 SECONDS. -OUTER ANNULUS PRESSURE = 0 PSI. 12:00 - 13:00 1.00 DHB P DECOMP BLOW DOWN LINES. -PJSM, STAND BACK (1) JOINT OF DRILL PIPE IN DERRICK. -DRAIN BOPE STACK. -BLOW DOWN CHOKE MANIFOLD, TOP DRIVE AND CHOKE AND KILL LINES. Printed 4/22/2013 10:26:38AM • Common Well Name: 3-43 AFE No Event Type: WORKOVER (WO) Start Date: 3/31/2013 End Date: 4/13/2013 X4 -00X5N -E:RIG (5,417,000.00 ) Project: Endicott Site: End SDI Rig Name/No.: DOYON 14 Spud Date/Time: 4/15/1994 12:00:00AM Rig Release: 4/13/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: 48 : 43 4/15/1994 00:00 ©56.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 13:00 - 13:30 0.50 DHB P ■- DECOMP PICKUP RIVER SAND. -PJSM, BEAVER SLIDE OPERATIONS, PICK UP #1350 OF RIVER SAND. 13:30 - 15:00 1.50 DHB P ■- DECOMP INSTALL SAND HOPPER. -DUMP MP #1350 OF RIVER SAND ON TOP OF THE RETRIEVABLE BRIDGE PLUG. 15:00 - 15:30 0.50 DHB P DECOMP CLEAR DRILL PIPE AND BHA OF SAND. -PUMP DRILL STRING VOLUME AT 5 BARRELS PER MINUTE AT 100 PSI. -BLOW DOWN TOP DRIVE AND LINE UP TO CIRCULATE OVER THE TOP OF THE HOLE TO TRIP TANK 15:30 - 16:00 0.50 DHB P ■- DECOMP ALLOW RIVER SAND SETTLE. -RU I -RUN IN THE HOLE WITH 1 JOINT OF 4" DRILL PIPE AND TAG UP AT TOP OF SAND AT 1921'. 16:00 - 18:00 2.00 DHB P -_ DECOMP PULL OUT OF THE HOLE WITH DRILL PIPE TO RETRIEVABLE BRIDGE PLUG RUNNING TOOL 18:00 - 21:00 3.00 BOPSUR P DECOMP CHANGE OUT UPPER RAMS. - PJSM,SUCK OUT BOPE STACK -PULL WEAR RING AND INSTALL UPPER TEST PLUG. -SHUT IN BLIND SHEAR RAMS. —PJSM, SWAP UPPER RAMS FROM 3.5 "x 6" VARIABLES TO 7 5/8" SOLIDS - INSTALL 7.875" TEST JOINT. -TEST 250 PSI LOW AND 4000 PSI HIGH FOR 5 MINUTES EACH -TEST PASSED. 21:00 - 21:30 0.50 BOPSUR P ■ DECOMP PULL TEST PLUG. -PULL TEST JOINT. - INSTALL WEAR RING, ID 8.75. 21:30 - 22:00 0.50 CUT P DECOMP MOBILIZE BAKER BHA TO RIG FLOOR. -PJSM WITH BAKER SERVICE HANDS AND BEAVER SLIDE OPERATIONS. -PICK UP BAKER TOOLS TO RIG FLOOR 22:00 - 00:00 2.00 CUT P DECOMP MAKE UP BAKER MULTI STRING CUTTER BHA #1. -MAKE UP STABILIZER AND MULTI STRING CUTTER. -PICK UP 4" DRILL PIPE SINGLES FROM PIPE SHED AND RUN IN THE HOLE. -PICK UP XT -39 FOSV AND 1 4" DRILL PIPE AND SCREW INTO TOP DRIVE. -OUTER ANNULUS PRESSURE = 0 PSI. 4/4/2013 00:00 - 01:00 1.00 CUT P DECOMP PRESSURE TEST LITTLE RED LINES. -PJSM WITH BAKER AND LITTLE RED AND CH2 HANDS ON UPCOMING OPERATIONS. -MAKE 2 ATTEMPTS TO LOCATE COLLARS ABOVE CUT DEPTH OF 1856 WITH NO SUCCESS. -SPACE OUT AND CUT TUBING. Printed 4/22/2013 10:26:38AM • • Common Well Name: 3-43 AFE No Event Type: WORKOVER (WO) Start Date: 3/31/2013 End Date: 4/13/2013 X4 -00X5N -E:RIG (5,417,000.00 ) Project: Endicott Site: End SDI Rig Name/No.: DOYON 14 Spud Date/Time: 4/15/1994 12:00:00AM Rig Release: 4/13/2013 Rig Contractor. DOYON DRILLING INC. UWI: Active datum: 48 : 43 4/15/1994 00:00 ©56.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 01:00 - 02:30 1.50 CUT P DECOMP CUTTING OPERATIONS ON 7 -5/8" CASING. - OBTAIN SLOW PUMP RATES. - LOCATE COLLARS, OBTAIN OPERATIONAL PARAMETERS. -PICK UP WEIGHT 81 K, SLACK OFF WEIGHT 83 K ROTATE AT 80 RPM AT 801<, FREE TORQUE 1 K. -SET ON DEPTH AT 1856'. -START ROTATION AT 80 RPM, STAGE PUMPS UP TO 5.7 BARRELS PER MINUTE AT 650 PSI. -CUT CASING, PRESSURE DROP NOTICED, STOPPED ROTATING. -PICK UP TO CONFIRM CUT, PRESSURE INCREASE SEEN. -SLACK OFF TO CONFIRM CUT, PRESSURE DROP NOTICED. -PICK UP TO FLOOR VALVE AND CLOSE. -BACK OUT 1 JOINT OF 4" DRILL PIPE AND THE TOP DRIVE. -LAY DOWN JOINT OF DRILL PIPE. -BLOW DOWN THE TOP DRIVE. - INSTALL CIRCULATION SUB, SWING AND 1/4 TURN VALVE AND CEMENT HOSE. 02:30 - 03:30 1.00 CUT P DECOMP - CIRCULATE OUT FREEZE PROTECT AND MUD. -PJSM WITH LITTLE RED AND RIG CREW. -LINE UP LITTLE RED AND PUMP 20 BARRELS OF 90 DEGREE DIESEL AT 1.25 BARRELS PER MINUTE AT 300 PSI. -SHUT DOWN PUMP AND CLOSE ANNULAR. -LINE UP TO CIRCULATE THROUGH THE CUT AND INTO THE 7 5/8" X 10 3/4" ANNULUS TAKING RETURNS FROM THE OUTER ANNULUS VIA THE CHOKE SKID TO THE OUTSIDE TANK - LITTLE RED PUMP 30 BARRELS OF 90 DEGREE DIESEL AT 1.25 BARRELS PER MINUTE AT 300 PSI. -SHUT DOWN AND LINE UP TO PUMP. -PUMP 20 BARRELS OF 9.8 PPG BRINE AT 2 BARRELS PER MINUTE. -SHUT DOWN, CLOSE WELL AND LET SOAK 03:30 - 04:30 1.00 CUT P DECOMP ALLOW DIESEL TO SOAK. 04:30 - 07:30 3.00 CUT P DECOMP - CIRCULATE AND CONDITION 7 5/8" X 10 3/4" ANNULUS. -PUMP 80 BARRELS OF 9.8 HEATED BRINE AT 2 BARRELS PER MINUTE AT 120 PSI. - INCREASE RATE TO 4.5 BARRELS PER MINUTE AT 700 PSI FOR 190 BARRELS. -PUMP 95 BARRELS OF 8.5 PPG SEA WATER. -SHUT DOWN PUMPS AND CHECK PRESSURE. -OPEN BAG AND MONITOR WELL FOR 10 MINUTES. 07:30 - 08:00 0.50 CUT P DECOMP SUCK OUT BOPE STACK -PJSM, BLOW DOWN CHOKE LINES AND MANIFOLD. 08:00 - 08:30 0.50 CASING P DECOMP MONITOR WELL. -GET ZERO MARK AND MONITOR WELL. -PJSM PULL OUT OF THE HOLE WITH MULTI STRING CUTTER FROM 1844'. Printed 4/22/2013 10:26:38AM • Common Well Name: 3-43 AFE No Event Type: WORKOVER (WO) Start Date: 3/31/2013 End Date: 4/13/2013 X4- 00X5N -E:RIG (5,417,000.00 ) Project: Endicott Site: End SDI Rig Name/No.: DOYON 14 Spud Date/Time: 4/15/1994 12:00:00AM Rig Release: 4/13/2013 Rig Contractor. DOYON DRILLING INC. UWI: Active datum: 48 : 43 4/15/1994 00:00 ©56.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 08:30 - 09:30 1.00 CASING P DECOMP RIG UP TO PULL 7-5/8" CASING. -PJSM, BEAVER SLIDE OPERATIONS. -SUCK OUT BOPE STACK, PULL WEAR RING. 09:30 - 12:00 2.50 CASING N DECOMP SAFETY SHUT DOWN WITH MORNING TOUR RIG CREW. - REVIEW DROPPED OBJECT INCIDENTS AND CURRENT BP AND DOYON POLICIES. - CONDUCT HAZARD HUNT AROUND RIG AND LOCATION FOCUSING ON DROPPED OBJECTS. -OUTER ANNULUS PRESSURE = 0 PSI. 12:00 - 12:30 0.50 CASING P DECOMP MORNING TOUR AND EVENING TOUR CREW CHANGE -CREW CHANGE WITH RELIEFS - EVENING TOUR CREW PERFORM PRE -TOUR RIG CHECKS FOR EQUIPMENT AND BOP EQUIPMENT 12:30 - 15:30 3.00 CASING N DECOMP SAFETY SHUT DOWN WITH EVENING TOUR RIG CREW. - REVIEW DROPPED OBJECT INCIDENTS AND CURRENT BP AND DOYON POLICIES. - CONDUCT HAZARD HUNT AROUND RIG AND LOCATION FOCUSING ON DROPPED OBJECTS. - PERFORMED COMPLETE DERRICK INSPECTION - PERFORMED THOUROUGH AND COMPLETE TOP DRIVE INSPECTION 15:30 - 16:30 1.00 CASING P DECOMP PULL AND LAY DOWN HANGER AND SPEAR. -PJSM WITH BAKER SERVICE PERSONNEL AND FMC HAND FOR PULLING HANGER. -MAKE UP GRAPPLE. -RUN IN HOLE TO NO GO. -FMC BACK OUT LOCK DOWN SCREWS. - PULLED TO 120 K THEN TO 135 K 3- TIMES. - PULLED FREE, BROUGHT HANGER TO RIG FLOOR. -LAY DOWN HANGER AND SPEAR. 16:30 - 17:30 1.00 CASING P DECOMP CLEAN RIG FLOOR OF ALL TOOLS AND EQUIPMENT NOT NEEDED FOR OPERATIONS. -RIG UP TO CIRCULATE BOTTOMS UP AT 12.5 BARRELS PER MINUTE AT 120 PSI. 17:30 - 18:30 1.00 CASING P DECOMP MAKE UP SAFETY JOINT AND CROSSOVERS. -BLOW DOWN THE TOP DRIVE. 18:30 - 21:00 2.50 CASING P DECOMP PULL OUT OF THE HOLE WITH 7 -5/8" CASING. -PULL OUT OF HOLE FROM 1856' TO CUT JOINT. '44 JOINTS RECOVERED, PLUS 1 CUT JOINT AT 5' 8" WITH NO FLARE 21:00 - 21:30 0.50 CASING P DECOMP CLEAR RIG FLOOR OF ALL TOOLS AND EQUIPMENT NOT NEEDED FOR UPCOMING OPERATIONS. 21:30 - 22:30 1.00 FISH P DECOMP MOBILIZE BAKER TOOLS TO RIG FLOOR. -PJSM, BEAVER SLIDE OPERATIONS. - INSTALL LONG WEAR RING 12.5" ID, OD 13 -3/8 ", LENGTH 42" INCHES. 22:30 - 23:00 0.50 FISH P DECOMP INSPECT AND SERVICE RIG. -PJSM, MAN RIDER OPERATIONS, INSPECT /GREASE TOP DRIVE, BLOCKS AND DRAVWWORKS. -OUTER ANNULUS PRESSURE = 0 PSI. Printed 4/22/2013 10:26:38AM • • .?� `� xr ° r �v r: e a B �. t 9 w 1 4 '� E �: s r rk � �' �. ✓�" � s � 3 fi �^ a �-'� . ; .µ5 y x t ' � * = .r� f` � xw �. ""�rx � �" s ' 0 y 5 G : ✓' a q s$^.#s '` .' f 3,`'`.tW a ,k -^�': 3 a , a '.. "*�� � *.���. �- �.'�r°9! ��431 � f ix 1, -�,2 Common Well Name: 3-43 AFE No Event Type: WORKOVER (WO) Start Date: 3/31/2013 End Date: 4/13/2013 X4- 00X5N -E:RIG (5,417,000.00 ) Project: Endicott Site: End SDI Rig Name/No.: DOYON 14 Spud Date/Time: 4/15/1994 12:00:00AM Rig Release: 4/13/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: 48 : 43 4/15/1994 00:00 ©56.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 23:00 - 00:00 1.00 FISH P DECOMP MAKE UP BAKER DRESS OFF SHOE BHA -PJSM. 4/5/2013 00:00 - 01:00 1.00 FISH P DECOMP CONTINUE TO MAKE UP BAKER DRESS OFF BHA. -MAKE UP 4-3/4" DRILL COLLARS. 01:00 - 02:30 1.50 FISH P DECOMP RUN IN THE HOLE WITH 7 5/8" CASING DRESS OFF BHA. -RUN IN THE HOLE ON 4" DRILL PIPE FROM 225' TO 1,839'. 02:30 - 03:00 0.50 FISH P DECOMP OBTAIN OPERATIONAL PARAMETERS. - OBTAIN SLOW PUMP RATES. -PICK UP WEIGHT 85 K, SLACK OFF WEIGHT 85 K, ROTATING WEIGHT 85 K AT 70 RPM 1 FREE TORQUE -PUMP 16 BARRELS AT 1400. PSI. - TAGGED UP WITH INNER MILL AT 1856'. - WEIGHT ON MILL 4-5 K, -DRESS OFF 6" OF 7 5/8" CASING STUB. 03:00 - 05:30 2.50 FISH P DECOMP LINE UP TO PUMP -PUMP SAFE - SURF -O PILL SURFACE TO SURFACE AT 3 BARRELS A MINUTE AT 60 PSI- SEVERE FOAMING EXPERIENCED WHEN PILL CAME BACK TO SURFACE, SLOW PUMP RATE TO 2 BARRELS PER MINUTE AND UNTIL SAFE SURF OUT OF HOLE. 05:30 - 06:30 1.00 FISH P DECOMP PULL OUT OF HOLE WITH 75/8" DRESS OFF BHA. -PJSM, PULL OUT OF HOLE. -FLOW CHECK, MONITOR WELL FOR 5 MINUTES, WELL STATIC. -BLOW DOWN TOP DRIVE. -PULL OUT OF HOLE FROM 1839' TO 225'. 06:30 - 07:00 0.50 FISH P DECOMP HANDLE & LAY DOWN 7 -5/8" DRESS OFF BHA. -STAND BACK TWO STANDS OF 4-3/4" DRILL COLLARS. - INSPECT INTER MILL. - BREAK AND LAY DOWN ALL BAKER TOOLS. 07:00 - 08:00 1.00 FISH P DECOMP CLEAR RIG FLOOR. -PJSM, MOBILIZE ALL TOOLS OFF RIG FLOOR NOT NEEDED FOR UPCOMING OPERATIONS. 08:00 - 12:00 4.00 CASING P DECOMP RIG UP TO RUN 7 -5/8" CASING. - MOBILIZE LONG BALES TO RIG FLOOR. - MOBILIZE TOOLS NEEDED FOR COMPENSATOR AND SINGLE JOINT ELEVATORS. - MOBILIZE 50 CENTRALIZER'S TO RIG FLOOR. - MOBILIZE HALLIBURTON CEMENT HEAD TO RIG FLOOR. -RIG UP CASING EQUIPMENT. - SAFETY MEETING AND PERMIT STATS FOR THIS TOUR: PJSM= 15, HAZARD CARDS= 1, STOP CARDS= 0, PERMITS= 4 -OUTER ANNULUS PRESSURE= 0 PSI. Printed 4/22/2013 10:26:38AM • sue' a J " '`,' „ t aiu, �'y„ x"° xa ;..* F :p ✓', : �� r y�. -5 'x° x ,?a Y`l;.. '� 2 a t :11 1 it @ Common Well Name: 3-43 AFE No Event Type: WORKOVER (WO) Start Date: 3/31/2013 End Date: 4/13/2013 X4- 00X5N -E:RIG (5,417,000.00 ) Project: Endicott Site: End SDI Rig Name/No.: DOYON 14 Spud Date/Time: 4/15/1994 12:00:00AM Rig Release: 4/13/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: 48 : 43 4/15/1994 00:00 ©56.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:00 - 15:30 3.50 CASING P DECOMP RUN 7 -5/8" L -80 VAM TOP CASING. - CONTINUE TO RIG UP TO RUN CASING WITH DOUBLE STACK TONGS AND COMPENSATOR. -MAKE UP OVER SHOT PACKER. -RUN IN HOLE TO 1808' 'RAN TOTAL OF 44 JOINTS OF 7 5/8" L -80 VAM TOP 29.7 POUND CASING *TAG TUBING STUMP AT 1857'. 'CENTRALIZERS RAN ON JOINTS 2 THOUGH 42. 15:30 - 16:00 0.50 CASING P DECOMP WASH OVER STUB WITH OVER SHOT PACKER. -RIG DOWN COMPENSATOR. -RIG UP TO PUMP OVER STUB WITH DRILL PIPE, PUMP AT 8 BPM WITH 60 PSI. -WENT OVER STUB, PRESSURE INCREASE TO 90 PSI. -PICK UP WEIGHT= 100K, SLACK OFF WEIGHT= 103K. 16:00 - 17:00 1.00 CASING P DECOMP RIG UP CEMENT HEAD. -RIG DOWN DRILL PIPE AND CROSS OVERS. -MAKE UP 10' PUP JOINT WITH CROSS OVER, - MAKE UP VAM TOP WITH BUTTRESS THREAD ON TOP WITH CROSS OVER FOR CEMENT HEAD. 17:00 - 18:00 1.00 CASING P DECOMP ENGAGE OVERSHOT. -SET 20K DOWN ON OVERSHOT, OVER PULL 25K. -RELAX OVERSHOT, OVER PULL 50K -TO CONFIRM OVERSHOT ENGAGEMENT, RELAXED AGAIN SET, OVER PULL 100K. 18:00 - 19:30 1.50 CASING P DECOMP PREPARE FOR CEMENT JOB -RIG UP CIRCULATION LINES TO CEMENTER. 19:30 - 20:00 0.50 CASING P DECOMP PRESSURE TEST ON CASING. - PRESSURE CASING TO 1000 PSI FOR 5 CHARTED MINUTES, BLED OFF PRESSURE. - PRESSURE BACK UP TO 1000 PSI., WAIT 1 MINUTE, PRESSURE UP TO 1200 PSI., WAIT ONE MINUTE. - PRESSURE UP TO 1400 PSI., WAIT ONE MINUTE, PRESSURE UP TO 1600 PSI., WAIT ONE MINUTE. - PRESSURE UP TO 1700 PSI. WAIT ONE MINUTE, PRESSURE UP TO 1780 PSI. -ECP INFLATION VALVE OPENS AT 1780 PSI AND LEVELED OUT TO 1450 PSI. - WAIT FIVE MINUTES, PRESSURE BACK UP TO 1780 PSI. - PUMPED .04 BBL TO PRESSURE UP FROM 1450 PSI TO 1780 PSI. - PRESSURE UP TO 2000 PSI. AND HOLD FOR 10 CHARTED MINUTES. - PRESSURED UP TO 3400 PSI. SHEARED HALLIBURTON ES CEMENTER. 20:00 - 21:00 1.00 CASING P DECOMP CIRCULATE. -PJSM WITH ALL PERSONAL INVOLVED IN CEMENT JOB WHILE CIRCULATING 5 BPM WITH 100 PSI . - RETURN SEAWATER TEMPERATURE OF 80 DEGREES IS REACHED CONTINUE TO CIRCULATE DURING SLB PRESSURE TESTING. Printed 4/22/2013 10:26:38AM • S - • , � „ $g i x� . &s�,,„ a s x, ..K.�;:..Aa�xr =,2zx„ �, b ^a,.., �z..,M �✓, ..,.s �.,..� .. ..., ,...,. z_a,..r v ,. .. F ,5 �2 *� -.� �, �. ar�*^" � >.., «. s�?� ,. .� z�,�,u,. x. Common Well Name: 3-43 AFE No Event Type: WORKOVER (WO) Start Date: 3/31/2013 End Date: 4/13/2013 X4 -00X5N -E:RIG (5,417,000.00 ) Project: Endicott Site: End SDI Rig Name/No.: DOYON 14 Spud Date/Time: 4/15/1994 12:00:00AM Rig Release: 4/13/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: 48 : 43 4/15/1994 00:00 ©56.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 21:00 - 21:30 0.50 CASING P DECOMP PRESSURE TEST & PUMP CEMENT. -SLB PRESSURE TEST CEMENT LINES TO 250 PSI. LOW FOR 5 MINUTES, 4000 PSI. HIGH FOR 5 MINUTES. -SLB CEMENTERS BATCHING UP FOR CEMENT JOB. -PUMP 5 BBLS OF FRESH WATER, PUMP 116 BBL OF 15.8 PPG GAS BLOCK CEMENT. CEMENT PUMPED AT 5 BARREL PER MINUTE WITH THE FOLLOWING PRESSURES. AT 5 BARRELS AWAY 90 PSI WELL HEAD PRESSURE. AT 60 BARRELS AWAY 119 PSI WELL HEAD PRESSURE. AT 115 BARRELS AWAY 37 PSI WELL HEAD PRESSURE WITH REDUCED RATE OF 2.9 BARRELS PER MINUTE. 21:30 - 23:00 1.50 CASING P DECOMP PUMP CEMENT, BUMP PLUG. - RELEASE PLUG, CEMENTING PUMP TRUCK PUMP 5 BBLS OF FRESH WATER. - DISPLACE WITH RIG PUMPS 5 BPM WITH 80 PSI. SEAWATER 17 BBL. - CLOSED ANNULUS, OPEN OUTER ANNULUS, CONTINUE PUMP 20 BBL AT 5 BPM. - CEMENT RETURNS SEEN AT OUTER ANNULUS VALVE AT 42 BARRELS TOTAL VOLUME PUMPED AFTER PLUG RELEASE. -PUMP 5 BBL THROUGH OUTER ANNULUS VALVE. - SLOWLY SHUT OUTER ANNULUS, RETURNS SEEN THROUGH WELL HEAD FLUTES IN CELLAR. NO INDICATION OF CEMENT MIGRATING ANYWHERE ELSE DURING THE REMAINDER OF THE CEMENT JOB. - CONTINUE PUMP TAKING RETURNS THROUGH FLUTES ON WELL HEAD INTO CELLAR BOX (36.5 BBL.) CEMENT SEEN COMING THROUGH ALL FLUTES ON WELL HEAD BEFORE BUMPING PLUG. **HAD TO SLOW PUMP RATES TO STAY UNDER MAXIMUM PRESSURE OF 3000 PSI AFTER OUTER ANNULUS VALVE WAS CLOSED AND REDUCE RATE TO KEEP UP WITH RETURNS IN CELLAR DURING A SUPER SUCKER ISSUE(SUSPECT HOSE MAY HAVE BEEN TOO LONG). AVERAGE PUMP RATE 2.8 BARRELS DURING LAST 30 BARRELS PUMPED -BUMP PLUG AT 2 BPM WITH 840 PSI,ES CEMENTER CLOSING SLEEVE SHIFTED AT 1700 PSI., HELD FOR 5 MINUTES. -BLEED OFF AND MONITOR WELL THROUGH OUTER ANNULUS AND CEMENT HEAD. 23:00 - 00:00 1.00 WHSUR P DECOMP NIPPLE DOWN STACK. -PJSM, WASH THROUGH OUTER ANNULUS VALVE AND BLOW THROUGH WITH AIR. -START NIPPLING DOWN BOP STACK TO INSTALL EMERGENCY SLIPS. -OUTER ANNULUS PRESSURE= 0 PSI. Printed 4/22/2013 10:26:38AM I • K;, t t P rtT sue ,*aY . � � �. a. s s� sx �* f' ^ "� 6�.# � � � 3$ p a r 'r.�� '` '�i �. a?,* ' ' �Z.'' - ® � � e 1 .g.•hii if& 's4' s �lff x'` Asa . f * `fir , • s ff >. tt ..,e Common Well Name: 3-43 AFE No Event Type: WORKOVER (WO) Start Date: 3/31/2013 End Date: 4/13/2013 X4 -00X5N -E:RIG (5,417,000.00 ) Project: Endicott Site: End SDI Rig Name/No.: DOYON 14 Spud Date/Time: 4/15/1994 12:00:00AM Rig Release: 4/13/2013 Rig Contractor: DOYON DRILLING INC. UWWI: Active datum: 48 : 43 4/15/1994 00:00 ©56.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 4/6/2013 00:00 00:30 0.50 WHSUR P ■- DECOMP CONTINUE NIPPLE BOP STACK STACK A CA -SPLIT BOP STACK AT CASING/TUBING SPOOL. 00:30 - 04:30 4.00 WHSUR P DECOMP SET EMERGENCY SLIPS. -PJSM, INSTALL EMERGENCY SLIPS AND CUT EXCESS 7 -5/8" CASING, LAY DOWN EXCESS CASING. -INSTALL PACK OFF AND NIPPLE UP BOP. -RUN IN LOCK DOWN SCREWS TO ENERGIZE PRIMARY SEAL AND SECURE SLIPS. 04:30 - 10:00 5.50 WHSUR N SFAL DECOMP TEST PACK OFF FOR 7 5/8" CASING. -NOT ABLE TO GET GOOD TEST ON FIRST ATTEMPT. -PULL PACK OFF THROUGH BOPS AND INSPECT FOR SEAL DAMAGE. -SPLIT STACK, CLEANED OFF STUMP AND 7 -5/8" CASING SPOOL. NOTICED SCRAPE MARKS IN THE 7 -5/8" CASING SPOOL. BUFFED OUT THE MARKS AND GRINDED A 1/4" OFF THE7 -5/8" CASING STUB. - INSTALL PACK OFF AND NIPPLE BACK UP THE BOP. 10:00 - 11:00 1.00 WHSUR P DECOMP TEST PACK OFF. -TESTED PACK OFF TO 3500 PSI. FOR 30 CHARTED MINUTES. -RIG EVACUATION DRILL H2S) 11:00 - 12:00 1.00 WHSUR P DECOMP NIPPLE UP BOP CONTINUE. - RESUME BOP NIPPLE UP OPERATION. -OUTER ANNULUS PRESSURE= 0 PSI. 12:00 - 14:00 2.00 WHSUR P ■- DECOMP CHANGE OUT RAMS. - CHANGE OUT 7 -5/8" SOLID RAMS TO 3.5" X 6" VARIABLE RAMS. 14:00 - 16:00 2.00 WHSUR P DECOMP TEST RAMS. - RIG UP AND TEST TOP RAMS WITH 4" AND 4.5" TEST JOINT. TEST 250 PSI. LOW / 4000 PSI HIGH FOR 5 CHARTED MINUTES EACH. TEST GOOD. 16:00 - 16:30 0.50 WHSUR P DECOMP INSTALL WEAR BUSHING. -VOID STACK OF FLUIDS. -PULL TEST JOINT AND INSTALL SHORT WEAR BUSHING. (ID= 8 -3/4 ", OD= 13-1W, L= 12 -1/2 ") 16:30 - 17:30 1.00 FISH P ■- DECOMP PICK UP TOOLS. - MOBILIZE BAKER TOOLS TO RIG FLOOR FOR NEXT OPERATION. 17:30 - 21:00 3.50 FISH P DECOMP WAIT ON CEMENT TO OBTAIN COMPRESSIVE STRENGTH. - CONDUCT TABLE TOP DRILLS, H2S RIG EVACUATION, MAN DOWN. DISCUSS ROLES AND RESPONSIBILITIES. -LOAD AND STRAP DRILL COLLARS. 21:00 - 21:30 0.50 CASING P DECOMP MAKE UP DRILL ASSEMBLY BHA #4. -PJSM, MAKE UP BHA WITH BAKER REP'S. -MAKE UP 6-3/4 BIT WITH BOOT BASKETS, OIL JARS,BUMPER SUB AND DRILL COLLARS. 21:30 - 22:30 1.00 CASING P ■- DECOMP -CONTINUE WITH PIOE RUN IN OF HOLE FROM 204' TO Printed 4/22/2013 10:26:38AM • ' .,+ ' �✓.,°"., t 4 Common Well Name: 3-43 AFE No Event Type: WORKOVER (WO) Start Date: 3/31/2013 End Date: 4/13/2013 X4 -00X5N -E:RIG (5,417,000.00 ) Project: Endicott Site: End SDI Rig Name/No.: DOYON 14 Spud DateTme: 4/15/1994 12:00:00AM Rig Release: 4/13/2013 Rig Contractor. DOYON DRILLING INC. UWI: Active datum: 48 : 43 4/15/1994 00:00 @56.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 22:30 - 00:00 1.50 CASING P DECOMP SLIP AND CUT WHILE WAITING ON CEMENT. -PJSM, SLIP AND CUT DRILL LINE. - INSTALL FULL OPEN SAFETY VALVE 1 JOINT BELOW ROTARY TABLE. -HANG OFF BLOCKS AND CUT 59.5 FOOT OF DRILL LINE. -OUTER ANNULUS PRESSURE= 0 PSI. 4/7/2013 00:00 - 03:00 3.00 CASING P DECOMP CIRCULATE WHILE WAITING ON COMPRESSIVE STRENGTH OF CEMENT. • - CIRCULATE AT 5 BARRELS PER MINUTE WITH 200 PSI. 'SIM -OPS: CONDUCT STAND DOWN FOR DROPPED OBJECTS - REVIEWED RECENT DROPPED OBJECT INCIDENTS WITH CREWS, DISCUSSED THE IMPORTANCE OF FOLLOWING POLICIES AND PROCEDURE TO AVOID FUTURE OCCURRENCE, THEY ARE WRITTEN IN "BLOOD ". REVIEWED ACTION LIST FOR OTHER STAND DOWNS AND TASKED CREW WITH LOOKING SPECIFICALLY AT THE CUT AND SLIP JOB FOR DROPPED OBJECT POTENTIAL. 03:00 - 07:30 4.50 CLEAN P DECOMP MILL OUT SHOE TRACT -PJSM - CONTINUE TO RUN IN HOLE TO 1537' AND GET PARAMETERS. *PICK UP WEIGHT= 82K SLACK OFF WEIGHT= 80K ROTATE WEIGHT= 85K RPM= 120 TORQUE ON= 1000 FT /LBS TORQUE OFF= 0 WEIGHT ON BIT= 3K GPM= 325 -TAG CEMENT STRINGER AT 1762' AND WASHED /REAMED THROUGH STRINGERS TO 1812' -TAG PLUG AT 1812 07:30 - 08:30 1.00 CLEAN P DECOMP DRILL OUT SHOE TRACK -DRILL THROUGH SHOE - WORKED THROUGH SHOE TRACK WITHOUT PUMPS A FEW TIMES - WASHED DOWN TO 1901' AND PUMPED HI -VIS SWEEP. 08:30 - 09:30 1.00 CLEAN P DECOMP TAG SAND AND DRILL SAND -TURN OFF PUMPS AND TAG SAND -BLOW DOWN TOP DRIVE -DRY DRILL ON TOP OF SAND. - ESTABLISH PARAMETERS: RPM= 100, TORQUE= 1-2K PICK UP WEIGHT= 82K SLACK OFF WEIGHT= 80K ROTATE WEIGHT= 85K WEIGHT ON BIT= 5K 09:30 - 10:00 0.50 CLEAN P DECOMP PULL OUT OF HOLE. - PJSM,FLOW CHECK WELL FOR 10 MINUTES, WELL STATIC. -PULL OUT OF HOLE FROM 1923' TO 224'. Printed 4/22/2013 10:26:38AM I Common Well Name: 3-43 AFE No Event Type: WORKOVER (WO) Start Date: 3/31/2013 End Date: 4/13/2013 X4 -00X5N -E:RIG (5,417,000.00 ) Project: Endicott Site: End SDI Rig Name/No.: DOYON 14 Spud Date/me: 4/15/1994 12:00:00AM Rig Release: 4/13/2013 Rig Contractor. DOYON DRILLING INC. UWI: Active datum: 48 : 43 4/15/1994 00:00 ©56.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 10:00 - 11:00 1.00 CLEAN P DECOMP LAY DOWN DRILL OUT BHA # 4. -PJSM, FLOW CHECK WELL FOR NON - SHEARABLES ACROSS STACK, WELL STATIC. -STAND BACK DRILL COLLARS. -BREAK AND LAY DOWN DRILL OUT BHA RETRIEVED 1/2 GALLON OF CEMENT AND HALF A CUP OF BRASS & ALUMINUM FROM BOOT BASKETS. 11:00 - 12:00 1.00 CLEAN P DECOMP MAKEUP REVERSE JUNK BASKET BHA# 5. -PJSM, MAKE UP REVERSE JUNK BASKET BHA AND RUN IN HOLE TO 235'. -OUTER ANNULUS PRESSURE= 0 PSI. 12:00 - 13:30 1.50 CLEAN P DECOMP RUN IN HOLE CONTINUE. -PJSM, RUN IN HOLE FROM 235' TO 1750'. - ESTABLISH PARAMETERS AND SLOW PUMP RATES: PICK UP WEIGHT= 82K SLACK OFF WEIGHT= 83K. ROTATE WEIGHT= 83K -PUMP 8 BARREL PRE MINUTE © 680 PSI. -DROP BALL, OPEN PUMP OUT SUB WITH 1000 PSI. 13:30 - 14:30 1.00 CLEAN P DECOMP MILL CEMENT. - TAGGED CEMENT AT 1915' WEIGHT ON MILL= 5K, PUMP 8 BARREL PER MINUTE WITH 1000 PSI. -MILL FROM 1915' TO 1920'. *NOTIFICATION SENT AOGCC FOR BOP EQUIPMENT TEST ON 4/8/2013 BY MIKE ALEXANDER AT 13:51 4/7/2013` 14:30 - 15:00 0.50 CLEAN P DECOMP CIRCULATE. -PUMP HIGH VIS SWEEP AT 8 BARREL PRE MINUTE WITH 1010 PSI. 15:00 - 16:00 1.00 CLEAN P DECOMP PULL OUT OF HOLE. -PULL OUT OF HOLE FROM 1920' TO 300' 16:00 - 16:30 0.50 CLEAN P DECOMP HANDLE REVERSE JUNK BASKET BHA# 5. -FLOW CHECK WELL FOR 10 MINUTES FOR NON - SHEARABLES ACROSS THE STACK WELL STATIC. -STAND BACK DRILL COLLARS. -PULL JARS & BUMPER SUB TO RIG FLOOR. REVERSE CIRCULATION JUNK BASKET PLUGGED WITH CEMENT AND RUBBER. MILL FACE BURNED SMOOTH. 16:30 - 18:30 2.00 CLEAN P DECOMP MAKE UP REVERSE JUNK BASKET BHA# 6. -PJSM, CHANGE OUT JUNK BASKET MILL AND MAKE UP WITH BHA TO 235'. 18:30 - 19:00 0.50 CLEAN P DECOMP RUN IN HOLE. -RIH FROM 235' TO 1754' WASH DOWN TO 1920' AND TAGGED UP. Printed 4/22/2013 10:26:38AM • S ye fin,; w , 3 x ,r = ! °„ -S�a- s :°� ` � p ' ?. ' `', '� x` :�, ' 1 "� lt ll � ® lb��� �" ` �� ,<.:::.. ..,a . >: ., �.. .,.... z• _, ....:.u� x ........,,,,x.:�- :�.�.., ....:.,�.. 1 ., ,3.,,� ,_..., „' . ,., �,.�..: ,,. -. �. s ,.� .3. . :,`�i. >�._r. �.:.. -„��r ;, »�°';: ���:n'�t.,?�' ��i�.,:?S;:a� Common Well Name: 3-43 AFE No Event Type: WORKOVER (WO) Start Date: 3/31/2013 End Date: 4/13/2013 X4 -00X5N -E:RIG (5,417,000.00 ) Project: Endicott Site: End SDI Rig Name/No.: DOYON 14 Spud Date /me: 4/15/1994 12:00:00AM Rig Release: 4/13/2013 Rig Contractor. DOYON DRILLING INC. UWI: Active datum: 48 : 43 4/15/1994 00:00 ©56.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 19:00 - 20:00 1.00 CLEAN P DECOMP RUN IN HOLE CONTINUE. - ESTABLISH PARAMETERS: PUMP 8 BARREL PER MINUTE WITH 1010 PSI. WEIGHT ON MILL= 2 -3K. ROTATION PER MINUTE= 60 RPM. TORQUE= 2 -5K. PICK UP WEIGHT= 82K. SLACK OFF WEIGHT= 83K. ROTATE WEIGHT= 83K. -PUMP HIGH VIS SWEEP, VERY LITTLE SAND CAME BACK. - WASHED DOWN TO 1937'. 20:00 - 20:30 0.50 CLEAN P DECOMP FLOW CHECK. -FLOW CHECK WELL FOR 10 MINUTES, WELL STATIC. -BLOW DOWN TOP DRIVE. 20:30 - 21:00 0.50 CLEAN P DECOMP PULL OUT OF HOLE. -PJSM, PULL OUT OF HOLE FROM 1937' TO 300' FLOW CHECK WELL FOR NON - SHEARABLES ACROSS STACK WELL STATIC. **WITNESS OF BOP EQUIPMENT TEST WAIVED BYAOGCC REP. MIKE JONES ON 4/7/2013 AT 20:16 PM."` 21:00 - 21:30 0.50 CLEAN P DECOMP HANDLE BHA# 6. - FLOW CHECK WELL FOR NON - SHEARABLES ACROSS STACK WELL STATIC. -STAND BACK DRILL COLLARS AND BREAK REVERSE JUNK BASKET NOSE. RECOVERED LARGE CEMENT CHUNKS GREATER THAN 1" DIAMETER, LARGE PIECES OF ALUMINUM, AND PLUG RUBBER. APPROXIMATELY 1/2 GALLON OF MATERIAL. 21:30 - 22:00 0.50 CLEAN P DECOMP HANDLE BHA #7 CONTINUE. -MAKE BACK UP REVERSE JUNK BASKET NOSE CONE WITH JARS, BUMPER SUB AND DRILL COLLARS. RUN IN HOLE TO 235'. 22:00 - 22:30 0.50 CLEAN P DECOMP RUN IN HOLE. -RUN IN HOLE FROM 235' TO 1754'. - ESTABLISH PARAMETERS: PUMP 8 BARRELS PER MINUTE WITH 1010 PSI. PICK UP WEIGHT= 87K. SLACK OFF WEIGHT= 83K. ROTATE WEIGHT= 85K. -TAG SAND AT 1937' 22:30 - 23:00 0.50 CLEAN P DECOMP RUN IN HOLE CONTINUE. -WASH DOWN FROM 1937' TO 1953' 23:00 - 23:30 0.50 CLEAN P DECOMP CIRCULATE. -PUMP HIGH VIS SWEEP, CIRCULATE AROUND AT 8 BARREL PER MINUTE WITH 1010 PSI. -10 MINUTE FLOW CHECK WELL STATIC. 23:30 - 00:00 0.50 CLEAN P DECOMP PULL OUT OF HOLE. -PULL OUT OF HOLE FROM 1953' TO 900'. -OUT ANNULUS PRESSURE= 0 PSI. Printed 4/22/2013 10:26:38AM • • y l 43' e t ,. �.,y., : n '�" �, � t�; t^Fh„� � a .; ✓ z , r ( r .. ��.�e, .uE'�,�,a , 1,a �=� . ..�?., x ' �... , � '',..4 �. Common Well Name: 3-43 AFE No Event Type: WORKOVER (WO) Start Date: 3/31/2013 End Date: 4/13/2013 X4- 00X5N -E:RIG (5,417,000.00 ) Project: Endicott Site: End SDI Rig Name/No.: DOYON 14 Spud Date/Time: 4/15/1994 12:00:00AM Rig Release: 4/13/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: 48 : 43 4/15/1994 00:00 ©56.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 4/8/2013 00:00 - 00:30 0.50 CLEAN P DECOMP PULL OUT OF HOLE. - CONTINUE TO PULL OUT OF HOLE FROM 900' TO 235'. 00:30 - 02:00 1.50 CLEAN P DECOMP LAY DOWN MILL OUT BHA # 7. -PJSM, FLOW CHECK FOR 10 MINUTES, WELL STATIC. -STAND BACK DRILL COLLARS, LAY DOWN BHA. - JUNK BASKET CAME BACK WITH NO DEBRIS. 02:00 - 04:00 2.00 CASING P DECOMP PRESSURE TEST CASING. -PJSM, RIG UP TO TEST CASING. - PRESSURE TEST CASING TO 4000 PSI FOR 45 CHARTED MINUTES. PASSED BP WELLBORE TESTING CRITERIA. OBTAINED APPROVAL OF TEST FROM JIM WILLINGHAM BP WORKOVER TEAM LEAD. 04:00 - 05:00 1.00 FISH P DECOMP RUN IN HOLE WITH RETRIEVABLE BRIDGE PLUG RETRIEVING TOOL -PJSM, MAKE UP RETRIEVING BHA FOR BRIDGE PLUG -RUN IN HOLE TO 1950' 05:00 - 06:00 1.00 FISH P DECOMP WASH SAND TO TOP OF RETRIEVABLE BRIDGE PLUG -WASH DOWN TO 1970' AND PUMP SWEEP 06:00 - 07:00 1.00 FISH P DECOMP REVERSE CIRCULATE. -RIG UP AND REVERSE CIRCULATE AT 3 BARRELS PER MINUTE WITH 60 PSI. 07:00 - 08:00 1.00 FISH P DECOMP LATCH ON RETRIEVABLE BRIDGE PLUG. -LATCH ON TO RPB WITH RETRIEVAL TOOL, RELEASED RBP FROM CASING AS PER HALLIBURTON REP. INSTRUCTIONS. -CLOSE ANNULAR PREVENTER. - CIRCULATE BOTTOMS UP THROUGH CHOKE, PUMP 4 BARRELS PER MINUTE WITH 90 PSI. NO GAS DETECTED. -FLOW CHECK FOR 10 MINUTES, WELL STATIC, OPEN ANNULAR PREVENTER. -BLOW DOWN CHOKE AND KILL LINES. - STRIPPING DRILL (D6) 08:00 - 10:00 2.00 FISH P DECOMP PULL OUT OF HOLE. -PJSM, PULL OUT OF HOLE WITH RETRIEVABLE BRIDGE PLUG. - DISENGAGE RBP FROM RETRIEVAL TOOL AND MOBILIZE OFF RIG FLOOR. 10:00 - 12:00 2.00 BOPSUR P DECOMP RIG UP TO TEST BOP EQUIPMENT. -VOID STACK OF ALL FLUIDS AND PULL WEAR BUSHING. -FLUSH STACK WITH STACK WASHING JOINT. -RIG UP TO TEST BOP EQUIPMENT AND CHOKE MANIFOLD AS PER DOYON PROCEDURE -KICK DRILL (D2) -OUTER ANNULUS PRESSURE= 0 PSI. 12:00 - 13:30 1.50 BOPSUR P DECOMP RIG UP TO TEST BOP EQUIPMENT CONTINUE. - CONTINUE WITH RIGGING UP TO TEST BOP EQUIPMENT. Printed 4/22/2013 10:26:38AM • • ATM , : ?�'��` ,fit ! �. ,. o , -; '' '. vs ^,.i aagg " r ,rzr j m " ® °� � � ° " - �c t" a ' - a s. r. cr, ,�k m..43; =..�?ar;.. xv�,',:� ...'a,.su'L.stk.�cF�r4ht;� „�: .,€., ,...,v"� :r ...4a,..�'; :'i.....e:.w�c, a .0 �a'r :.:-'�.`a`i`n_, . ...z.'�'�:,�ts ✓. .�.'�#�`a �`,lr '?.�.__.�"'�'..,.: - �,. Common Well Name: 3-43 AFE No Event Type: WORKOVER (WO) Start Date: 3/31/2013 End Date: 4/13/2013 X4 -00X5N -E:RIG (5,417,000.00 ) Project: Endicott Site: End SDI Rig Name/No.: DOYON 14 Spud DateTme: 4/15/1994 12:00:00AM Rig Release: 4/13/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: 48:43 4/15/1994 00:00 @56.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 13:30 - 20:00 6.50 BOPSUR P DECOMP TEST BOP EQUIPMENT. -VOID STACK OF ALL FLUIDS AND PULL WEAR BUSHING. -FLUSH STACK WITH STACK WASHING JOINT. -TEST BOP EQUIPMENT AND CHOKE MANIFOLD AS PER DOYON PROCEDURE IN ACCORDANCE WITH AOGCC RULES AND REGULATIONS. -TEST ANNULAR PREVENTER WITH 3.5 TEST JOINT. TEST CONDUCTED TO 250 PSI LOW! 3500 PSI. HIGH FOR 5 CHARTED MINUTES EACH. -TEST WITH 31 /2” & 4.5" TEST JOINTS, 2- 4" XT39 FULL OPEN SAFETY VALVES, 1- 4" XT39 DART VALVE, 1- 4.5 FOSV. TEST CONDUCTED TO 250 PSI L 4000 PSI. HIGH FOR 5 CHARTED MINUTES EACH. *BOPS FUNCTIONED FROM BOTH REMOTE PANEL AND ACCUMULATOR CONTROLS. 20:00 - 21:00 1.00 BOPSUR P DECOMP RIG DOWN BOP TEST EQUIPMENT. -PJSM, VOID STACK OF ALL FLUIDS. -BLOW DOWN CHOKE, KILL LINES, AND CHOKE MANIFOLD. -PULL TEST PLUG, INSTALL WEAR BUSHING (ID= 8 -3/4 ", OD= 13 -1/4 ", L= 12 -1/2") -BREAK AND LAY DOWN FULL OPEN SAFETY VALVE & CROSS OVER USED TO TEST SAFETY VALVES. -MAKE UP SAFETY JOINT FOR BHA. 21:00 - 22:00 1.00 FISH P DECOMP PICK UP BHA# 8 TO PULL SEAL ASSEMBLY. -PJSM, PICK UP BAKER TOOLS FOR BHA # 8 22:00 - 22:30 0.50 FISH P DECOMP MAKE UP BHA# 8 TO PULL SEAL ASSEMBLY. -MAKE UP OVERSHOT WITH GRAPPLE, JARS, AND BUMPER SUB. -PICK UP ONE MORE STAND OF 4-3!4" DRILL COLLARS. -RUN IN HOLE TO 302'. 22:30 - 23:30 1.00 FISH P DECOMP RUN IN HOLE. -PJSM, RUN IN HOLE FROM 302' TO 4101' WITH PIPE OUT OF DERRICK 23:30 - 00:00 0.50 FISH P DECOMP RUN IN HOLE. -PJSM, RUN IN HOLE PICKING UP SINGLES FROM PIPE SHED FROM 4101' TO 4800'. -OUTER ANNULUS PRESSURE= 0 PSI. 4/9/2013 00:00 - 00:30 0.50 FISH P DECOMP RIG SERVICE. - LUBRICATE RIG AND TOP DRIVE. 00:30 - 04:00 3.50 FISH P DECOMP RUN IN HOLE W/ OVERSHOT, CONT. -RUN IN HOLE FROM 4800 TO 9708 FT. 'OVERSHOT DRESSED W/ 3-1!2" BASKET GRAPPLE. Printed 4/22/2013 10:26:38AM • Common Well Name: 3-43 AFE No Event Type: WORKOVER (WO) Start Date: 3/31/2013 End Date: 4/13/2013 X4- 00X5N -E:RIG (5,417,000.00 ) Project: Endicott Site: End SDI Rig Name/No.: DOYON 14 Spud Date /me: 4/15/1994 12:00:00AM Rig Release: 4/13/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: 48 : 43 4/15/1994 00:00 ©56.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 04:00 - 06:30 2.50 FISH P DECOMP MILL AND ENGAGE 3-1/2" TUBING STUB. -TAG STUB AT 9708 FT. - ESTABLISH PARAMETERS AND SLOW PUMP RATES. -PICK UP WEIGHT = 220K. -SLACK OFF WEIGHT= 190K. - ROTATING WEIGHT= 205K. -40 RPM W/ TORQUE AT 5K ON AND 4K OFF. -5.0 BARREL PER MINUTE AT 430 PSI. -MILL ON TUBING STUB W/ 5K WOB AND NO DECREASE IN BIT WEIGHT. -WORK OVER TOP OF STUB W/O ROTATION. , INITIATE ROTATION UNTIL WEIGHT DECREASED. - ROTATE OVER STUB TO 9710 FT GIVING A 5 FT SWALLOW. - ENGAGE TUBING STUB WITH 25K DOWN WEIGHT W/O SUCCESS. REPEAT UNTIL FISH ENGAGED. OVER PULL W/ 60K AND FISH CAME FREE. `OBSERVE FLUID LEVEL DROP IN WELL BORE. 06:30 - 08:30 2.00 FISH P DECOMP CIRCULATE BOTTOMS UP THROUGH GAS BUSTER. -FILL HOLE AND CLOSE ANNULAR PREVENTER. - CIRCULATE AT 5.5 BARRELS PER MINUTE WITH 520 PSI. - INITIAL FLUID LOSS RATE OF 80 BARRELS PER HOUR DECREASING TO 30 BARRELS PER HOUR. 'KICK DRILL: RESPONSE TIME =3:15 MINUTES. 08:30 - 09:00 0.50 FISH P DECOMP CIRCULATE WELL. - CIRCULATE 100 BARRELS AT 5 BARRELS PER MINUTE WITH 420 PSI. -BLOW DOWN TOP DRIVE AND CHOKE. 09:00 - 09:30 0.50 FISH P DECOMP OBTAIN STATIC LOSS RATE. - STATIC FLUID LOSS RATE AT 12 BARRELS PER HOUR. 09:30 - 12:00 2.50 FISH P DECOMP PULL OUT OF HOLE W/ OVERSHOT AND SEAL ASSEMBLY. -PULL OUT OF HOLE FROM 9708 FT TO 3022 FT. 'OUTER ANNULUS PRESSURE= 0 PSI. 'FLUID LOST TO WELL FROM MIDNIGHT TO NOON= 105 BARRELS. 12:00 - 13:30 1.50 FISH P DECOMP PULL OUT OF HOLE, CONT. -PULL OUT OF HOLE FROM 3022' TO 300' 13:30 - 14:00 0.50 FISH P DECOMP HANDLE SEAL ASSEMBLY RETRIEVAL BHA# 8. -10 MINUTE FLOW CHECK WELL AT BHA - FLUID LEVEL FALLING. - HANDLE BHA. 14:00 - 14:30 0.50 FISH P DECOMP LAY DOWN OVERSHOT. -LAY DOWN TOOLS AND RECOVERY: PACKER SEAL ASSEMBLY. 14:30 - 15:00 0.50 FISH P DECOMP MOBILIZE PACKER MILLING ASSEMBLY TO RIG FLOOR. Printed 4/22/2013 10:26:38AM • } • Common Well Name: 3-43 AFE No Event Type: WORKOVER (WO) Start Date: 3/31/2013 End Date: 4/13/2013 X4 -00X5N -E:RIG (5,417,000.00 ) Project: Endicott Site: End SDI Rig Name/No.: DOYON 14 Spud DateTme: 4/15/1994 12:00:00AM Rig Release: 4/13/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: 48 : 43 4/15/1994 00:00 ©56.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 15:00 - 16:30 1.50 FISH P DECOMP PJSM ON PICKING UP PACKER MILL ASSEMBLY BHA #9. -MAKE UP MILLING ASSEMBLY. - 6-3/4" X 1 -3/8" PACKER MILL. -PICK UP (9) 4-3/4" DRILL COLLARS. 16:30 - 19:30 3.00 FISH P DECOMP TRIP IN HOLE VNTH PACKER MILL. -RUN STANDS FROM 308 TO 9350 FT. 19:30 - 23:00 3.50 FISH P DECOMP PJSM ON SLIP AND CUT DRILLNG LINE OPERATION. -HANG BLOCKS. - INSTALL FULL OPEN SAFETY VALVE AND RUN 1 JOINT. -LONG SLIP AND CUT 1708 FT DRILL LINE FROM NEW SPOOL. - UNHANG BLOCKS AND PULL FULL OPEN SAFETY VALVE. 23:00 - 23:30 0.50 FISH P DECOMP RUN IN HOLE W/ PACKER MILL, CONT. -FROM 9350' TO 9709'. PICK UP (2) SINGLES. -TAG PACKER AT AT 9750 FT. 23:30 - 00:00 0.50 FISH P DECOMP MILL PACKER FB1 PACKER. - ESTABLISH MILLING PARAMETERS AND SLOW PUMP RATES. -8 BARRELS PER MINUTE WITH 1180 PSI. -PICK UP WEIGHT= 223K. -SLACK OFF WEIGHT = 185K. - ROTATE WEIGHT= 203K. -MILL PACKER W/ - WEIGHT ON BIT= 2 -3K. -100 RPM AT 5-8K TORQUE. *OUTER ANNULUS PRESSURE= 0 PSI. *FLUID LOSS FROM NOON TO MIDNIGHT = 74 BARRELS. *TOTAL FLUID LOSSES FOR THE PAST 24 HOURS= 179 BARRELS = 7.5 BARRELS PER HOUR. 4/10/2013 00:00 - 01:30 1.50 FISH P DECOMP MILL PACKER FB1 PACKER, CONT. -MILL PACKER FROM 9751 TO 9753' CONT. - 8.0 BARRELS PER MINUTE WITH 1200 PSI. - WEIGHT ON BIT= 11K. - 80 RPM W/ 6-7K TORQUE. TORQUE = 6-7K *MILL TO 9753 (3.7 FT) AND PACKER FELL. SLACK OFF 5 FT TO CONFIRM. 01:30 - 02:00 0.50 FISH P DECOMP BULLHEAD PACKER GAS. - SHUT IN ANNULAR PREVENT ER AND BULL HEAD WITH 36 BARRELS. -PUMP 6 BARRELS TO GET TO FULL RATE OF 7 BARRELS PER MINUTE. -PUMP 30 BARRELS AT 7 BARRELS PER MINUTE WITH 1480 PSI. 02:00 - 03:30 1.50 FISH P DECOMP CIRCULATE BOTTOMS UP THROUGH GAS BUSTER. -LINE UP THROUGH OPEN CHOKE. - CIRCULATE BOTTOMS UP THROUGH CHOKE AT 5 BARRELS PER MINUTE WITH 580 PSI. - MONITOR CASING PRESSURE AND DRILL PIPE PRESSURE AT 0 PSI. -10 MINUTE FLOW CHECK WELL FOR 10 MINUTES WELL ON VACUUM Printed 4/22/2013 10:26:38AM • • � � f a t SY `53a7 t f p —g zit fz R d"L Common Well Name: 3-43 AFE No Event Type: WORKOVER (WO) Start Date: 3/31/2013 End Date: 4/13/2013 X4 -00X5N -E:RIG (5,417,000.00 ) Project: Endicott Site: End SDI Rig Name/No.: DOYON 14 Spud DateTme: 4/15/1994 12:00:00AM Rig Release: 4/13/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: 48 : 43 4/15/1994 00:00 @56.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 03:30 - 07:30 4.00 FISH P DECOMP PULL OUT OF HOLE WITH PACKER MILL. -BRING TOP DRIVE DOWN TO CONNECTION HEIGHT, PUTTING MILL AT 9765' WITH NO SIGN OF FB-1 PACKER -BLOW DOWN CHOKE, KILL LINE AND TOP DRIVE. -PULL OUT OF HOLE FROM 9765' TO 308'. *CURRENT LOSS RATE AT 6.7 BARRELS PER HOUR. 07:30 - 08:00 0.50 FISH P DECOMP LAY DOWN PACKER MILL BHA # 9. -FLOW CHECK WELL AT NON - SHEARABLES ACROSS STACK, WELL ON VACUUM. -STAND BACK DRILL COLLARS. -LAY DOWN PACKER MILL BHA. 08:00 - 08:30 0.50 FISH P DECOMP MAKEUP PACKER SPEAR BHA# 10. -MAKE UP ITCO TYPE C SPEAR (3.947 GRAPPLE BHAAND RUN IN HOLE WITH DRILL COLLARS. 08:30 - 12:00 3.50 FISH P DECOMP RUN IN HOLE.WITH SPEAR -RUN IN HOLE FROM 209' TO 9131'. `OUTER ANNULUS PRESSURE= 0 PSI. *FLUID LOST TO WELL FROM MIDNIGHT TO NOON= 118 BARRELS. 12:00 - 12:30 0.50 FISH P DECOMP -RIG SERVICE. - SERVICE BLOCKS, TOP DRIVE, AND DRAW WORKS. 12:30 - 13:00 0.50 FISH P DECOMP RUN IN HOLE WITH PACKER FISHING BHA CONT. -RUN IN HOLE FROM 9131' TO 9700'. - ESTABLISH PARAMETERS & SLOW PUMP RATES. PICK UP WEIGHT= 223K. SLACK OFF WEIGHT = 189K. 13:00 - 14:00 1.00 FISH P DECOMP ENGAGE PACKER. -PICK UP SINGLES FROM PIPE SHED FROM 9700' TO 10152' - TAGGED UP AT 10152', SET 25K DOWN, OVER PULLED, SET ANOTHER 10 K DOWN, OVER PULLED 20K. -FISH ENGAGED. 14:00 - 19:30 5.50 FISH P DECOMP PULL OUT OF HOLE WITH PACKER. -10 MINUTE FLOW CHECK, WELL STILL ON A VACUUM. -PULL OUT OF HOLE FROM 10152' - MONITOR WELL WHILE PULLING EACH STAND FOR 5 STANDS, NO SWABBING OBSERVED, FILL HOLE AFTER EACH STAND WITH PROPER HOLE FILL(.5 BARREL PER STAND). - LINE UP ON TRIP TANKAND CONTINUE OUT OF THE HOLE FILLING ACROSS THE TOP TO 400' 19:30 - 20:00 0.50 FISH P DECOMP HANDLE PACKER RETRIEVAL BHA #10 -FLOW CHECK FOR 10 MINUTES AT NON - SHEARABLES ACROSS THE STACK, FLUID LEVEL FALLING.. -PULL OUT OF HOLE, STAND BACK DRILL COLLARS. Printed 4/22/2013 10:26:38AM • • • , ''`' €�` d P�" a£'` ti+`Y' - a.'p .rr,�,� Errs+ r ;z u, WS- s w 4 ' -++fi� r - . - r# �... 7 .��.. � � ;' v`- r : s t a "- �r- ,.i.A 1 � c' e� � �A��f,K">s � �` sr N �. .,-� ,,:aa� c t x ''�`.,�8,r,p �, �5 ' .[l.[[ f :..a ®®. P c4 `.° , � 'a . � , � .a , ' Sz y `j` '` '?,-,`,'; Common Well Name: 3-43 AFE No Event Type: WORKOVER (WO) Start Date: 3/31/2013 End Date: 4/13/2013 X4 -0OX5N -E:RIG (5,417,000.00 ) Project: Endicott Site: End SDI Rig Name/No.: DOYON 14 Spud Date/Time: 4/15/1994 12:00:00AM Rig Release: 4/13/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: 48 : 43 4/15/1994 00:00 @56.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 20:00 - 22:00 2.00 FISH P DECOMP LAY DOWN SPEAR, PACKER AND TAILPIPE -PJSM, MAKE UP IRON RUFFNECK WITH TUBING PUNCH. -PUNCH TUBING ABOVE BOTH X NIPPLES IN TAILPIPE. -LAY DOWN TUBING TAIL, REMOVE SPEAR FROM PACKER AND LAY DOWN PACKER. 22:00 - 22:30 0.50 CLEAN P DECOMP PICK UP CLEAN OUT BHA. -PJSM, MAKE UP 6-3/4" JUNK MILL WITH BOOT BASKETS, 7 -5/8" SCRAPER, GRABBIT MAGNETS, OIL JARS AND BUMPER SUB. -PICK UP (9) 4.75" DRILL COLLARS 22:30 - 00:00 1.50 CLEAN P DECOMP TRIP IN HOLE WITH CLEAN OUT BHA. -RUN STANDS FROM 343' TO 5000'. 'OUTER ANNULUS PRESSURE= 0 PSI. *FLUID LOSSES FROMNOON TO MIDNIGHT= 42 BARRELS. *TOTAL FLUID LOSSES FOR THE PAST 24 HOURS= 160 BARRELS = 6.6 BARRELS PER HOUR. 4/11/2013 00:00 - 00:30 0.50 CLEAN P DECOMP SERVICE RIG. - LUBRICATE AND SERVICE RIG AND TOP DRIVE. 00:30 - 03:30 3.00 CLEAN P DECOMP RUN IN HOLE WITH CLEAN OUT BHA. -RIH FROM 2000' TO 9714' CASING SCRAPER DEPTH. - RECIPROCATE FROM 9670' TO 9745' (4) TIMES WITH NO OVER PULL OR DRAG. (TMT PACKER TO BE SET AT 9714) -RIH CONTINUE TO 10184'. 03:30 - 05:00 1.50 CLEAN P DECOMP CLEAN OUT TO 10190'. -TAG FILL AT 10184'. -PICK UP WITH NO OVER PULL TO 10175' . -GET MILLING PARAMETERS. SLOW PUMP RATE FOR BOTH PUMPS AT 20 STROKES PER MINUTE = 100 PSI. SLOW PUMP RATE FOR BOTH PUMPS AT 30 STROKES PER MINUTE = 200 PSI. PICK UP WEIGHT =230 K. SLACK OFF WEIGHT =195 K RPM =30. TORQUE =4 K 5 BARRELS PER MINUTE AT 2380 PSI. -CLEAN FILL FROM 10184' TO 10190' AT BOTTOMS UP STROKES NOTICED RIVER SAND, PACKER RUBBER AND SMALL AMOUNT OF CEMENT FINES AT SHAKER. -PUMP SWEEP RETURNS CLEANED UP WHILE SWEEP WAS STILL IN HOLE. 05:00 - 06:00 1.00 CLEAN P DECOMP DISPLACE WELL BORE FLUIDS. - DISPLACE WELL TO CLEAN 8.5 POUND PER GALLON SEAWATER AT 6 BARRELS PER MINUTE AT 2500 PSI. - PARAMETERS: GALLONS PER MINUTE= 450 WITH 2230 PSI. ROTATE= 30 RPM. TORQUE= 4K. Printed 4/22/2013 10:28:38AM • I Common Well Name: 3-43 AFE No Event Type: WORKOVER (WO) Start Date: 3/31/2013 End Date: 4/13/2013 X4 -00X5N -E:RIG (5,417,000.00 ) Project: Endicott Site: End SDI Rig Name/No.: DOYON 14 Spud Date/Time: 4/15/1994 12:00:00AM Rig Release: 4/13/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: 48 : 43 4/15/1994 00:00 @56.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 06:00 - 07:30 1.50 CLEAN P DECOMP PULL OUT OF HOLE WITH PJSM -FLOW CHECK WELL FOR 10 MINUTES, WELL ON VACUUM. -PULL OUT OF HOLE FROM 10190' TO 9744' WITH CLEAN OUT AND SCRAPER ASSEMBLY BHA# 11 LAYING DOWN DRILL PIPE. - RECIPROCATE CASING SCRAPER FROM 9737' TO 9687' MULTIPLE TIMES. 07:30 - 09:30 2.00 CLEAN P DECOMP SERVICE RIG. -SLIP AND CUT 59.5 FOOT OF DRILL LINE. *FIRE DRILL, RESPONSE TIME 1:20 MINUTES. 09:30 - 12:00 2.50 CLEAN P DECOMP PULL OUT OF HOLE WITH CLEAN OUT BHA -PULL OUT OF HOLE LAYING DOWN SINGLES FROM 9744' TO 6600' WITH CLEAN OUT AND SCRAPER BHA *OUTER ANNULUS PRESSURE= 0 PSI. *FLUID LOSSES FROM MIDNIGHT TO NOON= 37 BARRELS. 12:00 - 13:00 1.00 CLEAN P DECOMP PULL OUT OF HOLE WITH CLEAN OUT BHA CONTINUE. -PULL OUT OUT OF HOLE LAYING DOWN SINGLES FROM 6600' TO 5500' WITH CLEAN OUT AND SCRAPER BHA. 13:00 - 17:00 4.00 CLEAN N RREP DECOMP TROUBLE SHOOT TOP DRIVE FAILURE -TOP DRIVE LINK TILT HYDRAULIC SYSTEM NOT FUNCTIONING PROPERLY. AFTER TROUBLE SHOOTING, RIG MECHANIC AND ELECTRICIAN RESET TOP DRIVE POWER UNIT AND LINK TILT FUNCTIONING PROPERLY. 17:00 - 21:00 4.00 CLEAN P DECOMP PULL OUT OF HOLE WITH CLEAN OUT BHA CONTINUE.. -PULL OUT OF HOLE FROM 5500' TO 400' WITH CLEAN OUT AND SCRAPER BHA, LAYING DOWN SINGLE TO PIPE SHED. * *NOTIFICATION SENT TO AOGCC ON 4/11/13 @ 20:00 OF MIT ON 4/12/13. ** 21:00 - 21:30 0.50 CLEAN P DECOMP LAY DOWN DRILL COLLARS. -FLOW CHECK WELL FOR 10 MINUTES FOR NON - SHEARABLES ACROSS STACK, WELL TAKING FLUID. -LAY DOWN 4-3/4" DRILL COLLAR SINGLES TO PIPE SHED. 21:30 - 22:30 1.00 CLEAN P DECOMP LAY DOWN CLEAN OUT AND SCRAPER BHA# 11. -LAY DOWN BUMPER SUB, OIL JARS, SCRAPER, BOOT BASKETS, AND MILL. RECOVER 1 "X 3/4" PIECE OF PACKER SLIP, SMALL AMOUNT OF PACKER RUBBER, SAND AND METAL PARTICLES, TOTAL 1 GALLON FROM BOOT BASKETS AND MAGNETS. 22:30 - 00:00 1.50 FISH P DECOMP MOBILIZE FISHING TOOLS WITH PJSM - MOBILIZE BAKER FISHING TOOLS OFF RIG FLOOR. *OUTER ANNULUS PRESSURE= 0 PSI. *FLUID LOSSES FROM NOON TO MIDNIGHT= 32 BARRELS. *TOTAL FLUID LOSSES FOR THE PAST 24 HOURS= 69 BARRELS = 2.8 BARRELS PER HOUR. Printed 4/22/2013 10:26:38AM " F, :`'x` r r i S 7 e r ,T�. `Y'a�: ,,. ' Common Well Name: 3-43 AFE No Event Type: WORKOVER (WO) Start Date: 3/31/2013 End Date: 4/13/2013 X4 -00X5N -E:RIG (5,417,000.00 ) Project: Endicott Site: End SDI Rig Name/No.: DOYON 14 Spud Date/Time: 4/15/1994 12:00:00AM Rig Release: 4/13/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: 48 : 43 4/15/1994 00:00 @56.00usft (above Mean Sea Level) Data From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 4/12/2013 00:00 - 00:30 0.50 CLEAN P DECOMP FLUSH OUT BOP STACK -MAKE UP BOP STACK WASHER. -PUMP 9.5 BARRELS PER MINUTE WITH 100 RPM WHILE RECIPROCATING STRING THROUGH STACK 00:30 - 02:00 1.50 CLEAN P RUNCMP PULL WEAR BUSHING. -VOID BOP STACK OF ALL FLUIDS. -RIG UP TO PULL WEAR BUSHING, PULL WEAR BUSHING. -TEST RUN 12 "X 4.5" FMC TUBING HANGER THROUGH BOPS -GOOD 02:00 - 04:00 2.00 RUNCOM P RUNCMP RIG UP TO RUN COMPLETION. - REMOVE SHORT BALES FROM TOP DRIVE, INSTALL LONG BALES. -LAY DOWN WEAR BUSHING AND BUSHING RUNNING TOOL. -PICK UP SINGLE JOINT COMPENSATOR AND ELEVATOR -MAKE UP SAFETY JOINT AND CROSS OVER ON FULL OPEN SAFETY VALVE. -RIG UP DOUBLE STACK TONGS. 04:00 - 12:00 8.00 RUNCOM P RUNCMP RUN 4.5" COMPLETION WITH PJSM. -RUN 4.5" TC II L -80 COMPLETION WITH HES 7 5/8" X 41/2" TNT PACKER TO 5520'. COMPLETION RUN WITH TORQUE TURN TO 3850 FOOT POUNDS. STABBING GUIDE AND HAND START EACH JOINT. JET LUBE SEAL GUARD THREAD COMPOUND USED ON EACH JOINT. ALL CONNECTIONS BELOW TNT PACKER BAKER LOC'D 'KICK WHILE TRIPPING DRILL, (D1) `OUTER ANNULUS PRESSURE= 0 PSI. `FLUID LOSSES FROM MIDNIGHT TO NOON= 30 BARRELS. 12:00 - 16:00 4.00 RUNCOM P RUNCMP RUN 4.5" COMPLETION WITH PJSM CONTINUE. -RUN IN HOLE FROM 5520' TO 8370' WITH 4.5 12.6# TC -II TUBING. 'CHUCK SHEVE OF AOGCC WAIVED WITTNESS OF MIT INNER ANNULUS TEST AT 1535 HOURS ON 4/12/2013. 16:00 - 17:30 1.50 RUNCOM P RUNCMP RUN CONTROL LINE WITH PJSM. - PICK UP SCHLUMBERGER SPOOLER. -RIG UP AND TEST CONTROL LINE. TEST CONTROL LINES TO 5000 PSI FOR 10 MINUTES. 17:30 - 20:00 2.50 RUNCOM P RUNCMP RUN 4.5" COMPLETION WITH DUAL CONTROL LINES. - RUN CONTROL LINE FROM HES XXO WITH CLAMPS AT EACH COUPLING. RUN IN HOLE FROM 8370' TO 9802'. Printed 4/22/2013 10:26:38AM • • . : + t a rs �, z E, a f er- s H a e i a ,' �e r < t r • Common Well Name: 3-43 AFE No Event Type: WORKOVER (WO) Start Date: 3/31/2013 End Date: 4/13/2013 X4- 00X5N -E:RIG (5,417,000.00 ) Project: Endicott Site: End SDI Rig Name/No.: DOYON 14 Spud Date/Time: 4/15/1994 12:00:00AM Rig Release: 4/13/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: 48 : 43 4/15/1994 00:00 ©56.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 20:00 - 20:30 0.50 BOPSUR P RUNCMP PREP HANGER, RUN CONTROL LINE THROUGH CONTROL PORT.. -MAKE UP LANDING JOINT AND TUBING HANGER. - SCHLUMBERGER REP. AND FMC REP. TEST CONTROL LINE TO 5000 PSI. FOR 5 MINUTES CUT AND CAP CONTROL LINE 8 FT. ABOVE HANGER. -FINAL PICK UP WEIGHT WITH BLOCKS= 171K. -FINAL SLACK OFF WEIGHT WITH BLOCKS= 150K. 'BLOCK WEEGHT ON DOYON 14 =50K -RAN A TOTAL OF(40) 5/8" STAINLESS STEEL BANDS ON CONTROL LINE. 20:30 - 21:00 0.50 BOPSUR P RUNCMP LAND TUBING HANGER. 'CENTER OF ELEMENT OF TNT PACKER AT 9712.30', WIRELINE ENTRY GUIDE BOTTOM AT 9835.67' WITH TUBING HANGER LANDED. -RUN IN HOLE AND LAND 12 "X 4.5" FMC TUBING HANGER. FMC REP. RAN IN LOCK DOWN SCREWS. - SIM -OPS: RIG DOWN TUBING COMPLETION TOOLS. SPOT LITTLE RED SERVICES INTO POSITION FOR FREEZE PROTECT. SPOT VAC TRUCK WITH 8.5 PPG SEAWATER WITH CORROSION INHIBITOR. 21:00 - 22:30 1.50 BOPSUR P RUNCMP PRESSURE TEST LITTLE RED FREEZE PROTECT LINE WITH PJSM. - PJSM, BULL HEAD DOWN THE INNER ANNULUS. 8.5 PPG SEAWATER WITH CORROSION INHIBITOR AND DIESEL FREEZE PROTECT. - PRESSURE TEST LITTLE RED SERVICES LINE TO 250 PSI LOW/ 4000 PSI HIGH FOR 5 MINUTES EACH. 22:30 - 23:30 1.00 BOPSUR P RUNCMP BULLHEAD DOWN INNER ANNULUS. - ATTEMPT TO BULLHEAD WITH 10 BARRELS OF 8.5 PPG SEAWATER AT 120 DEGREES WITH CORROSION INHIBITOR DOWN THE INNER ANNULUS. PUMPING 0.5 BARRELS PER MINUTE WITH 570 PSI. *CALLED DAVE BJORKANDAPPROVED TO PUMP DOWN INNER ANNULUS AND TAKE RETURNS THROUGH TUBING BECAUSE OF FORMATION NOT READILY ACCEPTING WELLBORE FLUIDS. Printed 4/22/2013 10:26:38AM • Common Well Name: 3-43 AFE No Event Type: WORKOVER (WO) Start Date: 3/31/2013 End Date: 4/13/2013 X4 -OOX5N -E:RIG (5,417,000.00 ) Project: Endicott Project: Site: End SDI Rig Name/No.: DOYON 14 Spud Date/Time: 4/15/1994 12:00:00AM Rig Release: 4/13/2013 Rig Contractor: DOYON DRILLING INC. UWI: Active datum: 48 : 43 4/15/1994 00:00 ©56.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 23:30 - 00:00 0.50 BOPSUR P RUNCMP SPOT CORROSION INHIBITOR IN INNER ANNULUS. -SHUT DOWN PUMP, LINE UP TO PUMP DOWN INNER ANNULUS AND TAKE RETURNS FROM TUBING TO PITS. - CONTINUE TO PUMP 240 BARRELS OF 8.5 PPG SEAWATER AT 120 DEGREES WITH CORROSION INHIBITOR DOWN THE INNER ANNULUS TAKING RETURNS TO THE PITS THROUGH THE 4.5" TUBING. -PUMP 4 BARRELS PER MINUTE WITH 400 PSI. *OUTER ANNULUS PRESSURE= 0 PSI. *FLUID LOSSES FROM NOON TO MIDNIGHT= 17 BARRELS. *TOTAL FLUID LOSSES FOR THE PAST 24 HOURS= 47 BARRELS 1.95 BARRELS PER HOUR. 4/13/2013 00:00 - 00:30 0.50 BOPSUR P RUNCMP CONTINUE TO SPOT CORROSION INHIBITOR IN INNER ANNULUS -PUMP 120 DEGREE SEAWATER WITH CORROSION INHIBITOR DOWN INNER ANNULUS, TAKING RETURNS THROUGH TUBING TO PITS AT 4 BARRELS PER MINUTE AT 440 PSI. TOTAL OF 250 BARRELS PUMPED 00:30 - 03:00 2.50 BOPSUR P RUNCMP FREEZE PROTECT WELL. -PUMP 50 BARRELS OF 120 DEGREE DIESEL DOWN INNER ANNULUS TAKING RETURNS THROUGH TUBING TO PITS WITH LITTLE RED SERVICES PUMPING AT 1.5 BARRELS PER MINUTE AT 200 PSI. -CLOSE INNER ANNULUS AND BULLHEAD 30 BARRELS OF 120 DEGREE DIESEL DOWN THE 4 1/2" TUBING WITH LITTLE RED SERVICES PUMPING AT 0.5 BARRELS PER MINUTE AT 600 PSI. -SHUT IN 4 1/2" TUBING AND LET TUBING PRESSURE BLEED FROM 600 PSI TO 0 PSI IN 20 MINUTES. 03:00 - 04:00 1.00 RUNCOM P RUNCMP SET PACKER V ITH PJSM. -RIG DOWN AND REMOVE FULL OPENING SAFETY VALVE FROM TOP OF LANDING JOINT. -DROP BALL AND ROD. -LAY DOWN LANDING JOINT. -CLOSE BLIND /SHEAR RAMS AND LINE UP TO PUMP THROUGH KILL LINE. -SET 7 5/8 "X 41/2" TNT PACKER BY PUMPING DOWN 4 1/2" TUBING WITH BALL ON SEAT. PACKER SET AT 4283 PSI. 'CENTER OF ELEMENT OF TNT PACKER AT 9712.30', WIRELINE ENTRY GUIDE BOTTOM AT 9835.67' WITH TUBING HANGER LANDED. Printed 4/22/2013 10:26:38AM • • J ,PrS 0 � ± � r £- � �� e � s � � �^� � � � 4 4.Je,®I f. '3' p, ......,mot x . Common Well Name: 3-43 AFE No Event Type: WORKOVER (WO) Start Date: 3/31/2013 End Date: 4/13/2013 X4 -00X5N -E:RIG (5,417,000.00 ) Project: Endicott Site: End SDI Rig Name/No.: DOYON 14 Spud DateTme: 4/15/1994 12:00:00AM Rig Release: 4/13/2013 Rig Contractor. DOYON DRILLING INC. UWI: Active datum: 48 : 43 4/15/1994 00:00 @56.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) _ 04:00 - 06:30 2.50 RUNCOM P RUNCMP TEST TUBING AND IA WITH PJSM -TEST TUBING TO 4000 PSI. FOR 30 CHARTED MINUTE. -BLEED TUBING DOWN TO 1500 PSI. AND TEST 7 -5 /8" X 4 1/2" INNER ANNULUS FOR 30 CHARTED MINUTES. * BOTH TEST PASSED TEST CRITERIA C. NOTIFY JIM WILLINGHAM WTLAND TOLD TO PROCEED WITH OPERATIONS. 06:30 - 08:00 1.50 RUNCOM P RUNCMP BLEED OFF PRESSURE WITH PJSM. -BLEED OFF PRESSURE FROM 7 -5/8" X 4" INTER ANNULUS. -VOID STACK OF FLUIDS. -DRY ROD IN TWO WAY CHECK VALVE. 08:00 - 08:30 0.50 RUNCOM P RUNCMP TEST TWO WAY CHECK WITH PJSM. -TEST TWO WAY CHECK FROM TOP TO 250 PSI. LOW / 4000 PSI HIGH FOR 10 CHARTED MINUTES. 08:30 - 11:00 2.50 BOPSUR P RUNCMP NIPPLE DOWN BOP STACK WITH PJSM. -VOID STACK OF FLUID. - NIPPLE DOWN STACK AND STAND BACK ON PEDESTAL. 11:00 - 12:00 1.00 WHSUR P RUNCMP TERMINATE CONTROL LINE. - TERMINATE HXO CONTROL LINE PER SCHLUMBERGER REP INSTRUCTIONS. *OUTER ANNULUS PRESSURE= 0 PSI. * ZERO FLUID LOSSES FROM MIDNIGHT TO NOON. 12:00 - 13:00 1.00 WHSUR P WHDTRE PRESSURE TEST CONTROL LINE. -FMC AND SCHLUMBERGER CONTINUE TO INSTALL CONTROL LINE ON TUBING HANGER. TEST CONTROL LINE TO 5000 PSI FOR 5 MINUTES, TEST GOOD. -PJSM, NIPPLE UP TREE. 13:00 - 13:30 0.50 WHSUR P WHDTRE MOBILIZE TREE. - MOBILIZE ADAPTER FLANGE AND TREE INTO CELLAR. 13:30 - 17:00 3.50 WHSUR P WHDTRE NIPPLE UP TREE. - INSTALL ADAPTER FLANGE AND ORIENT TREE AS PER PAD OPERATOR. - TORQUE UP AND TEST HANGER VOID. TEST VOID TO 5000 PSI. FOR 30 MINUTES AS PER FMC REP. - SIM -OPS: SKID CONVEYOR #2, RIG DOWN ROCK WASHER FOR RIG MOVE. 17:00 - 18:00 1.00 WHSUR P WHDTRE TEST TREE WITH PJSM. -TEST TREE WITH DIESEL. TEST TO 250 PSI. LOW/ 3500 PSI HIGH FOR 5 CHARTED MINUTES EACH, TEST GOOD. Printed 4/22/2013 10:26:38AM • • ,.s ;r '�`,'s�:7 -# 6 � i Y ' � m e cra�s: ` n '"'' RAe ' i r t"e„S�'. ,. , ., ,. ,a ... . „ , _ ,v. .. a . .:,& . " ° '.:� -:t .'.' .. ,x, Common Well Name: 3-43 AFE No Event Type: WORKOVER (WO) Start Date: 3/31/2013 End Date: 4/13/2013 X400X5N -E:RIG (5,417,000.00 ) Project: Endicott Site: End SDI Rig Name/No.: DOYON 14 Spud DateTme: 4/15/1994 12:00:00AM Rig Release: 4/13/2013 Rig Contractor. DOYON DRILLING INC. UWL Active datum: 48 : 43 4/15/1994 00:00 ©56.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 18:00 - 20:30 2.50 WHSUR P WHDTRE PULL TWO WAY CHECK, INSTALL BACK PRESSURE VALVE. -PJSM ON TESTING LUBRICATOR, TEST LUBRICATOR. TEST TO 250 PSI LOW/ 3500 PSI. HIGH FOR 5 CHARTED MINUTE EACH. -PULL TWO WAY CHECK. -RETEST LUBRICATOR, TEST TO 250 PSI LOW/ 3500 PSI. HIGH FOR 5 CHARTED MINUTE EACH. - INSTALL BACK PRESSURE VALVE.'NOTABLE TO TEST BACK PRESSURE VALVE DUE TO WELL CONFIGURATION. -LAY DOWN LUBRICATOR. 20:30 - 21:00 0.50 HSUR P WHDTRE RIG UP TREE. W - INSTALL BLANK FLANGES, GAUGES AND VALVES ON TREE. •WSLAND TOUR PUSHER VERIFIED CONDUCTOR FLUTES FULLY CEMENTED.' - TUBING PRESSURE= 0 PSI., OUTER ANNULUS PRESSURE= 0 PSI., INNER ANNULUS PRESSURE= 100 PSI. 21:00 - 22:00 1.00 MOB P PRE `RIG DOWN FOR RIG MOVE. -CLEAN AND SECURE CELLAR. - DISCONNECT BREAK TRAILER. -POWER DOWN ROCK WASHER. 'RIG RELEASED FROM END3 -43 AT 22:00 TO GO TO PBU X -10. Printed 4/22/2013 10:26:38AM TREE = 4 -1/16" DRYHOLE NOTES: H26 Dt AV 230 ACTUATOR S 10-3/4 • E N 0 3 !` 3 26 NI ON AJL & INJECTORS * "« WELL REQUIRES A SSSV .* INITIAL KB.EI.EV= 56' BF E.EV 14.50' I 1 111 • KOP= 322 44 ... r 11 i 1503' H 4-1/2" HES XXO SSSV NP, 13 = 3.813" Max Angle = 11 * © 8232 a� 1 1 1 1 1 ` Datum MD= _�.._..,_..,.. 10143' �j © • i . 1812' --H7 -518" HES ES I Datum TVD = 10000 SS 1 ���� 1835' H7-5/8" IS OZONE EXT CSG FKR, 0 = 6.83' 7 - 518" LNR PATCH, 29,7 #, L -80 VAM TOP, —1 1857' I Ili .0569 bpf, D = 6.94' 10 -3/4" CSG, 45.5#, NT80 BTRS, ID = 9.950' H 2740' Minimum ID = 3.725" @ 9818' 4 -112" HES XN NIPPLE 9680' - 14 -1/2" FES X NP, ID = 3.813" I �� IMO 9710' —f 7 -5 /8 " X4-1 /2" HES TNT FKR, ID = 3.856" I 9745' H4 -1/2" EES X NP, ID = 3.813` I I I 9818' H 4 -112" HES XN NP, ID = 3.725" I I 4- 112' TBG, 12.6#, L -80 TCII, --I 9834' .0152 bpf, 4:1= 3.958" \ 9836' — 14 -1/2' W1LEG (9 -C, ID =3.958" I PERFORATION SI flrW I RY ? [H E MO TT NOT LOGGED I REF LOG: SLB on 05/02/94 ANGLE AT TOP FERE:2'( 10010' I Note: Refer to Roduction I7B for historical perf data SIZE [ SFF INTERVAL Opn /Sqz SHOT [ SQZ 2" 4 10010 - 10080 0 03/22/99 I r 2 -112 4 10106 - 10114 0 10/27/95 ' 2 -1/2" 4 10108 -10112 0 04/04/95 2 -1/8" 4 10132 - 10140 S 05/25/94 02/03/95 2-1/2" 4 10132 - 10140 0 10/27/95 2-1/8" 4 10132 - 10140 0 02/06/95 I 10190' I —IFLL (TAGGED 04/10113 RIG) I 2 -1/8" 4 10154 - 10156 S 05/25/94 02103/95 109 c38• J TOP OF CEMENT CAP (02107!10) 2 -1/8' 4 10162 - 10164 S 05/25/94 02/03/95 1 I � - " 4 10170 - 4 1 10190 0 03/22/99 1 2 1 I 10220 I—I SAND PLUG (02i05/10) 2 -1 /8* 4 10222 - 10245 S 05/25/94 02/03195 r 2 -5/8 4 10228 - 10245 C 03/01/95 ' 2 -1/2" 4 10228 - 10245 C 10/27/95 2 -1/8" 4 10287 - 10291 S 05/25/94 02/03/95 10386' H POST' SQZ ID (02/04/95) I 2 -1/2' 6 10287 - 10307 C 06/02/05. ' 2-112' 6 10315 - 10335 C 06/02/05 '••••10386' —I FISH - CENTRALIZER ARM (07/24/94) I 2 -1/8" 4 10108 - 10112 S 05/25/94102/03/95 . 4V440V4 . 4 . " 10413' —I ELM TD (05/26/94) I . PBTD H 10478' 1'ff••ccf•Vg f • ••••••••••• 1 1 1 •1 •1 •1 •1 •1 •1 •1 1 7 -5/8" LNR, 29.7 #, NT95HS NSCC, H 10558' 11.1.1.1.1.1.1.1.1.1.1.1 t .0459 bpf , ID = 6.875" DATE REV BY COf tv13+ITS DATE REV BY /DINE +ITS ENDICOTT UNIT 05/25/94 13-15 INITIAL COMPLETION WELL 3-43 / P.36 12/20/94 D-15 RWO PERIVIT N3: '1931700 04/13/13 D-14 RIAIO API N3: 50- 029- 22416 -00 04/18/13 PJC DRLG HO CONS SEC 8, T1114, R17E, 2503' FNL & 640' FEL 05/01/13 JMJJI ID DRAWING OCIMECTIONS EP Exploration (Alaska) • • Or rk 69 l'* \ I %%y A THE STATE Alaska Oil and as " s � i — � � 0J L i s Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue OF Anchorage, Alaska 99501 -3572 ALA Main: 907.279.1433 Fax: 907.276.7542 David Reem SCANNED FEB 2 6 2013 Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 /� 3 '' Anchorage, AK 99519 -6612 v1 Re: Endicott Field, Endicott Oil Pool, 3- 43/P -36 Sundry Number: 313 -020 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. 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 reconsideration. A request for reconsideration 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. Sincerely, Cathy P. Foerster Chair DATED this 2 day of January, 2013. Encl. • STATE OF ALASKA , RECEIVED ALA. OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL JAN 1 J 2013 oT s /12..s/!3 20 AAC 25.280 A G l�V p�C 1. Type of Request: ❑ Abandon ❑ Plug for Redrill ❑ Perforate New Pool ® Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate :.4 Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ® Alter Casing ❑ Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration (Alaska) Inc. ❑ Exploratory ❑ Stratigraphic 193 -170 - 3. Address: ❑ Development ® Service"' 6. API Numbe P.O. Box 196612, Anchorage, Alaska 99519 -6612 50.029- 22416 -00 -00 - 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 3- 43/P -36 Will planned perforations require a Spacing Exception? ❑ Yes No 9. Property Designatior 10. Field / Pool(s): ADL 047502 & 047503 • Endicott Field / Endicott 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) 10565' • 10448' ' 10478' 10391' 9793', 10198', 10220' 10386' Casing Length Size MD TVD Burst Collapse Structural Conductor 94' 30" 44' - 131' 44' - 131' Surface 2697' 10 -3/4" 43' - 2740' 43' - 2731' 5210 2480 Intermediate 10516' 7 -5/8" 42' - 10558' 42' - 10471' 8180 5120 Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10010' - 10190' 9923' - 10103' 3 -1/2 ", 9.3# L -80 9800' Packers and SSSV Type: 7 -5/8" x 3-1/2" Baker FB -1 Packer Packers and SSSV 9754' / 9668' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal BOP Sketch ❑ Detailed Operations Program ❑ Exploratory ❑ Stratigraphic ❑ Development ® Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation March 10, 2013 ❑ Oil ® WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG ❑ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: David Bjork, 564 -5683 Printed Name: Davi eem Title: Engineering Team Leader Email: David.Bjork @bp.com Signature: R _ Phone: 564 - 5743 Date: 1 - /6_20'3 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness n ��� Sundry Number: t 5- ❑ Plug Integrity LJ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: goo p s r tiBGMS JAN 2 8 2013 Spacing Exception Required? ❑ Yes ❑ No Subsequent Form Required: 1G — 4 c /' APPROVED BY f / Approved By: COMMISSIONER THE COMMISSION Date: l 6 Fo 1 i 1 / 12 Approved application is valid for 12 from the date of approval Submit In Duplicate . 1./ L)rU L l 22- // months fr 3 , � , . • • O bp G U i egkeltheAsirsy END 3 -43i Rig Workover i Scope of Work: Repair OA x Conductor communication. Pull 3 - Tubing. Run USIT log and find top of cement, cut and pull 7 casing as deep as possible. Tie back 7 casing and cement to surface, squeeze cement out the hole in the surface casing to the conductor. Top off conductor flutes with cement. Install 7 hanger and pack -off. Mill and retrieve old FB -1 packer. Run a new 4 - Carbon Completion. MASP: 2,892 psi Well Type: Injector Estimated Start Date: March 10 , 2013 Production Engineer: Jennifer McLeod Intervention Engineer: Dave Bjork Pre-rig prep work: S 1 Drift for jet -cutter to - 9800'md. F 2 MIT -T to 3,500 psi. MIT -IA to 3500 psi. W 3 Check the tubing and casing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). PPPOT -T & IC. E 4 Power Jet cut the first full joint of 3 -'/ 9.2# EUE 8rd tbg at 9745'md (the FB -1 packer will be milled up during RWO). (Reference Doyon -15 tubing tally of 12/18/94) Post cut CMIT -TxIA to 1,000 -psi ✓ 5 Set a BPV in the tubing hanger. Secure well. O 6 Remove the well house & flow line. Level the pad as needed for the rig. Will likely require two well houses on either side of End3 -43 to be removed as well ... Doyon-14's Tool- pusher and WSL to confirm. Proposed Procedure: 1. MIRU Rig. ND tree. NU 4 Preventer BOPE with annular, 3 - x 6" VBR's, blind shears, mudcross and 2 - x 5" VBR's. Pressure test the rams to 4 000.psi and annular to 3,500 psi. Circulate out freeze protection fluid and circulate well to clean seawater. 2. Pull and LD 3 - tubing string from cut. 3. RU E -line, Run USIT in the 7- casing to determine TOC in the 7 x 10 - annulus. 4. Set retrievable bridge plug 100' below the top of cement. 5. Change upper VBR's to 7 fixed and test to 3 500-o.sj 6. Cut and Pull 7/ production casing. 7. Run and fully cement new 7 29.7# L -80 VamTopHC casing with ECP, ES Cementer and casing patch to surface. Squeeze cement into the surface casing x conductor leak and top off conductor flutes. 8. Change upper VBR's to 3-11 x6 "and test to 4,000 -psi. 9. Drill out shoe tract and retrieve the RBP. 10. Mill and retrieve FB -1 packer. Run a scraper and clean out to 10,198' 11. Run 4 - x 7 -5/8" L -80 injection completion. 12. Displace the IA to completion fluid, freeze protect and set the packer. 13. Test tubing and IA to4,000-psi, 14. Set TWC. ND BOPE. NU and test tree. Pull TWC, set BPV. RDMO. TREE: 4- 1/16" / 5000 IW / (BAKER "CAC" ACTUATORS) SA NOTES: H2S READINGS W ELLHEAD: 13 -5/8" / 0 psi / FMC / CCL / CTC AVERAGE 230 - 260 PPM ON A/L 8 R.T. ELEV = 58.85' GAS INJECTORS. WELL B.F. ELEV = 14.50' , I -, REQUIRES SSSV. MAX DEV = 10° 42' ■ @ MD = 8,325' I I 3 - 1/2" HES "XDB" 1 1524' / SSSV nipple (2.75" ID) 10 -3/4 ", 45.5#/ft, NT -80, Btrs Csg 2740 I Alli 3 -1/2" 9.3 ppf L -80 EUE 8rd Tubing GAS LIFT MANDRELS (1 -1/2" McMURRAY FHMO) i 11 ST MD TVD VLV LATCH PORT DATE 6 3661 3500 DMY RK 0 01/03/10 5 5372 5250 DMY RK 0 4 6619 6500 DMY RK 0 01/03/10 1 3 7336 7200 DMY RK 0 2 8050 7900 DMY RK 0 J 1 8747 8600 DMY RK 0 01/03/10 3 t1 ∎- 1. At r r .L J 3- 1/2 " 'X' NIPPLE 9,745' 2.750" ID BAKER "GBH -22S" LOCATOR & BONDED SEAL ASSEMBLY NOTE: TUBING NOT ANCHORED BAKER "FB -1 PACKER 1 9,754' /1 'VI 4.00" ID P SEAL BORE PERFORATION SUMMARY REF LOG: SBL ON 05/02/94 9777' 13-1/2" X NIP, ID = 2.75" I ANGLE AT TOP PERF: 9793' 3 -1/2" XX PLUG (09/27/11) Note: Refer to Production DB for historical pert date Pida 9793' 13-1/2" X NIP, ID = 2.75" I SIZE SPF INTERVAL ** DATE 2" 4 10010 - 10080 0 2 -1/8" 4 10106 - 10114 0 9800' 3 -1/2" WLEG, ID = ? ? ?? 2 -1/2" 4 10132 - 10140 0 I 979 ELMD TT LOGGED ON ? ? / ? ? / ?? I 10154 - 10156 S 10162 - 10164 S 10198' TOP OF CMT CAP (02/07/10) 2" 4 10170 -10190 0 P•••••• #••44 10228 - 10245 S 1.4................ 2 -1/2" 4 10228 - 10245 C 10220' SAND PLUG (02/05110) 10287 - 10291 S 2 -1/2" 6 10287 - 10307 C 06/02/05 2 -1/2" 6 10315 - 10335 C 06/02/05 I ** KEY: 0 = OPEN / C = CLOSED / SQZ= SQUEEZED I POST SQZ TD = 10,386' (2/4/95) FISH IN HOLE 7/24/94 (CENTERLIZED ARM FROM ir ELM TD = 10,413' PBTD I 10,478' I • • (5/26/94) 7 -5/8 ", 29.7 # /ft, 10,558' l NT -95HS, NSCC DATE REV BY COMMENTS DATE REV BY COMMENTS ENDICOTT UNIT 05/09/94 JJM COIL COM PLETION 08/15/11 DW /JMD ADDED H2S NOTE WELL: 3 -43 / P-36 03/26/99 DB ADPERF 10/11111 CHN/ PJC SET XX PLUG (9/27/11) PERMIT No: 03/06/05 NBF /TLH ADPERF API No: 50 -029- 22416 -00 SEC T N R E 01/03/10 ? /JPJC GLV C/O 03/18/10 JKD /SV SAND /CMT PLUG (02/07/10) BP Exploration (Alaska) 1 TREE: 4- 1/16" / 5000 IW / (BAKER "CAC" ACTUATORS) SA NOTES: H2S READINGS • - WELLHEAD: 13 -5/8" / psi / FMC / CCL / CTC d AVERAGE 230 - 260 PPM ON A/L & R.T. ELEV = 58.85' END 3 -43 GAS INJECTORS. WELL e P RWO REQUIRESASSSV. B.F. ELEV = 14.50' Proposed MAX DEV = 10° 42' @ MD = 8,325' 1524' 4 -1/2" HES "XXO" 9 -5/8" HES ES Cementer' —1 255 I SVLN nipple (3.813" ID) 19-5/8" BKR ECP 1_1 2678• 19-5/8" Bowen Casing Patch' — I 2555 I 7 -5/8" 29.7 #, L -80, VamTopHC — 2600' 2740 10 3/4 ", 45.5 # /ft, NT -80, Btrs Csg 4 -1/2" 12.6 ppf L -80 TC -II Tubing 9682' — 4-1/2" X NP, ID = I I 3.813" 3 9,714' HES 7 -5/8" x 4 -1/2" TNT PKR. ID =3.833 PERFORATION SUW?AARY REF LOG: SBL ON 05/02/94 ANGLE AT TOPFERF: I , 9748' — 4 -1/2" X NP, ID= Note: Refer to Production DB for historical pert date 3.813" SEE SFr INTERVAL DATE -1/2' 2" 4 10010 - 10080 0 I I 9819' — 4 3 25 XN NP, D 2 -1/8" 4 10106 - 10114 0 2 -1/2" 4 10132 - 10140 0 9837' I — 4 -1/2" WLEG 10154 -10156 S 10162 -10164 S ' 2" 4 10170 - 10190 0 10228 - 10245 S 10198' — TOP OF CMf CAP (02/07/10) 2 -1/2" 4 10228 - 10245 C • • • • • • • • • • • • • • • • • * 44 10287 - 10291 S ......... 10220' — SAND PLUG (02/05/10) 2 -1/2" 6 10287 - 10307 C 06/02/05 2 -1/2" 6 10315 - 10335 C 06/02/05 " KEY: 0 = OPEN IC = CLOSED I SQZ POST SQZ TD = 10,386' (2/4/95) FISH IN HOLE 7/24/94 (CENTERLIZED ARM FROM ELM TD = 10,413' PBTD 10,478' Al i (5/26/94) 7 -5/8 ", 29.7 # /ft, 10,558' X X X X NT -95HS, NSCC DATE REV BY COMMENTS DATE REV BY COMMENTS ENDICOTT UNIT 05/25/94 D15 INITIAL COMPLETIO 08/15/11 DW /JWD 1-2S NOTE WELL: 3 -43 / P -36 03/26/99 DB ADPERF 10/11/11 CHN PJC SET XX PLUG (9/27/11) PERMIT No: 03 /06 /05 NBF/TLH ADPERF AR No: 50- 029 - 22416 -00 01/03/10 ?/ JPJC GLV GO SEC T N R E 03/18/10 JKD/SV SAND/CMT PLUG (02/07/10) BP Exploration (Alaska) RIG FLOOR 33.7 ' AGL n iW Mg • VALVE LEGEND 1� ©T ©�0�©M0T01 1 BYPASS 1— Li 2 KILL I 3 CHOKE r' 4 BOTTOM RAMS I 5 BLIND RAMS 111.111M1 \ S 6 TOP PIPE RAMS • ACCUMULATOR: NL SHAFFER, 180 GAL, 6 STATION 7 ANNULAR 13 5/8 ". 5000 P0, HYDRIL ANNULAR BOP, TRIPLEX PUMP: 575 VAC, 30 HP STUDDED 3 000 PSI, H BOTTOM AIR PUMP: 1, NL SHAFFER N _ — �� FLANGED FGED TOP CD O ( iI) 0 .� I .• 13 5/9", 5000 PSI, 10' MPL OPERATORS, i HYDRL PIPE RAM 3 1/8' 5000 PSI SIDE OUTLET \ i 3" CHOKE LINE 13 E. 14' MPAPI. OPERATORS, C : : : _ a to i � () H1'0FO9L 8 BOND ND SHEAR RAM C _ : - ] • -- • STUDDED 80TTOM OX 160 BY PASS • • • S I /O" 5000 PSI HCR VALVE 1500 3000 ■l' 4 II'/IIII'1III II'1II' /II∎ 2' KILL LINE a .+ 3 I/8' 5000 PSI HCR VOLVEJ / N 3 3 1/8" 5000 PSI GATE VALVE • • 3 I/8' 5000 PSI CATE VALVE LMLML�LLL 1.111IMIPW SINGLE 13 5/8', 5000 PSI, 10' NPL OPERATORS, r� �0 \ �� -��� I � I SING PPE RAM • __ SNDOED BOTTOM/FLANGED TOP EN 1X7 ACCUMULATOR MANIFOLD o ; 110 4I114111110 4I 18 BOTTLES, 10 GALLONS EACH ri -- VV , AN AN AN P BOP STACK ELEVATION C : : REMOTE PANEL IN DOGHOUSE I AND UTILITY MODULE ling III • I I� NITROGEN BACKUP BOTTLES 21 1/4', 2000 PSI, -- 16" 150 PS HYDR. ASP HYOTSL 130P/DNERTER OPERATED KNIFE GATE VALVE STUDDED TOP/FLANGED BOTTOM 1' C/N PLUG im■■ FLANGE /FLANGE 60 73B a �W01pI� NIN{3W eY NM gut °F - -_ —_ —_ 18' FLC'D VENT UNE - - -- -- -- __ I 01/18/00 5 OMB LEA UPDATE BOP 5008 PA .CI � 1 I I 03/05/01 4 OMB LEA WOW BOP SIRS RIG 14 ■11111MIIII I FLANGE 01/31/00 3 OMB LEA MOE aKKENOL LIES 1111E AND CONTROL BOP SYSTEM I 12 -20-00 2 OMB LEA OPM1E BOP Boat SURFACE DIVERTER CONFIGURATION 11 - - � 1 y mt LEA MEN 1$ N MEJO 0 11/28/98 8 RP w''''' er LEA Am 5 E.... 110.E ' 7' la 0ESCPPO x A NTS �H RI480PSYSACONTROL 1 ra 3Q2011 Not Operable Injector Report 4) • Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWellIntegrityCoordinator @bp.com] Sent: Thursday, November 24, 2011 9:59 PM To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA) Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O &M TL; AK, RES END Production Optimization Engineer; Kruger, Dale 0 Subject: 3Q2011 Not Operable Injector Report Attachments: Not Operable Injector Report 3Q2011.zip Tom, Jim, Phoebe and Guy, Attached is the 3Q 2011 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors classified as Not Operable. «Not Operable Injector Report 3Q2011.zip» Notes on wells: : ,3aa? ' Removed from Quarterly Injection Report: MPF -74 (PTD #1961080): Long term shut in that was returned to service. Passed MIT -IA on 09/11/11. Added to Quarterly Injection Report: 09 -36C (PTD #1951140): Leak found in tubing patch 13 -17 PTD #1820260: reclassified while flowline repair is being performed END 3- 43/P -36 (PTD #1931700 Surface casing leak discovered post Brinker treatment MPC -08 (PTD #1850140): Long term shut in requiring MITIA to be compliant MPF -89 (PTD #2050900): Surface casing leak MPF -99 (PTD #2061560): Long term shut in requiring MITIA to be compliant NGI -10 (PTD #1760690): TxIA communication when on gas injection, AA for IAxOA communication. R -02 (PTD #1781000): Identified TxIA communication with leak detect log S -09 (PTD #1821040): Shut in for rig workover to replace tubing U -04A (PTD #1920270): Starting head leak with a Furmanite repair failure Please call with any questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 11/28/2011 NOT OPERABLE: Injector END 3- 43/P -36 (PTD #1931700) Confirmed Surface Casing ... Page 1 ofd'' • •" Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIllntegrityCoordinator @bp.com] Sent: Thursday, July 21, 2011 9:38 PM To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS END OIM; AK, OPS END Facility & FieldO &M TL; AK, OPS END Board Operator; AK, OPS END AES Drillsite Lead; AK, OPS END Operations Lead Tech; AK, RES END Production Optimization Engineer; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Yeager, Kevin E Cc: McLeod, Jennifer D; Wood, Alecia; Grey, Leighton (CH2M Hill); Townsend, S. Eliot; Reynolds, Charles (ALASKA) Subject: NOT OPERABLE: Injector END 3- 43/P -36 (PTD #1931700) Confirmed Surface Casing Leak Attachments: END3 -43 TIO Plot 07- 21- 11.doc; 3-43 Wellbore Schematic.pdf All, Injector END 3- 43/P -36 (PTD #1931700) was confirmed to have a surface casing leak during an MIT -OA on 07/20/11. The well was converted to a produced water injector and had passed an AOGCC witnessed MIT -IA on 08/03/10. The well is reclassified as Not Operable and should not resume injection. The well will remain shut in until a repair option can be determined. A TIO plot and wellbore schematic are included for your reference. «END3 -43 TIO Plot 07- 21- 11.doc» «3-43 Wellbore Schematic.pdf» Please call if you have questions or concerns. Thank you, Taylor Taylor Wellman filling in for Mehreen Vazir /Jerry Murphy Office: 659 -5102 u Pager: 659 -5100 x 1154 .w .f Fro . K, D &C Well Integrity Coordinator Sent: Tues.a ay 31, 2011 2:08 PM To: 'Maunder, Thom. (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy (DOA) <guy.schwartz @alaska.gov>'; AK, OPS END OIM; AK, OPS END Facility & FieldO &M TL; AK, O• D Board Operator; AK, OPS END AES Drillsite Lead; AK, OPS END Operations Lead Tech; AK, RES END Production Optimization Engineer; AK, D &C Wir- • • - Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Yeager, Kevin E Cc: King, Whitney; McLeod, Jennifer D; Wood, Alec Subject: OPERABLE: Injector END 3- 43/P -36 (PTD #193 : 4 Surface Casing Leak Repaired with Brinker Platelets All, Injector END 3- 43/P -36 (PTD #1931700) was treated with Brinker Platele • 05/17/2011 to mitigate the surface casing leak. After the treatment, an MIT -OA to 1200 psi passed with no indica is • of a leak to atmosphere. The passing test verifies competent surface casing. The well has been reclassified as Op- = •le and may be placed on injection. A placard will be hung from the OA valve stating that the OA pressure must rema - •ove 25 psi to ensure positive pressure is applied to the platelets at all times. Please call with any questions or concerns. II I 7/29/2011 • • END 3- 43/P -36 (PTD #1931700) 07 -21 -2011 —343 Fy t :P10. 1 + j —a— OA maw OOA � OpOA 000 I 09,03/10 09A3P0 10M4/10 11/04/10 12/05/10 01+95111 02,75/11 0379,1 01/09/11 0509/11 06!09.'11 07/10.,1 2Q2011 Not Operable Injector "Fort • Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWeIIIntegrityCoordinator @bp.com] Sent: Monday, July 04, 2011 4:44 PM To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA) Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O &M TL; AK, RES END Production Optimization Engineer; Kruger, Dale 0 Subject: 2Q2011 Not Operable Injector Report Attachments: Not Operable Injector Report 2Q2011.zip Tom, Jim, Phoebe and Guy, Attached is the 2Q 2011 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors classified as Not Operable. «Not Operable Injector Report 202011.zip» Notes on wells: M l JUL 1 1 M Removed from Quarterly Injection Report: 13 -09 (PTD #1811580): RWO repaired TxIA comm. On 04/30/11 END 3- 43/P -36 PTD #1931700): urface casing leak repaired with Brink platelets on 05/17/11 LGI -08 (PTD #1860570 1 0 •perable Producer that had been mismarked in BP system as a not operable injector thereby being generated to report MPF -92 (PTD #1981930): SI waiting for AOGCC MIT -IA that passed an AOGCC MIT -IA on 04/17/11 MPF -95 (PTD #1981790): SI waiting for AOGCC MIT -IA that passed an AOGCC MIT -IA on 04/17/11 P2 -16 (PTD #1931230): RWO repaired PC leak and TxIA comm. On 04/15/11 U -10 (PTD #1851970): TxIA comm. That was repaired with a tubing patch on 06/05/2011. Moved to Monthly Injector report pending AOGCC witnessed test WGI -06 (PTD #1900300): RWO repaired TxIA comm. Well moved to Monthly Injector report pending AA cancellation Z -12 (PTD #1891020): TxIA communication repaired with cement packer on 05/24/11. Added to Quarterly Injection Report: L -223 (PTD #2090990): MIT -IA failed on 05/01/11. MPS -07 (PTD #2020720): MIT -IA failed on 04/09/11 MPS -13 (PTD #2021140): Passed MIT -IA on 04/11/11. LTSI that requires AOGCC MIT -IA when put on production. V -227 (PTD #2091160): Exhibiting rapid IA repressurization. Classified as Not Operable on 06/20/11. 7/5/2011 OPERABLE: Injector END 3- 43/P -36 (PTD #1931700) Surface Casing Leak Repaired wi... Page 1 of 2 • Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Tuesday, May 31, 2011 2:08 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS END OIM; AK, OPS END Facility & FieldO &M TL; AK, OPS END Board Operator; AK, OPS END AES Drilisite Lead; AK, OPS END Operations Lead Tech; AK, RES END Production Optimization Engineer; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Yeager, Kevin E Cc: King, Whitney; McLeod, Jennifer D; Wood, Alecia Subject: OPERABLE: Injector END 3- 43/P -36 (PTD #1931700) Surface Casing Leak Repaired with Brinker Platelets All, Injector END 3- 43/P -36 (PTD #1931700) was treated with Brinker Platelets on 05/17/2011 to mitigate the surface casing leak. After the treatment, an MIT -OA to 1200 psi passed with no indication of a leak to atmosphere. The passing test verifies competent surface casing. The well has been reclassified as Operable and may be placed on injection. A placard will be hung from the OA valve stating that the OA pressure must remain above 25 psi to ensure positive pressure is applied to the platelets at all times. Please call with any questions or concerns. Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator 2'° BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWelllntegrityCoordinator @BP.com From: AK, D &C Well Integrity Coordinator Sent: Wednesday, August 04, 2010 11:35 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA); 'Schwartz, Guy (DOA) <guy.schwartz @alaska.gov >'; AK, OPS END OIM; AK, OPS END Facility & FieldO &M TL; AK, OPS END Board Operator; AK, OPS END AES Drillsite Lead; AK, OPS END Operations Lead Tech; AK, RES END Production Optimization Engineer; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Engel, Harry R; McLeod, Jennifer D Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Quy, Tiffany; Vazir, Mehreen Subject: NOT OPERABLE: Injector END 3 -43 (PTD #1931700) Confirmed Surface Casing Leak All, Injector END 3-43 (PTD #1931700) was confirmed to have a surface casing leak during an MITOA on 8/4/2010. The well was converted to a produced water injectior and had passed an AOGCC witnessed MITIA on 8/3/2010. The well is reclassified as Not Operable and should cease injection of produced water and be freeze protected as soon as possible. The well will be added to the Quarterly AOGCC Injector Report. 5/31/2011 OPERABLE: Injector END 3- 43/P -36 (PTD #1931700) Surface Casing Leak Repaired wi... Page 2 of 2 • • Plan forward: 1. DHD: Leak depth determination 2. WIE: Evaluate for surface casing repair options A TIO plot and copy of the well schematic are included for reference. « File: END 3 -43 (PTD #1931700) schematic.pdf» « File: Injector END 3-43 TIO and Injection Plot.doc» Please call if you have questions or concerns. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 5/31/2011 Ai STATE OF ALASKA '' ALASKA ND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Other Ei BRINKER/ Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waived] Time Extension ❑ CASING LEAK/ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ NEW TECHNOLOGY 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑ Exploratory ❑ .� 193 -1700 3. Address: P.O. Box 196612 Stratigraphic❑ Service El 6. API Number: Anchorage, AK 99519 -6612 ! 50- 029 - 22416 -00 -00 8. Property Designation (Lease Number) : d 9. Well Name and Number: ADLO- 047503 v- 3- 43/P -36 10. Field /Pool(s): ENDICOTT FIELD / ENDICOTT OIL POOL 11. Present Well Condition Summary: Total Depth measured 10565 feet Plugs (measured) 10198 TOC feet true vertical 10477.91 feet Junk (measured) 10386 feet Effective Depth measured 10478 feet Packer (measured) 1524 9754 feet true vertical 10391 feet (true vertical) 1517 9668 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 94' 30" 37 - 131 37 - 131 Surface 2700' 10 -3/4" 45.5# NT -80 36 - 2736 36 - 2730 5210 2480 Production 10523' 7 -5/8" 29.7# NT -95HS 35 - 10558 35 - 10471 8180 5120 Production *AIMED Liner JUN 0 9 201 Liner Perforation depth: Measured depth: SEE ATTACHED - _ True Vertical depth: _ - _ _ _ Tubing: (size, grade, measured and true vertical depth) 3 -1/2" 9.3# L -80 33 - 9800 33 - 9714 Packers and SSSV (type, measured and true vertical depth) 3 -1/2" MCX SSSV 1524 1517 3 -1/2" Baker FB -1 Packer eau 9668 RECEIVED 12. Stimulation or cement squeeze summary: idi $; i1 Intervals treated (measured): n Treatment descriptions including volumes used and final pressure: At�)}'!:a Gil & iaA Crifi$, GioilfiliniOn ; ncherge 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: SI Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development ❑ Service 0 , Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ 0 t WAG❑ GINJ p SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 310 -445 Contact Joe Lastufka Printed N- �` Lastu -� w� Title Petrotechnical Data Technologist Signatu - \111M `` Phone 564 -4091 Date 5/26/2011 RBDMS MAY 27 2O . - l/ Form 10 -404 Revised 10/2010 Submit Original Only 3- 43/P -36 193 -170 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 3- 43/P -36 5/25/94 PER 10,108. 10,112. 10,021.38 10,025.38 3- 43/P -36 5/25/94 PER 10,228. 10,245. 10,141.26 10,158.24 3- 43/P -36 5/25/94 PER 10,162. 10,164. 10,075.32 10,077.32 3- 43/P -36 5/25/94 PER 10,287. 10,291. 10,200.2 10,204.19 3- 43/P -36 5/25/94 PER 10,132. 10,140. 10,045.36 10,053.35 3- 43/P -36 5/25/94 PER 10,154. 10,156. 10,067.33 10,069.33 3- 43/P -36 2/3/95 SQZ 10,228. 10,245. 10,141.26 10,158.24 3- 43/P -36 2/3/95 SQZ 10,108. 10,112. 10,021.38 10,025.38 3- 431P -36 2/3/95 SQZ 10,154. 10,156. 10,067.33 10,069.33 3- 43/P -36 2/3/95 SQZ 10,162. 10,164. 10,075.32 10,077.32 3- 43/P -36 2/3/95 SQZ 10,287. 10,291. 10,200.2 10,204.19 3- 43/P -36 2/6/95 RPF 10,132. 10,140. 10,045.36 10,053.35 • 3- 43/P -36 3/1/95 RPF 10,228. 10,245. 10,141.26 10,158.24 3- 43/P -36 4/4/95 RPF 10,108. 10,112. 10,021.38 10,025.38 3- 43/P -36 10/27/95 RPF 10,106. 10,114. 10,019.38 10,027.37 3- 43/P -36 10/27/95 RPF 10,132. 10,140. 10,045.36 10,053.35 3- 43/P -36 10/27/95 RPF 10,228. 10,245. 10,141.26 10,158.24 3- 43/P -36 3/22/99 APF 10,170. 10,190. 10,083.32 10,103.3 3- 43/P -36 3/22/99 APF 10,010. 10,080. 9,923.48 9,993.41 3- 43/P -36 6/2/05 APF 10,287. 10,307. 10,200.2 10,220.17 3- 43/P -36 6/2/05 APF 10,315. 10,335. 10,228.17 10,248.15 3- 43/P -36 2/5/10 SPS 10,220. 10,335. 10,133.26 10,248.15 3- 43/P -36 2/7/10 SPS 10,198. 10,220. 10,111.29 10,133.26 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED i FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • 3- 43/P -36 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY '.0 Jy T4 . . , °.:.t �, Q ➢+br i.ce' d&� -.. .... $�n w.i� `A+2°1* .�', is "e�43-�1 ,,.a .i:.: °S" R?k,'� �� 5/17/2011:T/I/O =? ?/850/30. Temp =SI. Assist Brinker. (SC repair). Pumped diesel & diesel '. based gel as required to assist Brinker treatment for SC repair. OAP left @ 500 psi. Final W HPs =? ?/850/500. SV, WV, =C. SSV, MV =O. IA &OA =OTG. NOVP. Note: No gate on swab platform. } 5/17/2011 :Open permit, pre -job safety mtg, RU, pump diesel to confirm leak rate /hole size, swap to gel, pump platelets; well passed 1200 psi MITOA. Bleed OA press to 500 psi, hang signs on wellhead regarding Brinker job for OA w/ min 250 psi, max 1000 psi allowable range. FLUIDS PUMPED BBLS 6 DIESEL 3 SCHL 415 DIESEL GELLING AGENT 4 SCHL 416 DIESEL GELLING AGENT ACTIVATOR 13 TOTAL TREE: 4- 1/16" / 5000 psi / CIW / AIR "CAC" ACTUATORS) ( SAFETY NOTE WELLHEAD: 13 -5/8" / 5000 psi / CCL / CTC R.T. ELEV = 58.85' \ D �- B.F. ELEV = 14.50' IN D3-4 DEV = 10° 42' @ MD = 8,325' WELL REQUIRES A SSSV. 3 -1/2" HES "XDB" 1 1524' I SSSV nipple (2.75" ID) 10 -3/4 ", 45.5 # /ft, NT -80, Btrs Csg 2740 I , 3 -1/2" 9.3 ppf L -80 EUE 8rd Tubing GAS LIFT MANDRELS (1 -1/2" McMURRAY FHMO) ST MD TVD VLV LATCH FORT DATE 6 3661 3500 DMY RK 0 01/03/10 5 5372 5250 DMY RK 0 4 6619 6500 DMY RK 0 01/03/10 3 7336 7200 DMY RK 0 2 8050 7900 DMY RK 0 1 8747 8600 DMY RK 0 01/03/10 3- 1/2 " 'X' NIPPLE 1 9,745' 2.750" ID BAKER "GBH -22S" LOCATOR & BONDED SEAL ASSEMBLY NOTE: TUBING NOT ANCHORED BAKER "FB -1 PACKER 1 9,754' ,' 4.00" ID SEAL BORE EXTENSION PERFORATION SUMMARY REF LOG: SBL ON 05/02/94 I 9777' H 3-1/T X NNE, ID = 2.75" I ANGLE AT TOP PERF: Vote: Refer to Production DB for historical pert dah SIZE SPF NTERVAL " DATE 1 9793' H3 -1/2" X NP, ID = 2.75" I 2" 4 10010 - 10080 0 2-1/8" 4 10106 - 10114 0 9800' H3-1/2" W LEG, ID = ? ? ?? I 2-1/2" 4 10132 - 10140 0 1 L 9798' ELMD TT LOGGED ON ? ? / ? ? / ?? I 10154 - 10156 S 10162 - 10164 S 10198' 1 — I TOP OF CMT CAP (02 /07/10) I 2" 4 10170 -10190 O �1 • •••1+•4441 10228 - 10245 S 4 4 j 2 -1/2" 4 10228 - 10245 C 10220' H SAND PLUG (02/05110) 10287 - 10291 S 2-1/2" 6 10287 - 10307 C 06/02/05 2 -1/2" 6 10315 - 10335 C 06/02/05 **KEY: 0 = OPEN / C = CLOSED / SQZ= SQUEEZED POST SQZ TD = 10,386' (2/4/95) FISH IN HOLE 7/24/94 ( CENTERLIZED ARM FROM ELM TD = 10,413' PBTD ( 10,478' i' ii ---_ (5/26/94) 7 -5/8 ", 29.7 # /ft, I 10,558' I X X X X NT -95HS, NSCC >• " " DATE REV BY COMMENTS DATE REV BY COMMENTS ENDICOTT UNIT 05/09/94 JJM COIL COMPLETION 03/26/99 DB ADPERF WELL 3 -43 / P -36 05/26/94 SGK NJITIAL PERFS 03/06/05 NBF /TLH ADPERF PERMIT No: 12/19/94 NJS COMPLETION 01/03/10 ?/ JPJC GLV C/O API No: 50- 029 - 22416 -00 02/06/95 HT POST SQZ PERFS 03/18/10 JKD/SV SAND/CMT PLUG (02/07/10) SEC T N R E 10/27/95 DV ADPERF 11 BP Exploration (Alaska) • • SMITE C1[F ALASEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Alecia Wood Petroleum Engineer i BP Exploration (Alaska), Inc. (`� ✓ ` P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Endicott Field, Endicott Oil Pool, 3- 43/P -36 Sundry Number: 310 -445 Dear Ms. Wood: 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. 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 reconsideration. A request for reconsideration 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. Sincerely, ) s ) /&- Daniel T. Seamount, Jr. Chair DATED this 3 day of January, 2011. Encl. STATE OF ALASKA `" / . ALASKA* AND GAS CONSERVATION COMMISSION V � ` APPLICATION FOR SUNDRY APPROVALS ‘.' 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool❑ Repair Well ❑ Change Approved Program ❑ Suspend �``� L. p end ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Sid‘ � i • Time Extension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate❑ Alter Casing ❑ Ot BRINKER JOB • IS 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 193 -1700- 3. Address: P.O. Box 196612 Stratigraphic ❑ Service , 0 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 22416- 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- 43/P -36 " Spacing Exception Required? Yes ❑ No 9. Property Designation (Lease Number): 10. Field / Pool(s): ADLO- 047503 • 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): 10558 . 10471. 10386- 10299 10198 TOC 10386 Casing Length Size MD TVD Burst Collapse Structural Conductor 94' 30" 37 131 37 131 Surface 2703' 10 -3/4" 45.5# NT -80 36 2736 36 2730 5210 2480 Intermediate Production 10523' 7 -5/8" 29.7# NT -95HS 35 10558 35 10471 8180 5120 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 3 -1/2" 9.3# L -80 33 9800 Packers and SSSV Tvpe: 3 -1/2" BAKER FB -1 PKR Packers and SSSV MD and TVD (ft): 9754 9668 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service El - 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 1/10/2011 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ S' GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Joe Lastufka Printed Name Alecia Wood Title PE Signature p h Phone Date Vii x j 564-5492 12/27/2010 Prepared by Joe Lastufka 564 -4091 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: J I 7 0._ U 3 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ RECEIVED Other: DEC 2 8 2010 Alaska Gil & Gas Cons. Commission Subsequent Form Required: /d — 4-/D--t Anchorage APPROVED BY ft 37/ Approved b �?? COMMISSIONER THE COMMISSION Date: / RB s ,s JAN 04 /2- •Z� Form 10-403 Revised 1/2010 Submit in Duplicate 0R1G1NAL /2 %/,4 3- 43/P -36 193 -170 PERF ATTACHMENT Sw Name Operation Date Pert Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 3- 43/P -36 5/25/94 PER 10,108. 10,112. 10,021.38 10,025.38 3- 43/P -36 5/25/94 PER 10,132. 10,140. 10,045.36 10,053.35 3- 43/P -36 5/25/94 PER 10,154. 10,156. 10,067.33 10,069.33 3- 43/P -36 5125/94 PER 10,162. 10,164. 10,075.32 10,077.32 3- 43/P -36 5/25/94 PER 10,228. 10,245. 10,141.26 10,158.24 3- 43/P -36 5125/94 PER 10,287. 10,291. 10,200.2 10,204.19 3- 43/P -36 2/3/95 SQZ 10,228. 10,245. 10,141.26 10,158.24 II 3- 43/P -36 2/3/95 SQZ 10,162. 10,164. 10,075.32 10,077.32 3- 43/P -36 2/3/95 SQZ 10,287. 10,291. 10,200.2 10,204.19 3- 43/P -36 2/3/95 SQZ 10,108. 10,112. 10,021.38 10,025.38 3- 43/P -36 2/3/95 SQZ 10,154. 10,156. 10,067.33 10,069.33 3- 43/P -36 2/6/95 RPF 10,132. 10,140. 10,045.36 10,053.35 3- 43/P -36 3/1/95 RPF 10,228. 10,245. 10,141.26 10,158.24 3- 43/P -36 4/4/95 RPF 10,108. 10,112. 10,021.38 10,025.38 3- 43/P -36 10/27/95 RPF 10,228. 10,245. 10,141.26 10,158.24 3- 43/P -36 10/27/95 RPF 10,132. 10,140. 10,045.36 10,053.35 3- 43/P -36 10/27/95 RPF 10,106. 10,114. 10,019.38 10,027.37 3- 43/P -36 3/22/99 APF 10,010. 10,080. 9,923.48 9,993.41 3- 43/P -36 3/22/99 APF 10,170. 10,190. 10,083.32 10,103.3 3- 43/P -36 6/2/05 APF 10,315. 10,335. 10,228.17 10,248.15 3- 43/P -36 6/2/05 APF 10,287. 10,307. 10,200.2 10,220.17 3- 43/P -36 2/5/10 SPS 10,263. 10,335. 10,176.22 10,248.15 • AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • by END3 -43 Sundry Request Well Type: Water Injector Current Status: This well is currently not operable due to a Surface Casing Leak. Request: Treat well with Brinker to fix the Surface Casing leak. Well History: Well END3 -43 was drilled and completed in 1994 as a producer in Endicott's upper sub - zones. It produced 0.251mm bbls of oil using gas lift for artificial lift before being shut in in 2009 as a poor producer. It was targeted to replace END4 -04, an injector that was SI for annulus communication and side tracked to a different location. In preparation for conversion a sand plug with a cement cap was laid over the FII and lower FIII, leaving the well open to the upper FIII, FIV, and FV for injection. The well was then converted to a water injector July 31 2010. The well injected for six days before failing an MIT -OA and being SI for a Surface casing leak on August 5 2010. Scope of Work: The leak depth is estimated at 6'3" with a leak rate of 1.16gpm at 1200psi, or 1.52gpm at 2000psi. The scope of work will be to pump Brinker platelets down the outer annulus, taking returns to the cellar to be vacuumed out with a super sucker. The Brinker platelets form a seal by deforming the platelet, pushing it partly into the hole in the surface casing. The outer annulus is then pressured up to 2000psi with diesel to fully set the platelets. The outer will then be bled to 200psi to keep the platelets seated, and the well will then be re- evaluated by the well integrity group for re- classification. If the job is successful in plugging the leak and the well passes a mechanical integrity test on the outer annulus it will be re- classified as Operable and put on produced water injection. Production Engineer: Alecia Wood (907) 564 -5492 ATTACHED: Current Well Schematic END3 -35 Sundry Application 1 09/16/2010 / TREE: 4-1/16'15030 pea 1 OW/ (BAKER "CAC' ACTUATORS) I SAFETY NOM: I WELLHEAO: 13 -511' 1500D psi 1 FMC 1 CCL 1 CTC R.T. ELEV = 58.86 I B.F. ELEV 14'.50' 3] MAX OEV = 10' 47 Q IAD = 8,325' G7 3-112' F ES 'XDE" 1 1526 SSSV nipple (2.75'10) 10 -314•, 45.511tI, NT-80, B*i Csg I 214° I 111 4 ` 3-1,7 93 ppf L-90 EIJE 84d Tul ng GAS LF t hV.P4 .S MD' II M L Y MOD) ST AO TVD VLV LATO• PORT DATE I 8 3881 3510 MY R1f 0 01R1310 5 5372 5250 DMY RI< 0 4 8819 8500 MAY PS( 0 01003710 3 7398 7288 DAY R1( 0 2 8050 79110 flfY RK 0 1 0747 8880 Olt? Rx 0 01013710 3-112' )C NIPPLE 8,745' I 2.750' I0 BAKER �8Ff -2 S LOCATOR & KE" BONDED SEAL ASSEMBLY NOTE: HARM NOT ANCHORED BA BAYER1 PAGYER 1 9,7!54' 4.00x' 10 • SEAL BORE EXTENSION ETONSME SMEARY REF LC �ONO302094 9 771' H3.1r2'1CNF, D =2_75' I ANGLE AT ICC PEF_ *Am %ler tQ P►ofitabo DB fm has:mica' part dab Sfe.E SW IHIERVAL '" DATE ingy I I1111 EP, D =2-75^I 7 4 10010.10080 O SNOW 2.1x8' 4 10108 • 10111 O I -13• D ?V? I 2 • t12' 4 10132 • 10140 0 ' I VW HEiAOTT LDG[a'1D EN 77077t?? I 10154. 10158 S 10182 • 10184 S 10994! I— LTOPOFCAfT CAP (02E1711(1) 2' 4 10170.10190 0 • •0 011. •0/4411444 10228 • 10245 S 4.1.4 * • 4 11 2 <1P2 4 102211 • 10245 C 1,.+.0.1* SAADPLIIG 10207 :,, t0291 S 2.111' 8 10287 10307 C 08102 2 • -L2 6 10315 • 10335 C 06702005 " 11th O * OPEICI C *CLOSED 0 10141pINEm POST SOL TD = 10,380 (24195) ASH 14 HOLE 7124194 1 (CENTERI I2rO ARM FROM ELBA TD ' 14,413' FWD 1 10470 " : (5126194) 1- 511', 28.711111, 1 10,558' I gMal NT -95H5, NSCC DATE WV BY COLLE fTS DATE RN BY CONSENTS ENOIOOTT 1J fT 06001x004 JAI COL COY PLLTION 332859 DB ADPBi WELL 3431 P36 88) 94 SOi( SEPAL PEWS 0301805 lFRUM AOPERF PERMIT No: 12119,94 KZ 0314FLEPOP 0110310 "MAC GLV 000 AR 1 4:: 50 429.22415.00 16/2010 132, 08, !IT POST SPOZ FE!S 03118710 J0)SV SA PENCL T PL LIG (020771 SFO T N R E 10127095 DI AOPEPF I 1 BP Expbrailm 4AVahah • MEMORANDUM TO: Jim Regg ~~~ ~~ ~,~~~ P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, August 04, 2010 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 3-43/P36 DUCK IS UNIT SDI 3-43/P36 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Comm Well Name: DUCK IS UNIT SDI 3-43/P36 API Well Number: 50-029-22416-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS100804054621 Permit Number: 193-170-0 Inspection Date: 8/3/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3-43/P36 ~ Type Inj. ~ W TVD 9668 IA 1200 2580 ~ 2510 i 2500 - P.T.D 193»oo',TypeTest SPT Test psi za1~ OA ao IIO loo so Interval ~IT~- p/F' P - Tubing lsso 1920 1930 1900 Notes: packer depth taken from operator, not in RBDMS. Conductor was full of diesel with cement found aprox 12" down. Test results indicate HD crew. likely surface casm~uther testing to be conducted on OA by D 1 ~J E' ~~aL .!~!.,~, , S 1 t Wednesday, August 04, 2010 Page 1 of 1 NOT OPERABLE: Injector END 3-43 (PTD #1931700) Confirmed Surface Casing Leak Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D&C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator@bp.com] Sent: Wednesday, August 04, 2010 11:35 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS END OIM; AK, OPS END Facility & FieldO&M TL; AK, OPS END Board Operator; AK, OPS END AES Drillsite Lead; AK, OPS END Operations Lead Tech; AK, RES END Production Optimization Engineer; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; Engel, Harry R; McLeod, Jennifer D Cc: AK, D&C Well Integrity Coordinator; King, Whitney; Quy, Tiffany; Vazir, Mehreen Subject: NOT OPERABLE: Injector END 3-43 (PTD #1931700) Confirmed Surface Casing Leak Attachments: END 3-43 (PTD #1931700) schematic.pdf; Injector END 3-43 TIO and Injection Plot.doc All, Injector END 3-43 (PTD #1931700) was confirmed to have a surface casing leak during an MITOA on 8/412010. The well was converted to a produced water iniectior and had passed an AOGCC witnessed MITIA on 8/3!2010. The well is reclassified as Not Operable and should cease injection of produced water and be freeze protected as soon as possible. The well will be added to the Quarterly AOGCC Injector Report. Plan forward: ~ ~` t~ , ` ~~ ~J i.. ~ ~ 11 1. DHD: Leak depth determination ~~'~ ~ ~~ 2. WIE: Evaluate for surface casing repair options A T10 plot and copy of the well schematic are included for reference. «END 3-43 (PTD #1931700) schematic.pdf» «Injector END 3-43 TIO and Injection Plot.doc» Please call if you have questions or concerns. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659-5102 Cell (907) 752-0755 Pager (907) 659-5100 Ext. 1154 8/6/2010 Injector END 3-43 TIO Plot WeR 3J3 II 3-000 2.000 i aoo Injector END 3-43 Injection Plot WeIL 3-I3 2,OW 1,900 1 ~0 i inn 100 3~ ?00 100 100 3~ r~ ~~ ~J i~] ,fin 3.200 3000 2~ 2.600 2A00 2,200 2,000 1,800 y ~6~3 1 000 1~ 1000 800 6CO 400 200 ~- ry9 ~ - W ~- OA DOA oooA o~ WHIP 9W - MI GI - OMer On ~~ TREE: 4-1/16" / 5000 psi / CIW WELLHEAD: 13-5/8" / 5000 psi R.T. ELEV = 58.85' B.F. ELEV = 14.50' MAX DEV = 10° 42' @ MD = 8,325' .R "CAC" ACTUATORS) /CCL/CTC I1 0 11 10-3/4", 45.5#/ft, NT-80, Btrs Csg 2740 SAFETY NO 3-1/2" HES "XDB" 1524' SSSV nipple (2.75" ID) 3-1/2" 9.3 ppf L-80 EUE 8rd Tubing Rn C I IGT AAA NIIRPI S (i -U9" M rM I IRRGY FHM Ot ST MD TVD VLV LATCH PORT DATE 6 3661 3500 DMY RK 0 01/03/10 5 5372 5250 DMY RK 0 4 6619 6500 DMY RK 0 01/03/10 3 7336 7200 DMY RK 0 2 8050 7900 DMY RK 0 1 8747 8600 DMY RK 0 01/03/10 NOTE: TUBING NOT ANCHORED PERFORATION SUMMARY REF LOG: SBL ON 05!02/94 ANGLE AT TOP PERF: ote: Refer to Production DB for historical perf dat SIZE SPF INTERVAL *` DATE 2" 4 10010 - 10080 O 2-1/8" 4 10106 - 10114 O 2-1/2" 4 10132- 10140 O 10154 - 10156 S 10162 - 10164 5 2" 4 10170 - 10190 O 10228 - 10245 2-1I2" 4 10228 - 10245 ~, 10287 - 10291 S 2-1 /2" 6 10287 - 10307 u 06!02/05 2-1/2" 6 10315 - 10335 C 06(02/05 '* KEY: O = OPEN t C =CLOSED ISQZ=SQUEEZED PBTD 10,478' 7-5/8", 29.7#/ft, 10,558' NT-95HS, NSCC OSI09/941 JJM )COIL COM 05!26/94 SGK INITIAL PEF DV POST SQZ 3-1/2"'X' NIPPLE 9,745' 2.750" ID BAKER "GBH-22S" LOCATOR & BONDED SEAL ASSEMBLY BAKER "FB-1 PACKER 9,754' 4.00" ID SEAL BORE EXTENSION 1777' 3-112" X NIP, ID = 2.75" 9793' ~ 3-112" X NIP, ID = 2.75" 9800' 3-1/2" WLEG, SD =: ?~?? g7g$' ELMD TT LOGGED ON ?'?%??!'%? 10198' TOP OF CMT CAP (02/07/10) 10220' ~--~ SAND PLUG (02/05!10) POST SQZ TD = 10,386' (2/4/95) FISH IN HOLE 7/24/94 (CENTERLIZED ARM FROM ELM TD = 10,413' (5/26/94) X X X X V BY COMMENTS ENDICOTT UNrf DB ADPERF WELL: 3-43 / P-36 F(TLH ADPERF PERMIT No: JPJC GLV C/O API No: 50-029-22416-00 DlSV SAND/CMT PLUG (02/07!10) SEC T N R E BP Exploration (Alaska) STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISS REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other ~ CONV'T TO Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ WINJ Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ^~ Exploratory ^ ~ 193-1700 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Number: Anchorage, AK 99519-6612 ~~ 50-029-22416-00-00 8. Property Designation (Lease Number) : 9. Well Name and Number ~ ADLO-047503 3-43/P-36 10. Field/Pool(s): ~ ENDICOTT FIELD / ENDICOTT OIL POOL 11. Present Well Condition Summary:- Total Depth measured 10558 feet Plugs (measured) 10198' TOC feet true vertical 10471 feet Junk (measured) 10386' feet Effective Depth measured 10386 feet Packer (measured) 9754 true vertical 10299 feet (true vertical) 9668 Casing Length Size MD TVD Burst Collapse Structural Conductor 94 30" 37 - 131 37 - 131 Surface 2703 10-3l4" 45.5# NT-80 36 - 2739 36 - 2730 5210 2480 Intermediate Production 10523 7-5/8" 29.7# NT-95HS 35 - 10558 35 - 10471 8180 5120 Liner Liner Perforation depth: Measured depth: SEE ATTACHED - _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 3-1/2" 9.3# L-80 33 - 9800 33 - 9714 ~K~ Packers and SSSV (type, measured and true vertical depth) 3-1/2" Baker FB-1 Packer 9754 9668 ,, ~~~ 12. Stimulation or cement squeeze summary: t-- ^ fire Intervals treated (measured): ~..~. ~`~S°:. ~ i_)1-, .- ~) ~ ~ ~'} ~ r+ ~~~sk~ ~ ~ ~~~ e~ i;~lt'gSSion ~ . rifaC.l~~~i~@ 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: Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^ Service Q Daily Report of Well Operations X 16. Well Status after work: Oil \ Gas / WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^~ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 309-314 Contact Gary Preble Printed Name Gary Preb a Title Data Management Engineer Signature -hone 564-4944 Date 8/4/2010 r unn iu--ruv iycvwcu ~icuu~ • ^vV(r1V NUt7 V v LYIY '-~ •,••••'•••• `•••y•"• ••••• / -~ _` O ~~ 3-43/P-36 193-170 PERF ATTArHMFNT • • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 3-43/P-36 5/25/94 PER 10,108. 10,112. 10,021.38 10,025.38 3-43/P-36 5/25/94 PER 10,132. 10,140. 10,045.36 10,053.35 3-43/P-36 5/25/94 PER 10,154. 10,156. 10,067.33 10,069.33 3-43/P-36 5/25/94 PER 10,162. 10,164. 10,075.32 10,077.32 3-43/P-36 5/25/94 PER 10,228. 10,245. 10,141.26 10,158.24 3-43/P-36 5/25/94 PER 10,287. 10,291. 10,200.2 10,204.19 3-43/P-36 2/3/95 SQZ 10,228. 10,245. 10,141.26 10,158.24 3-43/P-36 2/3/95 SQZ 10,162. 10,164. 10,075.32 10,077.32 3-43/P-36 2/3/95 SQZ 10,287. 10,291. 10,200.2 10,204.19 3-43/P-36 2/3/95 SQZ 10,108. 10,112. 10,021.38 10,025.38 3-43/P-36 2/3/95 SQZ 10,154. 10,156. 10,067.33 10,069.33 3-43/P-36 2/6/95 RPF 10,132. 10,140. 10,045.36 10,053.35 3-43/P-36 3/1/95 RPF 10,228. 10,245. 10,141.26 10,158.24 3-43/P-36 4/4/95 RPF 10,108. 10,112. 10,021.38 10,025.38 3-43/P-36 10/27/95 RPF 10,228. 10,245. 10,141.26 10,158.24 3-43/P-36 10/27/95 RPF 10,132. 10,140. 10,045.36 10,053.35 3-43/P-36 10/27/95 RPF 10,106. 10,114. 10,019.38 10,027.37 3-43/P-36 3/22/99 APF 10,010. 10,080. 9,923.48 9,993.41 3-43/P-36 3/22/99 APF 10,170. 10,190. 10,083.32 10,103.3 3-43/P-36 6/2/05 APF 10,315. 10,335. 10,228.17 10,248.15 3-43/P-36 6/2/05 APF 10,287. 10,307. 10,200.2 10,220.17 3-43/P-36 2/5/10 SPS 10,263. 10,335. 10,176.22 10,248.15 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • 3-43/P-36 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTlVITYQATE ' SUMMARY 2/1/2010 CTU #6 1.75" CT Job Scope: LaY in sand plug and cement cap Travel from V- 213. MIRU. MU and RIH w/ 2-1/8" Baker MHA and 2.625" mechanical nipple Iocator.Stop at lower most XNipple at 9770. Correct depth to SLB GR/CCI ;(01/09/10) .End of tool string now at 9795.4'. Paint yellow flag. RIH to tag TD.Tag TD at 10379.5. (10373.3 ctm up Up wt:24,500#) POOH 2/2/2010' CTU #6 1.75" CT (( Job Scope: Lay in sand plug and cement cap for conversion to injector )) POOH with Tubing end locator. LD BOT TEL and check valves, MU ';and RIH w/ 2-1/4" Pig Shear Nozzle. Tie to flag and continue RIH. Tag bttm @ ;10,373' corr. ctm. Lay in 3400 Ibs of sand in 14 bbls of 8 ppg slurry. Expected sand -top 10,248'. RIH to check sand top after 30 mins. Ran in to 10337 w/o tagging. POH due to weather. Secure well. Start weather ticket at 11:00 hrs. Cont. on 2/3/10 2/3/2010CTU #6 1.75" CT Job Scope: Sand Plug w/ CMT Cap. Continue OPS from Phase 3 ;shut down. Crew mobilized to Endicott SDI to assess what needs to be done to ;continue OPS. Test BOPE "*''Job continued on WSR 2/4/10**" 2/4/2010T/O/1=350/2070/10 Assist CTU Pumped 111 bbls 160* DSL through Choke Skid to CTU, while CTU pulled out of hole. CTU in control of well upon departure. PE & Well Tender notified. FWP=934/2220/14 • • 2/4/2010CTU #6 1.75" CT Job Scope: Sand Plug w/CMT Cap. «<Job continued from WSR 2/3/10»> Continue & finish testing BOPE. MU 2.25" Nozzle BHA and RIH to ;flag. Chains slipping. RU LRS to pump hot diesel down coil. POOH and perform ;injector inspection. All parts & pieces checked out 100% ok. MU Nozzle BHA and ;RIH to flag and correct depth. *"*Job continued on WSR 2/5/10*"* 2/5/2010CTU #6 1.75" CT Job Scope: Sand Plug w/CMT Cap. «<Job continued from WSR 2/4/10»> Continue RIH. Stop at flag at 10000' EOP. On depth RIH, paint 'flag at 10200' for CMT run tie in. Tagged sand top at 10260' Mixed 5.56 bbl Sand ;Slurry and laid in from 10250'. First tag yielded 3' of sand 2nd tag another 31' ;Final tag at 10219.7' POOH. MU and RIH with Pig Shear nozzle. Chains slipping =, at 9136' and can't POOH. Call CT Schedular and Well OPS Supervisor and the ';decision is to have LRS heat up diesel to get us OOH then RD CTU #6 and swap to ;CTU #8. Hot Diesel in coil and we are POOH. Well loaded with diesel and flowline FP w/ 60/40 Meth. Pad OP notified of well &flowline status. T/I/0= 281/ 2200/Opsi S/W/M= C/C/O OA open to gauge, IA has 2 leaking Whitey Valves and casing ;valve is shut in. Pad OP notified of leaking valves and will replace. RD CTU #6 and ;take back to shop "*'`Job not complete*** 2/5/2010aT/I/O =1500/2150/0 Assist CTU Pumped 62 bbls hot dsl to warm up coil (rigged up to CTU coil hs control of well) FWHP=900!2250/0 2/6/2010fCTU #6 1.75" CT Job Scope: Sand Plug w/ CMT Cap. «<Job continued from ;WSR 2/5/10»> Continue RD CTU #6 and swap to CTU #8. ***Job continued on WSR 2/7/10*** • • 2/7/2010CTU #8 1.75" (.134 wall) CT Job Scope: Sand Plug w/ CMT Cap. «<Job ;continued from WSR 2/6/10»> Continue RU CTU. Pump 1.25" Drift Ball and test ~BOPE. MU and RIH with Pig Shear Nozzle BHA. Lay in a 1 Bbl 15.8 ppg cement cap from 10220' corr. Estimated top of cement at 10198' corr. RDMO. ***Job Complete**'` 2/10/2010'.""*WELL S/I ON ARRIVAL"** (profile mod) :CURRENTLY RIH W/ 2.50" CENTRALIZER, TEL & 2.50" S-BAILER *"*CONTINUED ON 2/11/10 WSR*** 2/11/2010'`*"WSR CONTINUED FROM 2/10/10*''* (profile mod -post ctd sandback) TAGGED TT @ 9762' SLM (+36' = 9798' ELMD) ;TAGGED TOC @ 10156' SLM (+36' = 10192' ELMD) SET 3 1/2" MCX (SER# BPX-325) @ 1487 SLM (1524' MD) RAN CHECKSET TO 1487' SLM *DID NOT SHEAR* 'RAN 3-1/2" MCX (SERIAL #BPX-325) @ 1487 SLM, (1524' MD) 'i RAN CHECK SET TO 1487' SLM, (1524' MD) CHECK SET SHEARED. ;PERFORM CLOSURE TEST -GOOD *"" TURN WELL OVER TO WELL TENDER, INFORMED OF VALVE POSITIONS *~ 7/29/2010T1O=ssv/1770/0+. SI. IA FL (pre AOGCC). No integral installed. AL SI @ casing ;valve. IA FL @ 110' (4 bbls). 'SV,WV,SSV,MV=C. IA,OA=OTG. NOVP 7/30/2010 T/I/0=2170/1770/0+ Temp=Sl MiT IA 2600 psi PASSED (Convert from PAL to PWI) Bleed IAP down Pumped 5.2 bbls of 60* meth down IA to reach 2600 psi for ;MIT IA 1st test 1st 15 min lost 60 psi 2nd 15 min lost 30 psi for a total of 90 psi in 30 min Bleed IAP down bleed back aprox. 5 bbls wing shut swab shut ssv shut ;master open casing valves open to gauges Final Whp's= 2170/500/0+ ~J T/I/0=1860/1200/40 Temp=Hot MfT IA 2580 psi PASSED (Convert from PAL to PWI) AOGCC state witness by C.Sheve Pumped 3.4 bbls of 65'` meth down IA to ~~ ~ reach 2580 psi for MIT IA 1st test 1st 15 min lost 70 psi 2nd 15 min lost 10 psi fora ti 1 total of 80 psi in 30 min Bleed IAP down Bleed back aprox. 3 bbls Well on injection casing valves open to gauges Final Whp's=1900/1200/40 FLUIDS PUMPED BBLS 136.2 60/40 METH 2.7 15.8 CLASS G CMNT 666 DIESEL 804.9 Total TREE: 4-1/16" / 5000 psi / CI KER "CAC" ACTUATORS) WELLHEAD: 13-5/8" / 5000 psi /FMC / CCL / CTC R.T. ELEV = 58.85' B.F. ELEV = 14.50' ~~ MAX DEV = 10° 42' @ MD = 8,325' I1 0 11 10-3/4", 45.5#/ft, NT-80, Btrs Csg 2740 --~ NOTE: TUBING NOT ANCHORED PERFORATION SUMMARY REF LOG: SBL ON 05!02/94 ANGLE AT TOP PERF: ote: Refer to Production DB for historical pert dat SIZE SPF INTERVAL *` DATE 2" 4 10010 - 10080 O 2-1/8" 4 10106 - 10114 O 2-112" 4 10132 - 10140 O 10154 - 10156 S 10162 - 10164 S 2" 4 10170 - 10190 O 10228 - 10245 S 2-1/2" 4 10228 - 10245 C 10287 - 10291 S 2-1/2" 6 10287 - 10307 C 06/02/05 2-112" 6 10315 - 10335 C 06102!05 ** KEY: O =OPEN / C =CLOSED / SOZ=SQUEiZ® PBTD 10,478' 7-5/8", 29.7#/ft, 10,558' NT-95HS, NSCC DATE REV BY COMMENTS Y5/09/94 JJM COIL COMPLETION HT (POST SAFETY 3-1/2" HES "XDB" 1524' SSSV nipple (2.75" ID) 3-1/2" 9.3 ppf L-80 EUE 8rd Tubing GAS i_1FT MA NnRFI S /1.1 l7" McM11RRAY FHM AI ST MD TVD VLV LATCH PORT DATE 6 3661 3500 DMY RK 0 01(03/10 5 5372 5250 DMY RK 0 4 6619 6500 DMY RK 0 01!03!10 3 7336 7200 DMY RK 0 2 8050 7900 DMY RK 0 1 8747 8600 DMY RK 0 01!03/10 3-1/2"'X' NIPPLE g,745' 2.750" ID BAKER "GBH-22S" LOCATOR 8 BONDED SEAL ASSEMBLY - BAKER "FB-1 PACKER 9,754' 4.00" ID - SEAL BORE EXTENSION 9777' 3-112" X NIP, ID = 2.75" j 9793` ~--) 3-112" X N~, ID = 2.75" 9$00` 3-1/2" WLEG, ID=???? 9798' ELMD TT LOGGED ON ??/??/?? 10198' TOP OF CMT CAP (02/07/10) 10220' SAND PLUG (02/05110) POST SOZ TD = 10,386' (2/4/95) FISH IN HOLE 7/24/94 (CENTERLIZED ARM FROM ELM TD = 10,413' (5/26/94) XXXX V BY COMMENTS ENDIC0T7 UNrT DB ADPERF WELL: 3-43 ! P-36 F1TLH ADPERF PERMrf No: JPJC GLV C/O API No: 50-029-22416-00 :D/SV SAND/CMT PLUG (02/07110) SEC T N R E BP Exploration (Alaska) • • ~' ~~ ~ ~y'~ ~` ~~ ~ ~' ~~ ~ '~' ~`~ r-a k ~ l i ~ ` ~ ~ ~ ~ G ~~, ~ ~, ~ _ ~ ~ ~ ~~ ~ ~ p ~ ~ ~~ ~ ,R. _. ~ :s, ~' r ~ t ~ ~ ` ~'~ ~c~~ G p ~ ~~ ~ F ~ ~ ~ ~ ~ ~ k~ " ~ ~ r ~' ~'~. ~`rv ~ ~, GOVERNOR ~ ° SEAN PARNELL ~ ~~ ~ ~ ~ ~ ~s~ ~~ ~ y ~-~ ~,~~ ,~ ~_~ . . ~ ~_~ ~ ~.~ ~ ~ ~ t~ , ~-7~A ~IL ~~ l]rt~a7 ~ 333 W. 7th AVENUE, SUITE 100 ~ COI~SERQATIOH COAII-IISSIOI~T ANCHORAGE,ALASKA 99501-3539 ,# PHONE (907) 279-1433 # FAX (907) 276-7542 Mr. Jose Soto Petroleum Engineer BP Exploration P.O. Box 196612 ~ ~r.,_ ;,,. ; .. ':3~. .~ o»a:a .. , .,..-.~.~,i ,,~~ ~~~ Anchorage, AK 99519-6612 Re: Endicott Field, Endicott Oil Pool, 3-43 / P-36 Sundry Number: 309-314 Dear Mr. Soto: 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 representa.tive of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~ 1' Cathy . Foerster Commissioner TED this da of Se tember, 2009 DA ~. y P Encl. V q ~c~ ~ ; ,- b 1 ~ ~~~ ~ ~ ~0 ~ G~ a, 'S. x~~ ~ _{ q~~~~.~~~'~Tr" STATE OF ALASKA ~ ' ~ '~ ~{'~'~'9~~9 ALAS~IL AND GAS CONSERVATION COMMI~N APPLICATION FOR SUNDRY APPROVALS ` "~ ~ ~n aac ~s_~~n 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ PerForate ^ Waiver ^ Other ~ Alter casing ~ Repair well ~ Plug Perforations ~ Stimulate ^ Time Extension ~ CONVT TO WI 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. Development ~ Exploratory ~ 193-1700 - 3. Address: P.O. Box 196612 Stratigraphic ~ Service ~ 6. API Number: Anchorage, AK 99519-6612 50-029-22416-00-00 - 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: Spacing Exception Required? Yes ^ No ^ 3-43/P-36 ~ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): - ADLO-047503 - 56 KB - ENDICOTT Field / ENDlCOTT O1L Pool 12• PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 10558 10471 10386 10299 POST SQZ TD @ 10386' NONE Casing Length Size MD ND Burst Collapse Structural Conductor 94 30" 37 131 37 131 Surface 2703 10-3/4" 45.5# NT-80 36 2739 36 2730 5210 2480 Intermediate Production 10523 7-5/8" 29.7# NT-95HS 35 10558 35 10471 8180 5120 Liner Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): see attached - - 3-1/2" 9.3# L-80 33 - 9800 Packers and SSSV Type: 3-1/2" Baker FB-1 PKR Packers and SSSV MD (ft): 9754' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ~ BOP Sketch ~ Exploratory ~ Development ~ Service ^~ ~ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: 9/10/2009 Oil ~ Gas ^ Plugged ^ Abandoned ~ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ~~ WDSPL [] Commission Representative: Prepared by Gary Preble 564-4944 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jose Soto Printed Name ~ se Soto Title Petroleum Engineer Signature Phone Date 564-4972 9/4/2009 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: /~~~ ~~3/ Plug Integrity ~ BOP Test ~ Mechanical Integrity Test [~ Location Clearance ^ Other: ~ /~ A' ,/ Tvi~ t_c i~:~ Gt.-~~/`t~~1LGC t''~. ~:_CCx~ ~^~ 4.J,~ `~ ~~ Q Itfo. ! Subsequent Form Required: ~'"` ; ~., a} . ~~ ' ~' ~`~ __ ~~~~ ~~ ~ ~~ ~ APPROVED BY Approved by: MISSIONER THE COMMISSION Date: ~~~ -r -- - - -- --~-- ~ ~,1 ~ ~ ~ -- r c',/ 3-43/P-36 193-170 PERF OTTACHMENT • • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 3-43/P-36 5/25/94 PER 10,108. 10,112. 10,021.38 10,025.38 3-43/P-36 5/25/94 PER 10,132. 10,140. 10,045.36 10,053.35 3-43/P-36 5/25/94 PER 10,154. 10,156. 10,067.33 10,069.33 3-43/P-36 5/25/94 PER 10,162. 10,164. 10,075.32 10,077.32 3-43/P-36 5/25/94 PER 10,228. 10,245. 10,141.26 10,158.24 3-43/P-36 5/25/94 PER 10,287. 10,291. 10,200.2 10,204.19 3-43/P-36 2/3/95 SQZ 10,228. 10,245. 10,141.26 10,158.24 3-43/P-36 2/3/95 SQZ 10,162. 10,164. 10,075.32 10,077.32 3-43/P-36 2/3/95 SQZ 10,287. 10,291. 10,200.2 10,204.19 3-43/P-36 2/3/95 SQZ 9 0,7 08. 9 0,112. 10,021.38 10,025.38 3-43/P-36 2/3/95 SQZ 10,154. 10,156. 10,067.33 10,069.33 3-43/P-36 2/6/95 RPF 10,132. 10,140. 10,045.36 10,053.35 3-43/P-36 3/1/95 RPF 10,228. 10,245. 10,141.26 10,158.24 3-43/P-36 4/4/95 RPF 10,108. 10,112. 10,021.38 10,025.38 3-43/P-36 10/27/95 RPF 10,228. 10,245. 10,141.26 10,158.24 3-43/P-36 10/27/95 RPF 10,106. 10,114. 10,019.38 10,027.37 3-43/P-36 10/27/95 RPF 10,132. 10,140. 10,045.36 10,053.35 3-43/P-36 3/22/99 APF 10,010. 10,080. 9,923.48 9,993.41 3-43/P-36 3/22/99 APF 10,170. 10,190. 10,083.32 10,103.3 3-43/P-36 6/2/05 APF 10,287. 10,307. 10,200.2 10,220.17 3-43/P-36 6/2/05 APF 10,315. 10,335. 10,228.17 10,248.15 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MlR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • ~ Area of Review - Endicott DIU :~-4~/P-~6 (19:~1700) Prior to the conversion of well 3-43/P-36 from producer to water injector an Area of Review (AOR) is required. This AOR will discuss the wells within i/a mile of the well's entry point into the Kekiktuk Formation to the bottom of well bore completion. Only one well bore enters the AOR of 3-43 at the top of the Kekiktuk to bottom of wellbore completion. The following table shows the well within the AOR, its distance from 3-43, completions detail, and any annulus integrity comments based on an in-depth review. Well Name PTD Distance, Ft. Annulus Inte ri 3-43/P-36 i93i~oo TOC calculated to be above in'ection zone at 8,963' MD 3-47 Q-35 i86o640 1i44 TOC calculated to be above in'ection zone to to of liner Figure 1: Wells within AOR Well Name Casing Size Hole Size Vol Cement Kekiktuk De th 3-43 P-36 ~ 5 8" '7 8" 6i bbls 10,006' MD 3-47 Q-35 7~~ 81 2" 97 bbls io,i4 ' MD Figure 2: Completion Detail We113-47/Q-35 ~PTD i86o640) was completed as an upper sub zone producer in 1986 and converted to water injection in March 95. The completion crossed the Kekiktuk formation at io,i43 ' MD. A ~" liner was run to 11,4io' MD, hung off at 9,68'7' and cemented with 97 bbls of ~5.5 ppg class G cement. In Sep-93 a CT cement squeeze over all intervals passed a pressure test. The upper most interval squeezed io,144'-io,1~~' remains cemented. Well 3-47 complies with AOGCC regulations for water injection including demonstrated tubing/casing/packer integrity per passed MIT IA to 4,00o psi in 5-May-o~. • • FV Structure Map illustrating the AOR _ ,-~ , . ~„~,~. ~ • '~ ~y ~ ,1-3$p35 7~~ 7 .: .. `~ ~ ~' ~ ~ '.~'I~Sn~PBt'~NK~7 ' 9-07A.128 3tSN-33 ~ \ ~ , }11Aa30~; .. • . ~'V 309A133 ~ . ' ~ ' ~ " ~ ~ 3-3IM32 ~' 15TR-27 4~- ~ K . p,Ug,p.7/ ~K2B ' : ~: ~'l'280' . ,-' 10iR~179 0.a-Yl ~ . .._.-.. . t a,',~P.26 : 'tV~ ~~~ 3-29AI-~32 , :5k1[Oi~13t ' °" ~~' ~~ ~ - ~ t 3-OS 39 1 M _ ! . ;~ 1~pp~~~ t.1iQ-]6 ~ 3-3L+. _~ . _ J : ~ ~°VfJ.. . ' ~.~~ . ~I . ~377BilF37 }27M3.7~~;. - ~ ~' ~ 1311131 ~ __'~ISlQ'7~.. - __~~ . ~1 A. ~ - /.. -~„" ' - -Y' _ _}L4~R-30.. . . ;3.2YK71 ,' 33~.1.35 _` _ .. . • •'l-20MJ5 . . . ~'~.~ . ~+-~6~AJ0 ~~ -~ ' ;~ : ,~"~ . . ~ a-D/R-76 T ~, ,~' ' 136~b3t.. ~'~t' ; "3-35~L- ~ DIOt . • ~ ~ - ~ ~. . "'~ ~~.1 •. 4T~ ' ' . . 41&5-30 :R ~"L; ~,' ~ ~~ ~. ~ - 4~7 - , . ~/~' _ - _ . - - - ~.q' _' - - .~ _.,_.`i. ~~ - --- ~ ~ ~` 3-aat.s6 ~-_ i S . -10375 ~ ~ ~,a~-, S ~ __ ~. = S • .g~~ ~ ~N~o. ~ .;:~ a ~ - ~ __ - • - N ' ~.. h~ u -` '\ : . `' ..~„ ~ :.,.,~_~ toRZS ~ ~ ' . - . . ~d , _ - '~.A .~cl~~d~ ..,;,~~ ~ _ . . _ ~ ' ~ ~. ~ FV Structure Grid (2005) ~ Depth -tt754 -t0740 -tpg3p -gglp -ggp5 2000 0 2000 4000 6000 f[ ~ FI Tops 1:27529 ~ FV Tops • • Endicott DIU ~-4„~/P-~6 (1~700) Current Status End 3-43/P-36 is an active gas lifted oil producer. Last caliper performed in lo- Nov-o4 showed tubing was in excellent conditions with no recorded penetrations above 8 % . The reservoir management plan forward is to convert END3-43 to a water injector in zones Fv, Fiv and upper Fiii to support upper subzone wells in southern portion of the SDI fault block. It will also be given consideration for MI injection in the future. A sand plug with cement cap to io,21o' will be placed in the production liner before startin~ inJe~ti4~ to iso~afe f~ie i~ o~wer Fiii sa ds_ 3-43 ~11 be in compliance with BP internal well integrity policy for operation. Completion 3-43/P-36 (PTD 193i~oo) completion crossed the Kekiktuk formation at io,oo6' MD. The production packer is located 252' above the top of the Kekiktuk. ~ 5/a" casing was run from surface to io,558' MD. The casing was cemented with 61 bbls of ~lass G cement with no recorded losses. ~~ A Segmented Bond Log run in 2-May-94 indicates a minimum of 32' of continuous cement behind the ~ 5/s" casing above the top Kekiktuk in interval 9~972'-10,006' plus 32' of fairly good cement in interval 9,940~-9~972~• The log shows good cement across all the Kekiktuk formation and also shows good cement behind the production liner in the shale interval identified to serve as isolation from Fii and lower Fiii (io,i9o' to 10,228') via sand plug with cement cap. A cement squeeze in 2-Feb-95 successfully isolated all intervals perforated from Fv to Fii by placing o.5 to i bbl of cement behind pipe and adding on completion's Kekiktuk confinement capabilities. Plan Forward• i) Obtain Sundry for conversion to water injection 2) Place sand plug and cement cap with top at 1o,2io' MD. 3) Place well on water injection (confirm AOGCC approval prior to injection) 4) AOGCC witnessed MITIA once injection has stabilized ~ ~ 2 ~'C~ICAL i.NTEGRITY R~'PORT ~ nnnuiua Pxess Test: :..'~ j 35 mi ~,_,_,; :.0 m3.n"~„~. C omaaer~ t s : ` -~~ • ~ ~ss ~ -~-~ ~ ~,~ ~ .,...~'.~L~td.S~'~-i° .r ~ :. ~ : gUD vt."'_'. : z'I,- l~~ `~ `( OPER ~ FIEI.D ~i~.!t> `3 -~3 / P--3G~ . . ~ . ~ iir~~ rr~~~ = ; G ,? tL~~ ~ ~ : • .S~' 2~ `~ ~l ~.~i?.I. NtJI~ER ~~-~' ~ ~-r~ ~ ~LL ~~.TA TD : I d ~ ~ ~.. I d `f7~ TvD. ; : BTD : W~ ~,_„_? VD ~ ~ Casir.g lo~~`f ~r~ 5hoe : ~? 31 t~ID TVD ~ I3v : ~ -~ID , ~ •'T'~Z~ ~ - ~ ~ ~~ ~`~ ,,,;~~- , ~ ~~~ S h o e : 0~_,1'~ _ ?VG ; ':'CP : ~ r ~ '~'•.~i ~~~ ~ =uo=.^.g: ~~~`` Packar ~~J~( 1~ TVD; ~et ~t ~~._~~~. ~J ~~7 Z~ ` ~.._ ___r___..._ ____,......~ :ale Si~e /a'~~'f. ~~ and ; Perfs Io~,o~D' ~o t~ ~ ~~' . ~ ~~ ',~ ~„P.N i C~.L iNTEGRTTY - P 9RT # 1 ` 'tEC'HANIC?3~ YNTEGRII'F - PART # 2 ' '7 ~ k ~~~ ~ . Cemenz Volvmes :~mt, i..iuer ~ Gag ~~~~~ DV - ~:~...--. • _ CT~L ~O1 t0 C~vB_ DC~~.S ~(I~ • , 3l~ w ti ft ~ ~ ~i . ~ . c~ ~~ ~_~B/~1~'~. n~~~Y1~~1 -I r~ ~ Clcl c~/o °- /~SSc;') ~~~~r "\ ~ ~~./~.OS ~/ _ ~ w ~~t. ~ / P_r° ''~ _ '~'beoretical TOC ~~ ~ ~ ~ ~ D ° s~-;._ ~.: ~ ~- `~ ~o~ `~-, ~. ~~"~'~" C~*~...Q ~-d • . ' . Ctment Bond Lcg (Ye or No) ~/~~~ ; Ia AOGCC File ~~' C~L ~.valuaticn, :.ane ~oave perfs ~~ru.~C~ ~•~ ~ r ~9c~~ //~ #y~- +?~ ~-~ /' ~t~ ~"f'a [)~ ~ , ~ d .~y ~~yj, q ~,`~ C~ .r ~'~~,- ' • *~'~ ~ ' ~ ~G~i`s l' ~~96sv-sa.,e'~`- ~l+e` l ~ ~'! l ~, J ~' ~ ' ~ ~ B ~ ~ ~~~~ ~ ~'~oduatfon Log: T_ppe t Evaluation ~ ~ CONCLU5 iONS : ?`art #1: . ~~ ~ar~ - . ~ , ~ ~g .. _ ~~ r~%.~ ~?3-~70 r~.r~ # 2 : T ~ L u- ~ ~-~ -= ~=°----~ _~: - ':.~/;~ v~~~ s ~~ ~'l l T - 1. Operations Performed: Abandon D Alter CasingD Change Approved Program D KECEIVEr ) STATE OF ALASKA ) JUL 1 G 2 ALASKA OIL AND GAS CONSERVATION COMMISSION 4la,i(a J,¡¿¡ .. ··,·005 REPORT OF SUNDRY WELL OPERATION~~~:~~:COlI!Iri¡o", OtherD RepairWellD Pull TubingD Operation Shutdown 0 PluQ Perforations 0 Perforate New Pool D Perforate ŒJ Stimulate D WaiverD Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: 193-1700 6. API Number 50-029-22416-00-00 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. 4. Current Well Class: Development [!] ExploratoryD P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 56.00 8. Property Designation: ADL-047503 11. Present Well Condition Summary: Stratigraphic D 9. Well Name and Number: 3-43/P-36 10. Field/Pool(s): Endicott Field I Endicott Oil Pool ServiceD Total Depth measured 10558 feet true vertical 10470.9 feet Effective Depth measured 10386 feet true vertical 10299.1 feet Plugs (measured) Post Sqz TD @ 10386 (02l04/1995) Junk (measured) None Casing Length Size MD TVD Bu rst Collapse CONDUCTOR 94 30" Conductor 37 131 37.0 131.0 SURFACE 2703 10-314" 45.5# NT-80 36 - 2739 36.0 - 2729.6 5210 2480 PRODUCTION 10523 7-5/8" 29.7# NT-95HS 35 - 10558 35.0 - 10470.9 8180 5120 Perforation depth: Measured depth: 10010 -10080,10106 -10114,10132 -10140,10170 -10190,10228 -10245,10287 -10307,10315 -10335 True vertical depth: 9923 - 9993,10019 - 10027, 10045 - 10053, 10083 - 10103, 10141 -10158,10200 -10220,10228 -10248 S<J~NEC .1\ n 2 () 2005 3-112" 9.3# L-80 @ 33 TubinQ ( size, wade, and measured depth): Packers & SSSV (type & measured depth): 3-1/2" Baker FB-1 Packer 3-1/2" HES XDB SSV Nipple @ 9754 @ 1524 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Prior to well operation: Subsequent to operation: Oil-Bbl SHUT-IN 13 Representative Dailv Averaqe Production or Injection Data Gas-Mef Water-Bbl Casing Pressure Tubing Pressure 35 4408 680 14. Attachments: Copies of Logs and Surveys run _ Daily Report of Well Operations _ ! 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilŒJ GasD DevelopmentŒ] Service D Signature DeWayne R. Schnorr DeWayne R. Schnorr A?J,r~~Ä~ WAG D GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. Sundry Number or N/A if C.O. Exempt: NIA 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Title Petroleum Engineer Phone 564-5174 Date 7/13/05 OR' ¡r, . r , '/' RBDMS BFl JUL 1 9 2005 Form 10-404 Revised 4/2004 ) ) 3-43/P-36 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 06/02/05 PERFORATED 102871-103071 AND 103151.103351 WITH 2.5" HSD 6SPF 60DEG PHASED PJ2506 GUNS. USED GAMMA RAY TO CORRELATE TO ATLAS DUAL INDUCTION OPEN HOLE LOG FLUIDS PUMPED 88LS o NO FLUIDS PUMPED o TOTAL Page 1 TREE: 4-1/16"/5000 pSi , .,,~.W / (BAKER "CAC" ACTUATORS) WELLHEAD: 13-5/8" / 51. þsi / FMC / CCL / CTC ~D3-l.3 R.T. ELEV B.F. ELEV MAX DEV @MD 58.85' 14.50' 10° 42' 8,325' I 2740 10-3/4", 45.5#/ft, NT -80, Btrs Csg >  NOTE: TUBING NOT ANCHORED ~ PERFORA TION SUMMARY REF LOG: SBL ON 05/02/94 ANGLE AT TOP PERF: \lote: Refer to Production DB for historieal perf dató. SIZE SPF INTERVAL DATE 2" 4 10010 - 10080 0 2-1/8" 4 10106 - 10114 0 10154 - 10156 SOl 10162 - 10164 SQZ 10228 - 10245 SQZ 10287 - 10291 SOl 10132 - 10140 0 10170 - 10190 0 10228 - 10245 0 10287 - 10307 0 06/02/05 10315 - 10335 0 06/02/05 2-1/2" 4 2" 4 2-1/2" 4 2-1/2" 6 2-1/2" 6 ** KEY: 0 = OPEN I C = CLOSED / SQZ=SQUEEZED PBTD 7-5/8", 29.7#/ft, NT-95HS, NSCC -~ o ~ ~ æ- )OTES: 3-1/2" HES "XOB" 11524' I SSSV nipple (2.75" 10) 3-1/2" 9.3 ppf L-80 EUE 8rd Tubing GAS LIFT MANDRELS (1-1/2'" McMURRAY FHMO) ST MD TVD VLV LATCI- PORT DATE 6 3661 3500 RK 5 5372 5250 RK 4 6619 6500 RK 3 7336 7200 RK 2 8050 7900 RK 1 8747 8600 RK L 19,745' 3-1/2" 'X' NIPPLE ~ 2.750" ID r ______ BAKER "GBH-22S" LOCATOR ~ & BONDED SEAL ASSEMBLY ~.. BAKER "FB-1 PACKER 1 9,754,1 4.00" ID ~- SEAL BORE EXTENSION "I fIIIIII > ~/////X xxx x > 'J 'J 'J 10,478' 10,558' DA TE REV BY COMMENTS 05/09/94 JJM COIL COM PLETION OS/26/94 SGK INITIAL PERFS 12/19/94 NJS COMA..ETION 02/06/95 HT POST SOl PERFS 10/27/95 DV ADÆRF DA TE REV BY COMMENTS 03/26/99 DB ADPERF 03/06/05 NBFfTLH ADPERF 3-1/2" 'X' NiPPLE 2.750" ID 3-1/2" 'X' NIPPLE 2.750" ID WLEG 9,777'1 9,793' I I 9,800'1 ELMD I 9,798' I POST SQZ TD = 10,386' (2/4/95) FISH IN HOLE 7/24/94 (CENTERLlZED ARM FROM ELM TD = 10,413' (5/26/94 ) ENDICOTT UNIT WELL: 3-43 / P-36 PERMIT No: API No: 50-029-22416-00 SEC T N R E BP Exploration (Alaska) THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE JANUARY 03, 2001, PL M ATE E W IA L U N D ER T H IS M ARK ER C'.I.,O~.DOC STATE OF ALASKA ALAS'¢-~')IL AND GAS CONSERVATION COMMISS ..... REPORT O.-' SUNDRY WELL OPE,- ATIONS 1. Operations performed: Operation shutdown __ Pull tubing.__ Stimulate__ Plugging__ Perforate X Alter casing __ Repair well __ Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchora_cle, Alaska 99519-6612 4. Location of well at surface 2777' SNL, 640' WEL, Sec. 8, TIIN, R17E At top of productive interval 3677' NSL, 67' EWL, Sec. 9, TIIN, R17E At effective depth 3721' NSL, 63' EWL, Sec. 9, TIIN, R17E At total depth 3725' NSL, 65' EWL, Sec. 9, TIIN, R17E 5. Type of Well: Development .. Exploratory __ Stratigraphic __ Service __ 6. Datum elevation (DR or KB) KBE = 56' feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 3-43/P-36 9. Permit number/approval number 93-170~Not req. uired 10. APl number 50- 029-22416 11. Field/Pool Endicott Fie/d/Endicott Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 10565 feet 10422 BKB feet 10478 feet 10335 BKB feet Plugs (measured) Junk (measured) Centralized arm from FBS on bottom Length Size Cemented Measured depth True vertical depth BKB BKB 92' 30" Driven 131' 75' 2700 10 3/4 460 sx PF "E'Y375 sx G 2739' 2674' 10519' 7 5/8" 300 sx Class "G" 10558' 10415' measured 10010'-10080' (Open);10154;10156', 10162'-10164', 10287'-10291' (Afl squeezed) 10106;10114'; 10132'-10140' ;10228'-10245'; 10170'-10190' (Afl Open) true vertical (subsea) 10011'-10013', 10019'-10021', 10144'-10148' (All squeezed) 9876'-9937'; 9966'-9970'; 10027'- 1004 7'; 10085'- 10102'(Ail Open) Tubing (size, grade, and measured depth) 3 1/2" L-80 tubing to 9804' MD Packers and SSSV (type and measured depth) 7-5/8" Baker 'FB-I' packer @ 9754' MD; 3-12" 'XDB' SVLN @ 1524' 13. Stimulation or cement squeeze summary Add perforations 3/22/99 Intervals treated (measured) 10010'-10080'; 10170'-10190' perforated Treatment description including volumes used and final pressure ORIGINAL 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 73 795 354 0 5 8 10064 0 Tubing Pressure 349 1453 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations X Oil X Gas__ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed t"'~'~..~ ~-~'~'~~ Title~.ni~rT.~hnin. lA~i_~t~nt,V Form 10-404 Rev 0(~15/88 Service Date 4-11-98 SUBMIT IN DUPLICATE ,~( · BPX Endicott Production Engineering Department DATE: 3/22/99 WELL N°: 3-43/P-36 BP EXPLORATION REP: SERVICE COMPANY: Additional Perforations D. Barba SWS (P. AIIdredge & K. Nelson) DATE/TIME OPERATIONS SUMMARY I 0745 MIRU SWS. SIWHP = 1200 psig, lAP = 1770 psig, OAP = 0 psig. 0820 0830 0915 1 OO5 1025 1035 1130 1200 1245 1250 1300 1400 1430 1510 1250 1550 1630 1730 Hold Safety Meeting Request radio silence on SDI. Pressure test lubricator to wellhead pressure. RIH with Gun #1 (20') 2" @ 4 SPF, 60 DEG PHASING AND RANDOM ORIENTATION. CCL TO TOP SHOT 5.5'. MAKE TIE-IN PASS. MAKE +12 ' CORRECTION. Tied into DIFL dated 28-Apr-94. PARK CCL AT 10164.5' AND SHOOT (TS 10170' BS 10190'). GOOD INDICATION. POOH OOH. Confirm all shots fired. Pressure test lubricator to wellhead pressure. RIH with Gun #2 (20') 2" @ 4 SPF, 60 DEG PHASING AND RANDOM ORIENTATION. CCL TO TOP SHOT 5.5'. MAKE TIE-IN PASS. MAKE +11' CORRECTION.. Tied into DIFL dated 28-Apr-94. PARK CCL AT 10054.5' AND SHOOT (TS 10060' BS 10080'). GOOD INDICATION. POOH. OOH. Confirm all shots fired. Pressure test lubricator to wellhead pressure. RIH with Gun #3 (20') 2" @ 4 SPF, 60 DEG PHASING AND RANDOM ORIENTATION. CCL TO TOP SHOT 5.5'. MAKE TIE-IN PASS. MAKE +14' CORRECTION.. Tied into DIFL dated 28-Apr-94 PARK CCL AT 10034.5' AND SHOOT (TS 10040' BS 10060'). GOOD INDICATION. POOH. OOH. Confirm all shots fired. Release radio silence. RDMO. (continue tomorrow) 3-23,24,25 Waiting on weather 3-26 O9OO 1000 1010 1105 1215 1245 1255 1335 MIRU SWS. SIWHP = 1700 psig, lAP = 2250 psig, OAP = 0 pslg. Hold Safety Meeting Request radio silence on SDI. Pressure test lubricator to wellhead pressure. RIH with Gun #4 (20') 2" @ 4 SPF, 60 DEG PHASING AND RANDOM ORIENTATION. CCL TO TOP SHOT 5.5'. MAKE TIE-IN PASS. MAKE -12 ' CORRECTION. Tied into DIFL dated 28-Apr-94. PARK CCL AT 10014.5' AND SHOOT (TS 10020' BS 10040'). GOOD INDICATION. POOH OOH. Confirm all shots fired. DATE: 3/22/99 WELL N°: 3-43/P-36 TYPE OF oPERATION: OPERATIONS REPORT CONTINUED Additional Perforations 1445 1545 1600 1610 1700 1830 Pressure test lubricator to wellhead pressure. RIH with Gun #5 (10') 2" @ 4 SPF, 60 DEG PHASING AND RANDOM ORIENTATION. CCL TO TOP SHOT 15.5'. MAKE TIE-IN PASS. MAKE -16' CORRECTION.. Tied into DIFL dated 28-Apr-94. PARK CCL AT 9994.5' AND SHOOT (TS 10010' BS 10020'). GOOD INDICATION. POOH. OOH. Confirm all shots fired. Release radio silence. RDMO SWS. PERFORATION SUMMARY: GUN INTERVAL(DIL) FEET SUBZONE 1 10170-10190 20 F3 2 10060-10080 20 F5 3 10040-10060 20 F5 4 10020-10040 20 F5 5 10010-10020 10 F5 All intervals were shot using 2" guns at 4 spf, 60 degree phasing and random orientation. Page LAVERY GRANT ' Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 21 November 1995 Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: ECC No. Run ~ 1 2628.11 Run # 1 5756.07 , Run ~ 1 6192.10 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street ~ Or~_AX to STATE OF ALASKA AI_A,_ ~ 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 2777' SNL, 640' WEL, Sec. 8, TIIN, R17E At top of productive interval 3677' NSL, 67' EWL, Sec. 9, TIIN, R17E At effective depth 3721' NSL, 63' EWL, Sec. 9, TIIN, R17E At total depth 3725'NSL, 65'EWL, Sec. 9, TIIN, R17E 5. Type of Well: Development Exploratory Stratigraphic Service ORIgiNAL 6. Datum elevation (DF or KB) KBE = 56' feet 7. Unit or Properly name Duck Island Unit/Endicott 8. Well number 3-43/P-36 9. Permit number/approval number 93-170/Not required 10. APl number 50- 029-22416 11. Field/Pool Endicott Field/Endicott Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 10565 feet 10422 BKB feet 10478 feet 10335 BKB feet Plugs (measured) Junk (measured) Centralized arm from FBS on bottom Casing Length Structural Conductor 92' Surface 2700 Intermediate Production Liner 10519' Perforation depth: Size Cemented 30" Driven 10 3/4 460 sx PF "E"/375 sx G Measured depth True vertical depth BKB BKB 131' 75' 2739' 2674' 7 5/8" 300 sx Class "G" 10558' measured 10154'-10156', 10162'-10164', 10287'-10291'(AII squeezed) 10106'-10114'(Open), 10132;10140' (Open), 10228'-10245'(Open) true vertical (subsea) 10011'-10013', 10019'-10021', 10144;10148' (All squeezed) 9963'-9971'(Open), 9989;9997' (Open), 10085;10102' (Open) 10415' Tubing (size, grade, and measured depth) 3 1/2" L-80 tubing to 9804' MD Packers and SSSV (type and measured depth) 7-5/8"Baker 'FB-l'packer @ 9754'MD; 3-12" 'XDB' SVLN @ 1524' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 385 27O8 26 0 248 2299 34 0 322 320 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~.-~~- -'-'-~'' ~~"~~ Title Senior Technical Assistant I! Form 10~)-4' Rev 06/15/88 Date ////~ //~/~.__..r SUBMIT IN DU/PLI~/~TE Endicott Production Engineering Department DATE: 10/27/95 WELL N-°: 3-43/P-36 BP EXPLORATION REP: SERVICE COMPANY: RE-PERFORATE VARBLE ATLAS (ESARY) CURRENT WELL DATA (WELL HEAD) WHFP WHFT lAP OAP CHOKE (PSIG) (DEe F) (PSIG) (PSIG) (BEANS) 375 138 1380 0 176 DATE/TIME OPERATIONS SUMMARY 1115 MIRU ATLAS 123O ARM GUNS 1250 RIH WITH SINKER BAR/ PFC/ GUN #1 17'2.5 HSC, 4SPF, 180 DEG. PHASING, 90 'DEG. ORIENTATION (GR 5.5' FROM TOP SHOT) 1318 OUTTT - POPTO40 BEANS W/LIFT GASTO UNDER BALANCE.(SIWHP = 1100 PSI) TIE INTO SBT DATED 5/2/94 TAKE OUT 8' 1330 LOG CONFIRMATION PASS ON DEPTH LOG INTO POSITION GR @ 10222.5' MD TOP SHOT @ 102228' MD (FWHP = 600) 1350 SHOOT GUN#1 GOOD CAP BREAK & 30 # WEIGHT CHANGE LOG OFF FLOW WELL FOR 10 MIN. 1400 SHUT-IN WELL & POOH 1435 OOH ALL SHOTS FIRED ARMGUN#2&3 (16' SELECT FIRE) 1536 RIH (SIWHP= 1250) 1558 OUT TT POP TO 40 BEANS W/LIFT GAS TO UNDER BALANCE 1605 LOG TIE IN PASS TAKE OUT 2' LOG INTO PLACE (FWHP = 780 PSI) 1625 SHOOT GUN # 2 (BTM GUN ) GOOD CAP BREAK NO WEIGHT CHANGE 1634 LOG INTO PLACE & SHOOT GUN # 3 (TOP GUN) GOOD CAP BREAK NO WEIGHT CHANGE LOG OFF FLOWWELL FOR 10 MIN. 1636 SHUT IN WELL & POOH 1710 OOH ALL SHOTS FIRED 1830 RDMO ATLAS PERFORATION SUMMARY GUN SBT DEPTH FEET SUBZONE ~1 10228'-10245' MD 17' 3C1 #2 10132'-10140' MD 8' 3C2 #3 10106'-10114' MD 8' 3C3 THE INTERVALS WERE SHOT USING 2-1/2 ALPHA JET HSC, 10.5 GRAM CHARGES, 4 SPF, 180 DEG. PHASING, 90 DEG. ORIENTATION LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 1 November 1995 Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION 2-18/L-16 ~0'~ i PLS FINAL BL+RF 1 PLS FINAL BL+RF Run: #' 1 Run ~ 1 Run ~ 1 Run ~ 1 ECC No. ' 4297.10 .... _ 6001.15 6192.09 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Received by: ~..~ Date: R · ,- · ~aska Oit & Gas Cons. Commis$[o: Anchorage P E RN I'P DATA AOGCC individual Well ~ c~eoiogicai Haterials invent!}ry T DATA_PLUS .age ~ ~ate· !o/1~ RUN DATE 93-170 o~1i6 93-170 ~ 93-170 yL/GR/SP T 9600~10560, OH-DiFL/ZDL L 9900~i0533 I L 9600-10560 i 05/18/94 05/~V/94 0 ~ ~,/17/94 L 9000-10410 I L 9600-10560 1 02/17/95 03/07/q5 01/23/95 05/17/94 05/17/94 05/17/94 L 9900 1053~ Are dry ditch samples required? yes~l~~-rec~ yes was the weal cored? yes '.,~aiysis & desczipczon__~-e~um~., Are well tests requi-red?~es ~ived?~---ye~ne Well is in compliance I'aitial COMMENTS !to ii C, STATE OF ALASKA ALA~,A OIL AND GAS CONSERVATION COMMISS,_.. 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. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2777' SNL, 640' WEL, Sec. 8, 7lIN, R17E At top of productive interval 3677' NSL, 67' EWL, Sec. 9, TIlN, R17E At effective depth 3721' NSL, 63' EWL, Sec. 9, 7lIN, R17E At total depth 3725' NSL, 65' EWL, Sec. 9, 771N, R17E 12. Present well condition summary Total depth: measured true vertical 10565 feet 10422 BKB feet 5. Type of Well: Development .. Exploratory Stratigraphic Service . Plugs (measured) 6. Datum elevation (DF or KB) KBE = 56' feet 7. Unit or Property name Duck Island Unit/ENdicott 8. Well number 3-43/P-36 9. Permit number/approval number 93-170/Not required 10. APl number 50- 029-22416 11. Field/Pool Endicott Field/Endicott Pool Effective depth: measured true vertical 10478 feet 10335BKB feet Junk (measured) Centralized arm from FBS on bottom Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vejli.c~l depth BKB 92' 30" Driven 131' 75' 2700 10 3/4 460 sx PF "E"/375 sx G 2739' 2674' 10519' 7 5/8" 300 sx C/ass "G" 10558' measured 10154'-10156', 10162'-10164', 10287'-10291' (All squeezed) 10108'-10112'(Open), 10132'-10140' (Open), 10228'-10245'(Open) true vertical (subsea) 10011'-10013', 10019'-10021', 10144'-10148' (All squeezed) 9965'-9969' (Open), 9989'-9997' (Open), 10085'-10102' (Open) Tubing (size, grade, and measured depth) 3 1/2" L-80 tubing to 9804' MD 10415' Packers and SSSV (type and measured depth) 7-5/8" Baker 'FB-l'packer @ 9754' MD; 3-12" 'XDB' SVLN @ 1524' 13. Stimulation or cement squeeze summary 14. Intervals treated (measured) Treatment description including volumes used and final pressure RF_C£1VF-D MAY ?-- ,5 1995 ...... nH it. r'.~ P. nn~_ C0mmissi0D Reoresentative .... Daily Averaae Production or Iniectio~. ....... Anch0ra, .¢,;.. OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 226 1240 4O2 0 287 Subsequent to operation 668 1802 95 0 3O2 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si,ned ~t~"~-;/'7.~"7~.~ ;~. /(~d~;~d.~_~.~ Title Senior Technical Ass istantll Form 10-4d.4' Rev 06/15/88 SUBMIT IN DOPLIC~ATE Endicott Production Engineering Department AdO - P~rfs DATE' 4/3-4/95 WELL N=: 3-43 / P-36 BP EXPLORATION REP: TUCKER SERVICE COMPANY: ATLAS (BARKER/RICHARDS) I, II DATE/TIME OPERATIONS SUMMARY 4/3 1030 MIRU ATLAS. WELL SI. SIWHP = 1300 PSIG, lAP 300 PSIG, OAP 0. 1215 RIH WITH 4' 2-1/2" HSC, 4 SPF, 180° PHASING, 90° ORIENTATION. 1240 SET DOWN AT 3100'. PULL 1200# TO GET FREE. POH. 1300 OOH. GUN IS CLEAN. CALL HB&R AND CAMCO. 1500 RDMO ATLAS. 1630 BRUSH AND FLUSH. 2330 DRIFT OK. RD CAMCO. 4/4 0700 DRIFT (AGAIN). 0830 RDMO CAMCO. MIRU ATLAS. 1015 RIH WITH 4' 2-1/2" HSC, 4 SPF, 180° PHASING, 90° ORIENTATION. 11 00 TIE IN TO DIL DATED 4/28/94. ADD 30'. 11 16 POP WELL. HANG GRC AT 10105. WI---tP 330. 11 20 SHOOT 10108' TO 10112'. LOST 50# LINE WEIGHT. 1130 LOG OFF, SI WELL AND POOH. WHP 280. 1220 OOH. CONFIRMED ALL SHOTS FIRED. WHP 500. 1400 RDMO. TURN OVER TO PROD. PERFORATION SUMMARY: GUN DIL DEPTH FEET SUBZQNE 1 10108 - 10112 4 3C3 Interval was shot using 2-1/2 Alpha Jet (HSC) gun at 4 spf, 180° phasing and 90° orientation. LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 10 April 1995 RE: Transmittal of Data Sent by: PRIORITY MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL 88- 7 DESCRIPTION 1PFC/PERF FINAL BL+RF 1PLS FINAL BL+RF ECC No. Run ~ 1 6192.08 Run # 1 6355.03 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: ·" APR ~ O i99,5 Alaska 011 & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISS,,.,N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging__ Pull tubing Alter casing Repair well Perforate X Other X 2. Name of Operator BP Exploration (Alaska) inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2777' SNL, 640' WEL, Sec. 8, TI/N, R17E At top of productive interval 3677'NSL, 67'EWL, Sec. 9, TIIN, R17E At effective depth 3721' NSL, 63' EWL, Sec. 9, 771N, R17E At total depth 3725'NSL, 65'EWL, Sec. 9, 771N, R17E 5. Type of Well: Development .. Exploratory Stratigraphic Service 29 995 Gas Cons. Commission 6. Datum elevation (DF or KB) KBE = 56' feet 7. Unit or Property name Duck Island Unit/ENdicott 8. Well number 3-43/P-36 9. Permit number/approval number 93-170/Not required 10. APl number 50- O29-22416 11. Field/Pool Endicott Field/Endicott Pool 12. Present well condition summary Total depth: measured true vertical 10565 feet 10422 BKB feet Plugs (measured) Effective depth' measured true vertical 10478 feet 10335BKB feet Junk (measured) Centralized arm from FBS on bottom Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True v~l depth BKB 92' 30" Driven 131' 75' 2700 10 3/4 460 sx PF "E"/375 sx G 2739' 2674' 10519' 75/8" 300 sx Class "G" 10558' 10415' measured 10108'-10112', 10154'-10156', 10162'-10164', 10287'-10291'(AII squeezed) 10132'-10140', 10228'- 10245' (Open) true vertical (subsea) 9965'-9969', 10011'-10013', 10019'-10021', 10144'- 10148' (All squeezed) 9989'-9997', 10085'-10102' (Open) Tubing (size, grade, and measured depth) 3 1/2" L-80 tubing to 9804' MD Packers and SSSV (type and measured depth) 7-5/8"Baker 'FB-l'packer @ 9754' MD; 3-12" 'XDB' S VLN @ 1524' 13. Stimulation or cement squeeze summary Coiled tubing water shut off cement squeeze dated 2/3/95 Intervals treated (measured) 10108'-10112', 10154'-10156', 10162'-10164', 10228'-10245', 10287'-10291' Treatment description including volumes used and final pressure 1295 Bbls seawater, 12 Bbls 15% HCL w/20% xylene, 11 Bbls 12/3 HCL/HF, 29 Bbls effluent water, 20 Bbls Class "G" Cement, 16 Bbls Biozan. FSIWHP = 1489 psig 14. Prior to well operation Subsequent to operation Representative Daily Average Produ~ion orlnje~ion Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 183 804 1483 0 333 303 1161 303 0 290 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 an.?orrect to the best of my knowledge. Signed ~-~--~%¢'~/q.~(.~.., ~,'-~,~ ~'.~~,,_~"~' Title Senior Technical Assistant II Form 10-4?/~ev 06/15/88 D at e ~/_~/¢~ SUBMIT IN DUPLIGATE~.f. Endicott Production Engineering Department Re-Perforation DATE: 2/6/95 WELL N~: 3-43 / P-36 BP EXPLORATION REP: Tucker SERVICE COMPANY: ATLAS (BARKER) DATE/TIME OPERATIONS SUMMARY 2/6 0900 MIRU ATLAS. WELL SI. SIWHP = 1800 PSIGI lAP 1100 PSIG, (DAP 0. 1050 RIH WITH 8' 2-1/2" HSC, 4 SPF, 180° PHASING, 90° ORIENTATION. 1150 BLEED WHP TO 300. TIE IN TO SBL DATED 5/2/94. 1230 HANG CCL AT 10129.5. SHOOT 10132' TO 10140'. NO INDICATION. 1250 LOG OFF, SI WELL AND POOH. WHP 285. 1330 OOH. CONFIRMED ALL SHOTS FIRED. 1500 RDMO. SIWHP 300 PSI. TURN WELL OVER TO OPERATIONS TO POP W/GLT. PERFORATION SUMMARY: GUN ~BL DEPTH FEET SUBZONE 1 10132 - 10140 8 3C2 All intervals were shot using 2-1/8 Alpha Jet (HSC) guns at 4 spf, 180 degree phasing and 90 orientation. Cons. Comm'~ss'~on /~nchort" Endicott Production Engineering Department DATE: WELL N=: BP EXPLORATION REP: SERVICE COMPANY: Post Saueeze Perforations -- 3/1/95 3-43 / P-36 POWERS ATLAS (HARPER) DATE/TIME OPERATIONS SUMMARY 3/1 0900 MIRU ATLAS. WELL SI. SIWHP = 500 PSIG, lAP 1100 PSIG, OAP 0. 1050 RIH WITH 17 2-1/2" HSC, 4 SPF, 180° PHASING, 90° ORIENTATION. 1230 POP WELL AND TURN ON GASLIFT. TIE IN TO DIL DATED 4/28/94. 1245 HANG CCL AT 10223. SHOOT 10228' TO 10245'. 1250 LOG OFF, SI WELL AND POOH. WHP 285. 1330 OOH. CONFIRMED ALL SHOTS FIRED. 1500 RDMO. POP WELL AT 176 BEANS WITH 1.5 MMSCFD GASLIFT PERFORATION SUMMARY: GUN SBL DEPTH FEET SUBZONE 1 10228 - 10245 17 3C1 All intervals were shot using 2-5/8 Alpha Jet (HSC) guns at 4 spf, 180 degree phasing and 90 orientation. LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 9 February 1995 Transmittal of Data Sent by: MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION '1 PFC/PERF FINAL BL+RF 1 PLS FINAL BL + RF · Run # 1 Run # 1 ECC No. 6192.06 6217.10 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: AJaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate__ Plugging__ Pull tubing x Alter casing __ Repair well __ Perforate.__ Other__ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) BP Exploration (Alaska) Inc. Development x KBE = 56' Exploratory __ 3. Address Stratigraphic __ 7. Unit or Property name P. 0. Box 196612, Anchorage, Alaska 99519-6612 Service __ Duck Island Unit/Endicott 4. Location of well at surface 8. Well number 2777' NSL, 640' WEL, SEC. 8, T11N, R17E At top of productive interval 3677'NSL, 67' EWL, SEC. 9, T11N, R17E At effective depth At total depth 3725' NSL, 65' EWL, SEC. 9, T11N, R17E 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 3-43/P-36 9. Permit number/approval number 93-170/Cons. order # 297 10. APl number 50- 029-22416 11. Field/Pool Endicott Field/Endicott Pool feet feet Plugs (measured) feet feet Junk (measured) feet Size Cemented Measured depth BKB True vertical depth BKB Tubing (size, grade, and measured depth) 3-1/2", L-80 tubing to 9804' MD FEB --:5 1995 0[~ & Gas Cons. Commission Anchor~-.i9 Packers and SSSV (type and measured depth) 7-5/8" Baker 'FB-1' packer @ 9754' MD;3-1/2" 'XDB' SVLN 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 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. I Signed ,/_/~//__~,1~,¢~.~_~.~/~/?..~~.~/.~/¢/., L¢/~ /~ TitleDrillin.q En.qineerSupervisor Form 10-404 R~v 06/15¢88 ~//'./ ///,///~.. ~, Date SUBMIT IN DUPLICATE WELL : SDI 3-43 OPERATION: RIG : DOYON 15 PAGE: 4 05/02/94 (18) TD:10565 PB: 0 RIG RELEASED MW: 0.0 TESTED DRY HOLE TREE T/5000 & CLEANED UP WELLHEAD AREA/WELLHOUSES. RELEASED RIG @ 08:00 HOURS ON 5/1/94. 12/17/94 (19) TD:10588 PB:10478 NU BOPE MW: 0.0 MOVE RIG FROM MPI T/SDI. MOVE OVER WELL & SPOT IN PIT COMPLEX & LEVEL. ND VALVE & ADAPTER FLANGE, NU RISER & BOPE. 12/18/94 (20) TD:10588 PB:10478 RIH W/TBG COMPLETION MW: 0.0 NU BOPE, MIX 240 BBLS OF 8.7 PPG BRINE IN PITS. COMMISSION ESD. LOAD PIPE SHED W/3.5" TBG. STRAP 324 JTS, CHANGE OUT BRAKE ASSY ON DRAWWORKS. CHK WELL F/PRESS, STABLE. PULL BPV & FALSE BOWL F/WELLHEAD. INSTALL TEST PLUG, TEST BOPE, LO/HI PRESS TEST. PULL TEST PLUG. RIH W/3.5" DP T/1500. CIRC OUT DIESEL CAP F/WELL (70 BBLS.) POOH & LD 3.5" DP. RU TBG TONGS, MU SEAL ASSY & RIH W/3.5" TBG COMP. 12/19/94 (21) TD:10588 PB:10478 ND BOPE MW: 0.0 RIH W/3.5" TBG COMPLETION, MU CL T/BVLN. TEST T/5000. RIH & STING INTO SEAL BORE EXTENSION / TEST T/1500. POOH ABOVE PKR & REV. CIRC 8.7 PPG BRINE W/INHIBITOR DOWN ANNUL. MU SPACE OUT PUP JT. TBG HNGR & LNDG JT. HOOK UP CL & TEST T/5000. LAND TBG. RILDS. PRESS UP ON TBG X CSG ANNUL. T/2500 F/30 MIN. OK. LD LND'G JT & SET TWC. CLEAR RIG FLOOR LD TONGS & TOOLS. CHANGE RAMS IN BOP STACK T/5" & 4.5" X 7" VARIABLE. ND BOPE. 12/20/94 (22) TD:10588 PB:10478 RIG RELEASED. MW: 0.0 NU ADPTR FLNG & PRODUCTION TREE, TEST T/5000. ALSO TEST CL. RU HI PRESS LUB. & PULL TWC, RD LUB. SHEAR RP VALVE @3100 PSI, DISPLACE TBG ANNUL T/65 BBLS DIESEL. U-TUBE DIESEL, SET BPV & SECURE TREE & WELLHEAD. HAUL OFF WASTE FLUID F/SLOP TANK, PITS & CELLAR, DEACTIVATE ESD, PREPARE F/MOVE. RELEASE RIG @ 14:00 HOURS ON 12/19/94. SIGNATURE: (drill superintendent ) DATE: RECEIVED FEB 1995 Ai~..ska Oil & Gas Cons. Commission Anchoi'a ,o LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE.DRivE ANCHORAGE AK, 99501. Dear Sir/Madam, Enclosed, please find the data as described below: WELL ~7- &~ 3-21/L-34 SDZ ~ 7-- 3~ 3-21/L-34 SDZ ~-- / 70 3-~3/P-36 (SDS) DESCRIPTION PFC/PERF FINAL BL+RF PLS-STP FINAL BL+RF PLS FINAL BL + RF PFC/PERF FINAL BL+RF PFC/PERF FINAL BL+RF RECEIVED JAN 25 1995 Alaska Oil & Gas Cons. Commission Anchorag~ Date: 18 January 1995 RE.. Transmittal of Data Sent by: MAIL ECC No. Run # 1 5765.07 Run # 1 5765.08 Run # 1 6~92.05 Run # 1 6217.09 Run # 1 6296.03 Received by: Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Date: MEMORAND i,/i State Alaska Alaska Oil and Gas Conservation Commission TO: THRU' David John~~, Chairmarf/,,~ Blair Wondzell, P. I. Supervisor FROM' Bobby Fo~ SUBJECT: Petroleum Inspector · 0 DATE: December 17, 1994 FILE NO: ALHILQBD.doc BOPE Test - Doyon 15 BPX - DIU -,3-_2~J.~.~3.6- PTD # 86-126 Endicott Field Saturday, December 17, 1994: I was notified by Nick Scales, BPX drilling rep., at 11:00 AM that the initial BOPE test would began at approximately 2:00 PM. I arrived at the rig at 1'15 PM.The test began at 6:00 PM and was concluded at 9:30 PM. As the attached AOGCC BOPE test report shows there was 1 failure. The pressure sensor on the choke manifold would not function properly. It was removed and the rubber boot was changed and a small leak in the pressure line was repaired. The sensor functioned properly after repairs were completed. Summary: i witnesssed the BOPE test on Doyon rig 15 working over BPX's well 3- 34/P-36 - Test time 3.5 hours - 1 failure. Attachment: ALHILQBD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: 7" Test: Initial Workover: X DOYON Rig No. 15 PTD # BPX j .., Rep.: Set @ Location: Sec. X Weekly Other ' TE f2/17/94 g P~.# 659-6510 NICK SCALES MIKE DRODDY 8 T. 'I1N R. 17E Meridian U MISC. INSPECTIONS: Location Gen.: OK Well Sign OK Housekeeping: OK (Gen) Drl. Rig OK Reserve Pit N lA BOP STACK: Quan. Annular Preventer '/ Pipe Rams 1 Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves 2 Kill Line Valves 1 Check Valve N/A Test Pressure P/F 300/3,000 P 500/5,000 500/5,000 500/5,000 500/5,000 500/5,000 500/5,000 P P P P P P MUD SYSTEM: Visual Alarm Trip Tank YES YES Pit Level Indicators YES YES Flow Indicator YES YES Meth Gas Detector YES YES H2S Gas Detector YES YES FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F 1 500/5,000 P 1 500/5,000 P 1 500/5,000 P 1 500/5,000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes 17 Test Pressure 500/5,000 42 500/5,000 Functioned Functioned P/F P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained 3 Blind Switch Covers: Master: Nitgn. Btl's: 4 ~ 2500 3,000 P ~,500 P minutes 33 sec. minutes 7 sec. YES Remote: YES Psig. Number of Failures: I ,Test Time: 3.5 Hours. Number of valves tested 23 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: The sensor unit on the choke manifold failed - repaired and retested - OK Distribution: orig-Well File c - Oper./Rig c - Database c- Trip Rpt File c - Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: BOBBY D. FOSTER FI-021L (Rev. 7/19) ALHILQBD.XLS ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 1 August 1994 RE: Transmittal of Data ECC #: 6192.04 Sent by: U.S. MAIL Data: PL Dear Sir/Madam, Reference: 3-43/P-36 (SDI) ENDICOTT ~ NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: Prints/Films: 1 PL/GASLIFT FINAL BL Run # 1 1 PL/GASLIFT RF SEPIA Run # 1 Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 q) / /~ An_cho.rage, AK 99518 %- // Rodney D. Paulson Received ~~ ~~//~D a~e ~ ~ECE,~/ED Alas~ Oil ~ ~s Co~s. ~emmissio~ Please sign and return to: Petrotechnical Data Center BP Exploration (Alaska) Ine 900 East Benson Boulevard Anchorage, Alaska 99.508 Received by STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RI=COMP L£TION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPEI',DED [] ABANDONED [] SERVICE [] 2. Name of Operator OR] 7. Number BPExp/oration GINAL Permit _ 93-170 3. Address 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 so- 029-22416 4. Location of well at surface 9. Unit or Lease Name 2777' NSL, 640' WEL, SEC. 8, T11N, R17E~i ?;{i;{~!';~i'~'¥rlii~~, ~,~~ Duck Island Unit/Endicott 10. Well Number 3677'NSL, 67 EWL, SEC. 9, T11N, R17E I ~ ! 11 Field and Pool Fie/d/Endicott Pool 3725' NSL, 65' EWL, SEC. 9, T11N, R17E ..... ~'~'~ ~ '~' 5. Elevation in feet (indicate KB, DF, etc.) ~6. Lease Designation and Serial No. KBE = 56' I ADL 47502 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Waler Depth, if offshore 116. No. of Completions I 4/15/94 4/28/94 5/25/94 6-12' feet MSL I One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+'DVD) 19. Directional Survey ~20. Depth where SSSV set ~1. Thickness of Permafrost / 10565' MD/10479' TVD 10376' MD/10290' TVD YES [] NO [] 1500' feet MD ]1465'(Approx.) 22. Type Electric or Other Logs Run Run # 1 DIFL/ZDL/CNL/SP/GR Run #2 RFT 23. CASING, LINER AND CEMENTING RECORD SE'ri'lNG DEPTH MD CASING SIZE WT. PER F-T. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 30 Struct Drive 37' 131' Drive 10-3/4" 45.5~ NT-80 37' 2739' 13-1/2" 460 sx PF "E"/375 sx "G" 7-5/8" -29.7# NT95HS 41' 10558' 9-7/8" 300 sx Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MDI Gun Diameter 2-1/8" 4 spf MD TVD 3-1/2", HS-7OCM 9800' 9754' 10287'-10291' 10200'-10204' 10228'-10245' 10141'- 10158' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10162'-10164' 10075'-10077' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10154'-10156' 10067'-10069' 10132'-10140' 10045'-10053' 10108'-10112' 10021 '-10025' 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 5/26/94 I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF ¢/ATER-BBL iCHOKESIZE IGAS-OIL RATIO I TEST PERIOD Flow Tubing Casing Pressure CALCULATED ::)IL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence ol oil, gas or water. ,Submit core chips. RECEIVED JUi 29 !994- /:,..!$.si.',a ()il & Gas Cons, Commission Anchora.~8 Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOL~ MARKERS r,.)RMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS.'DEPTH - TRUE VERT. DEPTH GOR, and time of each phase. Subsea Base HRZ 9936' 9794' Top Itkiyariak 9966' 9824' Top Kekiktuk 10000' 9857' R[C !V D diJ["i 29 i99zi. ....... - .... ~ Ihs C'o~, C~mm. issi0p, I]1. LIST OF' ATTAOHMENT$ 32. I hereby oer~ify that the foregoing is true and correct to the best of my knowledge Signed ~' C /(~-f"~ Title Drilling Engineer Supervisor Date , . INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: SDI 3-43/P-36 BOROUGH: NORTH SLOPE I/NIT: ENDICOTT FIELD: ENDICOTT LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 04/14/94 06:00 SPUD: RELEASE: OPERATION: DRLG RIG: DOYON 15 WO/C RIG: DOYON 15 04/15/94 ( 1) TD: 350' ( 350) 04/16/94 ( 2) TD: 2750' (2400) 04/17/94 ( 3) TD: 2762' ( 12) 04/18/94 ( 4) TD: 2762' ( 0) SPUD/DRILL T/350' MW: 8.7 VIS:300 RDMO F/3-17. RU & ACCEPT RIG. TAKE ON WATER/MIX SPUD MUD. NU RISER/FLOW LINE & MIX MUD. MOVE BHA INTO PIPE SHED & STRAP, MIX MUD. RU ATLAS WL & GYROTEC. SERV. RIG. PU BHA & ORIENT. SPUD & DRILL T/350. DRILLING MW: 9.1 VIS:170 DRILL & SURV. EVERY 90' T/1427. SERV. RIG. CIRC. SHORT TRIP F/1427 T/477. DRILL & SURV. T/2483. WORK ON CUTTINGS WASHER DRILL & SURVEY T/2750. NU BOPE RISER MW: 9.3 VIS: 81 DRILL T/2762. CBU. SHORT TRIP 2762 T/1400. OK. CBU.GYRO EVERY 100' F/2762 T/SURF. POOH T/500. RD ATL. WL. & GYROTEC. POOH LD MWD & MUD MOTOR. RUN 10.75 CASG. 68 JTS. CBU. RU HALBRTN. PUMP 5 BBLS H20, TEST LINES T/3000. PUMP 15 BBLS H20/178 BBLS LEAD CMT/77 BBLS TAIL CMT, 7 BPM @800, DROP PLUG, DISPLACE W/RIG PUMP @ 10BPM 1100. BUMP PLUG & PRESS T/2000. CIP @23:20.CIRC. 60 BBLS CMT SLURRY T/SURF. NO TOP JOB NEEDED. CLN CMT F/RISER/FLOW LINE & SHAKERS, ETC. CLEAR RIG FLOOR OF CASG & DMT TOOLS, LD LNDG JT. ND RISER & DIVERTER. MU SLIM HOLE WELL HEAD & TEST T/1000. SET WORK PLATFORM, NU BOP & RISER, DUMP 60 BBLS CMT T/ROCK WASHER UNIT 16. CIRC & COND MUD MW: 9.4 VIS: 46 NU BOPE, TEST & INSTALL WEAR RING. CHANGE DL. RESET CROWN -O-MATIC. LD 8" BHA & ORIENT. RIH T/2657, TAG FLOAT COLLAR. TEST MWD. TEST CASG T/2500. DRILL OUT FLOAT EQUIP & CMT + 10' OF NEW HOLE T/2772. CIRC & COND. MUD. WELL : SDI 3-43 OPERATION: RIG : DOYON 15 PAGE: 2 04/19/94 ( 5) TD: 4077' (1315) 04/20/94 ( 6) TD: 5223' (1146) 04/21/94 ( 7) TD: 6413' (1190) 04/22/94 ( 8) TD: 7600'(1187) 04/23/94 ( 9) TD: 8321' ( 721) 04/24/94 (10) TD: 9242' ( 921) 04/25/94 (11) TD: 9507'( 265) DRILLING MW: 9.4 VIS:il0 LEAK OFF TEST EMW = 12.6PPG. DRILL T/3171 FILL ON CONNECTION. CIRC HI VIS SWEEP. DRILL T/3266. HOLE SLUFFING ON CONNECTION. CIRC HI/LO VIS SWEEP & BRING WT UP T/9.4 PPG. DRILL T/3362. 500 LB. PRESS. DROP, CHK. SURF. TOOH CHECKING F/WASH OUT. BIT JET W/O. CHANGE OUT BIT & NM/STAB, REORIENT MOTOR. RIH. WASH 95' T/BTTM. 25' OF FILL. DRILL T/4077. TOOH F/MWD. MW: 9.7 VIS: 71 DRLG T/4410. CBU. (2WICE). DROP SP-SUN SURV. TOOL. PULL T/2740. RECOVER SURV. TOOL, RAN BACK T/BTTM. DRILL T/5173. PUMP HI VIS. SWEEP WHILE DRLG. SHORT TRIP T/3812. WASH LAST 95' T/BTTM. NO FILL. DRILL T/5223, MWD QUIT WORKING. CBU. TOOH F/MWD. DRILLING MW: 9.7 VIS: 62 CON'T TOOH. LD MWD & BIT ~3. MU NEW MWD & BIT #4. SERV. RIG. TROUBLE W/ELEC. WIRE ON TOP DRIVE. TIH W/BHA, TEST MWD. TIH T/5223 OK. DRLG & SURV. F/5223 T/6128. CBU SHORT TRIP T/5173. WASH T/BTTM. OK. DRLG $ SURV T/6413. LD 20 JTS DP WHILE TIH F/HARD BANDING. CBU MW: 9.7 VIS: 60 DRLG & SURV. F/6413 T/7084. PUMP HI/LO SWEEPS. TRIP T/6224. NO FILL. DRLG & SURV. T/7600 MD. PUMP HI VIS SWEEP. CBU T/TOOH F/PDC BIT. TODAY MARKS 6 MO. W/O AN LTA F/DOYON 15! DRILLING W/ PDC BIT MW: 9.9 VIS: 54 PULL 10 STDS. PUMP DRY JOB. TRIP OUT. CHANGE OUT MUD MOTOR AND BIT. TRIP IN. TEST MWD. CONTINUE TRIP IN TO 7600'. DRILL AND SURVEY TO 8321' MD, PUMP HIGH VIS SWEEP. SHORT TRIP TO 7371'. DRILL TO 8321'. DRILLING W/ PDC BIT IN TUFFS MW:10.4 VIS: 67 DRILL AND SURVEY TO 8892' MD. SHORT TRIP TO 7943'. DRILL AND SURVEY TO 9242' DRILLING MW:10.4 VIS: 56 DRILL AND SURVEY F/ 9242-9273' SHORT 10 STDS. DRILL AND SURVEY TO 9350'. CBU. TRIP OUT. CHNAGE BHA, P/U BIT #6. TRIP IN TO 2708' CUT DRILL LINE. TEST MWD. CONTINUE TRIP IN, WASH LAST 88' TO BTM. DRILL AND SURVEY W/ BIT #6 TO 9507' WELL : SDI 3-43 OPERATION: RIG : DOYON 15 PAGE: 3 04/26/94 (12) TD: 9999' ( 492) 04/27/94 (13) TD:10354' ( 355) 04/28/94 (14) TD:10489' ( 135) 04/29/94 (15) TD:10565' ( 76) 04/30/94 (16) TD:10565' ( 0) 05/01/94 (17) TD:10565' ( 0) SHORT TRIP MW:10.4 VIS: 63 DRLG & SURV. F/9507 T/9787. SHORT TRIP, PULLED TIGHT, PUMP EA. STND OUT TIL FREE/8 STNDS. HOLE OK ON TRIP T/BTTM. POOH 5 STNDS. OK. BACK T/BTTM @ 9687. DRLG & SURV. T/9862. 10 STND SHORT TRIP. DRLG T/9999. SHORT TRIP T/9071 DRILLING MW:10.3 VIS: 54 SHORT TRIP. DRILL F/9999 T/10917. PUMP HI/LO VIS SWEEP. SHORT TRIP OF 10 STNDS T/9357. DRLG T/10292. PUMP SWEEP. 10 STND TRIP T/9358.DRLG T/10354. DRILLING MW:10.4 VIS: 60 DRLG T/10362, BIT BEGAN T/TORQUE UP. CBU. 10-STND SHORT TRIP. CIRC AROUND HI-VIS SWEEP. POOH. LD MWD, PU MECH JARS & RIH. WASH T/BTTM, NO FILL. DRLG T/10460. SHORT TRIP, 10 STNDS. DRLG T/10489. RUN IN HOLE MW:10.3 VIS: 56 DRILLED T/TD @ 10565. CBU. 20-STND SHORT TRIP. OK. CIRC HI-VIS SWEEP. PUMP DOWN SURV. POOH. RU WEST ATLAS. HOLE IN GOOD SHAPE, LOGS T/BTTM. RUN #1: DIFL, ZDL, CN, SP, GR TRI COMBP. RUN %2: RFT-18 READING DURING RUN. RD WEST. ATLAS. RIH F/WIPER TRIP. RUNNING 7-5/8 CASG MW:10.4 VIS: 65 CUT DL. RIH T/BTTM. NO FILL. CBU. TWICE/HOLE CLEAN. POOH, LDDP AFTER STANDING 50 STNDS BACK IN DERRICK. CHANGE T/7-5/8 CASG RAMS. POOH & LD HWDP, BHA. PULL WEAR BUSHING. CLEAN FLOOR, RU T/RUN 7-5/8 CASG. NU DRY HOLE TREE MW: 8.5 VIS: 0 RUN CASG, LND HNGR. SHOE @10558, FC @ 10478. CIRC & RECIP. TEST LINES T/3500 & PUMP CMT. DISPLACE W/SEAWATER USING RIG PUMPS. TEST CASG T/3500. CLEAR FLOOR. TEST PCK-OFF ASSY T/5000. OK. DOWNSQZ ANNUL. W/150 BBLS MUD & FRZ PROTECT. T/1500 W/60 BBLS DIESEL. CHANGE RAMS T/5". PU 123 JTS 3.5 DP & RIH T/3800. FRZ PRTECT CASG T/3800 W/DIESEL. POOH LDDP. & FILL HOLE W/20BBLS DIESEL. INSTALL FALSE BOWL & COIL TBG HNGR W/2-WAY CHK VALVE. ND BOP'S. NU HOLDDOWN FLANGE ADPTR. & 7" MASTR VALVE & TEST T/5000. WELL : SDI 3-43 OPERATION: RIG : DOYON 15 PAGE: 4 05/02/94 (18) TD:10565 PB: 0 RIG RELEASED MW: 0.0 TESTED DRY HOLE TREE T/5000 & CLEANED UP WELLHEAD AREA/WELLHOUSES. RELEASED RIG @ 08:00 HOURS ON 5/1/94. SIGNATURE: (drilling superintendent) DATE: OPERATION REPORT FROM: LOVELAND / MELVAN / DATE: 05/04/94 NORDLANDER ENDICOTT OPERATION: 3-43/P-36 WELL: 3.5" COILED TUBING INITIAL WELL COMPLETION IIs wHP [] o I iAP = o I OAP = 0 I AMBIENT = 15 II I II ITI~'E I ' OPERATION ' I 05-04 08.00 MI BOP & CRANE. KNOCK OFF TREE CAP. RELACE SEAL RING. SPEC OUT GUIDELINES. SPOT DSR SKID. 09.30 MU BOPS. SPOT WARM UP SHACK, COMMAND VAN, 4907. LAY OUT GUIDELINES. 11.00 UNLOAD & PU WORK WINDOW, MU GUIDELINES. OFFLOAD WINDOW W/TOOLS. PU WINDOW AND A'FI'ACH SAME. 15.00 LAY OUT SPILL CATCHERS, HYDRAULIC HOSES. WORK ON ELECTRIC POWER-GENERATOR MISSING TRANSFORMER 16.00 MOVE CRANE TO MOVE INJ HEAD. PREP TO REMOVE OLD COIL. PU HEAD AND SET ON GROUND TO REMOVE ARC. CLAMP COIL @ LEVEL WIND AND PREP TO CUT THE COIL. 19.00 MU BOP HOSES WHILE PREP TO REMOVE OLD SPOOL CONNECT HYD LINES FROM COMMAND VAN, POWER SKID, AND INJ. HEAD. RU BOP WIND WALLS 22.00 ATTEMPTTO CUT PIPE. DSL IN OLD OOIL. NO DSL AT ENDS OF COIL SOTHERE ARE ICE PLUGS IN IT TOO. CONTAIN DSL. DRAIN TOP OF COIL W/DRAIN HOLE. 22.45 CUT COIL. REMOVE OLD SPOOL (REEL ID 1875) FROM PRIOR COMPLETION AND LOAD ON FLOAT 23.30 FUNCTION TEST BOPS. CLOSE SHEAR AND BLIND RAMS. 05-05 00.30 SHUT DOWN FOR NIGHT. 08.30 CREW ON LOCATION. START UP EQUIP. PREP TO CONNECT NEW SPOOL TO OLD STUB IN INJ HEAD. OLD STUB LEFT IN INJ HEAD SINCE GOOSE NECK ROLLER SE'I-I'ING IS TOUCHY BUSINESS. 09.16 CONNECT NEW CT REEL TO CTSTUB IN INJECTOR W/CHAIN CONNECTOR. REPLACE GAS BO'I-I-LE 10.30 CUT OFF BRACE OF NEW COIL- SPOOL ID # 1837-6030 FT. DRESS WELD MARK OFF NEW COIL 11.45 MOVE CHAIN LINK PAST HORSE HEAD. 12.00 STAB INJ HD ONTO WINDOW-VERY TIGHT FIT BETWEEN GOOSE/BOOM/AND GUIDELINE DUE TO WIDTH OF LA'I-I'ICE BOOM AND GEOMETRY CONSTRAINTS. 13.15 TRY TO LOWER PIPE- NOT GETTING TRACTION PRESSURE TO HEAD. MOVE MAN BASKET TO INSPECT HOSE CONNECTIONS. TRACTION PRESSURE BLEEDING OFF. FOUND PROBLEM. FIX SAME. PROBLEM ALSO CAUSED CASE DRAIN ON INJ MOTOR TO LEAK ALSO. 14.00 RUN DWN & CUT AND LAY OUT OLD PIPE FROM LAST SPOOL AND CHAIN CONNECTOR. 15.00 TRY TO TIGHTEN BACK PLATE ON INJECTOR MTR TO STOP LEAK-NO SUCCESS. 15.30 BRING INJ. HEAD DWN. PULL OFF MOTOR AND TAKE TO SHOP. 18.00 LEAVE LOCATION. WILL CONTINUE AFTER INJECTOR MOTOR IS REPAIRED. 5/06 MOTOR WAS TORN DOWN AND INSPECTED. NO DAMAGED SEALS FOUND. POSSIBLY A FEW BOLTS WERE NOT TO REQUIRED TORQUE. RE-ASSEMBLE MOTOR. 07.00 RE-A'FI'ACH INJ. HEAD MOTOR. TEST RUN IT. NO LEAKS. 09.00 RU TO INJ HEAD. RE-ARRANGE HOSES TO WORK WINDOW RAMS. MADE MODIFICATION FOR CONTROLS IN BOTH FLOORS OF WINDOW. 11.05 ATTACH BULL NOSE. RUN IN PIPE TO TOP OF MASTER. 12.00 FILL AND FLUSH CT W/80 BBL MEOH @ 6 BPM. 13.32 PT PIPE RAMS, SHEAR SEALS, AND BLIND RAMS. FUNCTION TEST ANNULAR. 14.02 PREP COIL STUB. ATTACH COUNTER. PU BKR SEAL ASSEMBLY AND SET W/DOG COLLAR 15.30 REMOVE INJ. HD-SWING OUT OF THE WAY. LOWER CENT. ASSEMBLY THRU TOP OF WINDOW. MAKE UP SAME. 18.50 RIH W/BHA. ENDICOTT 3-43, 3.5" CT COMPLETION PAGE 1 19.26 STOP @ 779 COIL DEPTH (NOT BKB) SET SLIPS. PREP TO CUT COIL. 20.34 22.04 PTTO2000. GOOD. RIH. CT DEPTH AT TOP OF MANDREL CONNECTOR 780 22.30 SHUT DWN @ GLM ~2 POINT. SECURE WELL. SDFN. 5/7 06.30 START EQUIPMENT. DRILL & DRAIN PIPE. CUT PIPE. DRESS STUBS. MU GLM #2. 08.11 PULL TEST. MU SEALS. P-TEST 2000 PSI. OK O8.52 RIH 09.15 SET SLIPS. INSTALL GLM #3. P-TEST. DRLG HAS US MOVE WARM UP SHACK. 11.27 RIH. TOP GLtv~3 @ 1868 COUNTER DEPTH. 12.05 INSTALL GLM ~4. COUNTER @ 2566 FT. WRAP COUNT ON SPOOL VERIFIES DEPTH. 13.22 P-TEST GLM~4. 14.11 RIH 14.50 STOP @ 4076 CTD. INSERT GLM #5. P-TEST-OK 16.40 RIH TO FINISH SPOOL. 17.28 STOP TO CHANGE SPOOLS. COUNTER @ 5845. MOVE TRIPLEX & MEOH TRAILER. VAC ON COIL. CLAMP OFF OLD SPOOL. REMOVE COUNTER. CUT COIL & SECURE SAME. RU CRANE. SWAP SPOOLS. 20.50 PREP TO CUT RETAINER BAR OFF OF NEW SPOOL. SPOOL ID 1617-4900 FT. 22.01 PULL CHAIN CONNECTOR THRU HORSE'S HEAD. INSTALL COUNTER. MEASURE LENGTH 22.16 PULL CHAIN CONNECTOR TO TOP OF INJ HEAD. 22.45 CUT PIPE. INSTALL SPLICE & PT. 5/8 00.15 PT. FLUSH CT W/55 BBLS ~ 4.5 BPM AND 300 PSI 02.09 PULL 56K. SET PACKING. PT TO 2000. 02.41 GOOD. PU, RELEASE SLIPS. RIH, PERFORM PULL TEST, 70K UP, 44 DWN. 03.00 STOP @ GLM #6 POINT. SDFN 10.30 BLEED COIL. CUT COIL FOR GLM #6. PREP COIL AND INSTALL GLM. P-T 11.30 RIH. GOT 751 FT IN AND HORSE HEAD ON REEL HUNG UP AND DIMPLED THE PIPE. DECIDE TO CUT OUT AND SPLICE. 15.30 DRAIN PIPE, CUT AND PREP. INSERT SPLICE AND P-T. 17.45 RIH. RU SHEAVE FOR CONTROL LINE. RU PUMP FOR SSSV 18.31 STOP @ 8171 CTD (NOT TRUE DEPTH). DRILL/DRAIN/CUT PIPE. INSTALL SSSV. PU TEST TO 84 K 20.32 P-T SSSV CONNECTIONS. CLOSE SSSV. 21.00 SECURE WELL. LEAVE LOCATION. 5/9 07.00 CREW ON LOCATION. PU CONTROL LINE. OPEN SSSV. MU 08.00 RIH W/CONTROL LINE. BAND EVERY 80 FT. 4 BANDS ON SSSV 09.40 TAG UP. LOOSE 5K. PU WT 84-86 K. COUNT WRAPS ON REEL. 10.15 PUMP UP & SHEAR OUT PLUG @ 3100 PSI. 450 PSI BACK PRESSURE. 10.50 RIH PUMPING TO CHECK DEPTH AGAIN. LOWER SEAL IN @ 9612. SAW PRESS INC 300 PSI. DROP DOWN 2 FT- PRESS INCREASING. GOOD SEALS. DROP TOTAL OF 15 FT AND SAW LOCATOR LAND. 12.08 PU TO NEUTRAL 84K UP WT. COUNTER DEPTH 9625.7. PU 1 MORE FOOT TO 9624.7FT. DISTANCE FROM HOLD DWN SCREWS TO WORK FLOOR 18 FT 7-1/2" (18.62 FT) 12.30 SPACE OUT AND MARC COIL. SHUT SSSV. BLEED OFF COIL. CUT & PREP PIPE. INSTALL PUP/HANGER/AND RUNNING TOOL. PULL TESTED TO 100K. 15.51 PREP HANGER CONTROL LINE-TEST SAME- PEEL BACK RUBBER. WRAP LINE AROUND NECK AND BAND SAME. EQUALIZE ABOVE SSSV AND OPEN SAME. UNBOLT 17.14 BEGIN TO LOWER HANGER SLOWLY THRU. STOP TO REMOVE SLIP BOLTS. 17.40 SCREW IN LOCK DWN SCREWS. Pfr COIL TO 2500 PSI. NO LEAKS. IA CAME UP TO 140 PSI FROM BALOONING- HOLDING ALSO. BLEED OFF THEN CLOSE SSSV. 18.50 REMOVE ICE PLUG FROM AIR SUPPLY. DRILL AND CUT COIL. BACK OUT LANDING JOINT-TOUGH WITH THE ARC IN THE COIL. 19.00 VAC REEL PLUG COIL & LAY DWN INJ. HD. INTSTALL 2-WAY CHECK. PULL WORK WINDOW & BOPS. 21.07 SET TWO-WAY CHECK. RIG DOWN INJ HD. 21.58 HOOK UP TO INJECTOR HEAD, REMOVE GUIDE WIRES, SET DWN WIDOW, UNLOAD SAME. 11.30 REMOVE BOP'S. INSTALL TREE CAP. LOAD OUT EQUIPMENT 01.30 RIG DWN COMPLETE. ENDICOTT 3-43, 3.5" CT COMPLETION PAGE 2 08.00 RU CRAN. REMOVE 7-1/16 VALVE. INSTALL 7-1/16 BY 4-1/16 ADAPTOR. INSTALL CONTROL LINE PENETRATOR. P-TEST 5000 OK. RU TREE. HAD TO TURN WING ACTUATOR: DELIVERED BY ~PER IN HORIZONTAL POSITION. P-TEST 5000 PSI. OK. REMOVE TWO-WAY CHECK. P-TEST IA TO 1000 PSI. 16.00 TREE RIG UP COMPLETE. 05-04-94 RIG UP 4907, 3.5" CTU EQUIP. AND DSR 7" BOP'S. INSTALL DEADMEN AND GUIDE WIRES. 3.5" CT REELS #1837( 6,005 FT) AND #1817 (4900 FT ) ON LOCATION. CUT AND REMOVE OLD SPOOL FROM REEL STAND. INSTALL NEW SPOOL (#1837) FUNCTION TEST INJECTOR HEAD AND DSR BOP'S. 05-05-94 SPLICE IN NEW SPOOL STAB INJ HEAD. RUN DOWN OLD PIPE IN INJ HEAD AND CUT OFF SAME. HYDRAULIC LEAK DEVELOPED IN INJ HEAD MOTOR FROM HIGH HYDRAULIC PRESSURE ON BACKSIDE OF MOTORS. INSPECT WHILE ON TOP OF WINDOW WITH MAN BASKET. TRIED TO TIGHEN OUTER FLANGE BOLTS TO STOP LEAK- NO SUCCESS. LAY DOWN INJ HEAD ON GROUND AND INSPECT SAME. UNABLE TO DETERMINE EXACT LEAK SOURCE. REMOVE INJ HEAD MOTOR TANDEM AND TAKE TO SHOP. TEAR DOWN AND INSPECT SEALS-NO DAMAGE. REASSEMPLBE MOTOR 5-06-94 INSTALL MOTOR ON HEAD AND PICK HEAD BACK UP TO WINDOW. DISCOVERED HYDRAULIC PATH PROBLEM ON WORK WINDOW RAM CONTROLS (RECENT MODIFICATION)-FIX FLUSH AND FILL COIL W/80 BBL MECH. PRESSURE TEST BOPS-NO LEAKS SWING INJECTOR TO THE SIDE AND PICK UP BHA THROUGH TOP OF WINDOW. MAKE OF 1ST CONNECTOR AND RIH W/COIL. INSTALL #1 GLM AND P-T. RIH TO #2 GLM POINT AND SHUT DOWN FOR NIGHT. 5-07-94 INSTALL #2, #3, #4 AND #5 GLM CLAMP OFF AND CUT PIPE. REMOVE EMPTY SPOOL, INSTALL NEW SPOOL AND CHAIN CONNECTOR. PULL NEW PIPE TO FLOOR. RU PUMP TRUCK TO COIL AND RETURN LINE FROM END OF COIL TO HARDLINE. FLUSH AND FILL EMPTY COIL W/55 BBL MECH. INSTALL SPLICE AND P-T. RIH TO ~GLM POINT SDFN 5-08-94 INSTALL #6 GLM AND P/T RIH W/PIPE-MADE 71 FT AND HORSE HEAD HUNG UP ON REEL AND DIMPLED THE COIL. TOO SEVERE TO RIH. CALL OUT SPLICE FROM DEADHORSE. USED 6 FT PUP AND 2 COIL CONNECTORS. INSTALL SPLICE, P-T, AND RIH INSTALL SSSV NIPPLE AND P-T. RU CONTROL LINE SHEAVE, PUMP ETC. PREP TO RUN LAST OF COMPLETION SDFN 5-09-94 INSTALL CONTROL LINE AND P-T. RIH W/COIL, BANDING CONTROL LINE EVERY 80 FT. TAG UP ON PACKER. PU AND SHEAR OUT RETRIEVALBE PLUG @ 3100 PSI. 450 PSI UNDERBALLANCE ON COIL. STING INTO PACKER. SPACE OUT. PULLED OUT OF PACKER AND STUNG IN AGAIN TO VERITY SPACEOUT. STING BACK OUT SHEAR OUT .ISHUT SSSV, BLEED OFF, AND INSTALL HANGER ASSEMBLY, RUNNING TOOL, AND LANDING JOINT. PUMP UP COIL TO 450 AND OPEN SSSV. LAND HANGER AND SECURE SAME. P-T TO 2500 PSI-SEALS HOLDING CLOSE SSSV AND BLEED OFF AGAIN. CUT COIL AND BACKED OUT LANDING JOINT AND COIL STUB. INSTALL 2-WAY CHECK. RIG DOWN ALL COIL COMPLETION EQUIPMENT AND MOVE OUT SAME. INSTALL TREE CAP ON VALVE SDFN ENDICOTT 3-43, 3.5" CT COMPLETION PAGE 3 5-10-94 REMOVE TREE CAP AND INSTALL ADAPTOR. P-T TO 5000. INSTALL CONTROL LINE PENETRATOR AND P-T TO 5000. INSTALL TREE AND CLOSE WING. REMOVE WIND VALVE AND ACTUATOR AND RE-INSTALL IN VERTICAL POSITION. P-T TREE TO 5000 PSI. REMOVE 2-WAY CHECK P-T IA TO 1000 PSI. OK LEAVE LOCATION. I SEAL ASSEMBLY SUMMARY i ITEM OD (INI ID (INt LENGTH IFT! REMARKS 3.5" COILED TBG CONN. 4.86 3.12 1.76 CAMCO 3.5"r 9.2#r PUP W/ CENTR. 3.52 2.99 9.13 BPX- NSCT 3.5" SWS NIPPLE 3.97 2.750 1.00 3.5"~, 9.2#;, PUP W/ CENTR. 3.52 2.99 10.03 BPX- NSCT LANDING PROFILE 4.26 2.99 0.83 BAKER DUAL SEAL ASSM, 6 TOP 4.00 3.00 15.14 BAKER SEALSr 6 BTM SEALS RATCHETING WLEG 3.95 3.00 1.58 BAKER 39.47 TOTAL LENGTH GAS LIFT MANDREL SUMMARY ITEM DEPTH BKB ID / OD lIN! LENGTH (FTI REMARKS #6 - 3.5" GAS LIFT MNDRL 3577 2.92 / 5.968 12.97 RP VLVE @ 3000 PSI #5-3.5" GAS LIFT MNDRL 5597 2.92 / 5.968 12.95 DUMMY VALVE #4 - 3.5" GAS LIFT MNDRL 7117 2.92 / 5.968 12.98 DUMMY VALVE #3-3.5" GAS LIFT MNDRL 7827 2.92 / 5.968 13.02 DUMMY VALVE #2-3.5" GAS LIFT MNDRL 8437 2.92 / 5.968 12.99 DUMMY VALVE #1-3.5" GAS LIFT MNDRL 8938 2.92 / 5.968 13.03 DUMMY VALVE THIS NEEDS TO BE UPDATED FOR 3-43 FLUIDS PUMPED II B BLS. DESCRIPTION 135 MEOH ENDICOTF 3-43, 3.5" CT COMPLETION PAGE 4 Endicott Production Engineering Department OPERATIONS REPORT DATE: 05-11-94 WELL N°: 3-43 TYPE OF OPERATION: BP EXPLORATION REP: SERVICE COMPANY: POST CTU / COMPLETION WORK MCBRIDE CAMCO [ MARK ] DATE/TIME OPERATIONS SUMMARY 0700 TGSM; MIRU1 3/4" TOOLS. 0900 RIH w/3 1/2" GS. PULL 3 1/2" X SHEAR PLUG FROM 9704' WLM. POOH. 1030 RIH w/2.5" X10' STEM & TTL. SET DOWN IN STATION #4 @ 7065' WLM. TAP THRU. SET DOWN IN STATION # 3 @ 7780' WLM. TAP THRU. SET DOWN IN STATION #2 @ 8393' WLM. TAP THRU. SET DOWN IN STATION #1 @ 8894' WLM. TAG WLEG @ 9754' WLM. TAG PBTD @ 10376' WLM. POOH. 1200 RIH w/2.5" X 5' STEM. DRIFT TO 9800' WLM. POOH. 1300 RIH w/2 1/8" X 10' DUMMY GUN. TAG BTM. @ 10376' WLM. POOH. 1430 OOH. RIG DOWN. SIP= 0 PSI lAP= 0 PSI OAP= 0 PSI SUMMARY: THE BTM. FOUR STATIONS WERE FOUND TO BE TIGHT WITH A 2.5" X 10' DRIFT. THE DEPTHS WERE AS FOLLOWS: STATION #4 @ 7065' WLM; STATION #3 @ 7780' WLM; STATION #2 @ 8393' WLM; & STATION #1 @ 8894' WLM. TAG WLEG @ 9754' WLM. TAG PBTD @ 10376' WLM. PAG~ NO, COMPANY PE"dDHOE BAY DRILLING WELL NAME 3-43/P-36 LOCATION 1 DUCE IShqND UNIT LOCATION 2 SPI ~ENDICOTT MAGhETIC D[LINA?ION 30.01 ])ATE: 15-APR-94 WEE NUMBER 0 ~LL H~AD LOCATION= LAT(N/-S) DEP(E/-W) AZIMU?H FRt3M ROTARY ?ABL~ ?0 ?ARG~ IS 46,66. TIE IN POINT(TIP) : MEASURED DP'TH 450+00 ll~ ~RT D~F~H 450.00 INCLINATION 0.00 AZIMUTH 355.00 LATITUD~(N/-S) 0.00 DEPAEqlJRE(£/-W) 0.00 M~URt~ INTERVAL ~RTICAI. D£F~H D~PTH ft ft ft 450,00 0.0 45~9.LXi 605,34 155.3 6~,29 7~,~i ~,6 7~,71 7~,24 94,3 794,77 989,~ 194,7 At~I}RILL S~/E~ CALO]LATIONS CIRCULAR ARC TARG~ STATION AZIMUTH LATI1L~I~ SEL'TI~4 II~U,t. N/-S ft deo deo ft 0.00 0.00 255.(~) 0.00 2.36 2,62 1,10 3,55 6,19 3.52 11,70 8.60 11.03 5.32 354,10 15,79 24,31 7.64 357.47 37.71 D)~PARqlJRE DI~LACEMKNT at AZIMUTH E/-W ft ft dE~ 0,00 0,00 0,00 0+07 3.55 1,10 0,71 8,63 4.~.9 O.B4 15,81 3,06 -0,66 37.71 359,00 DLS deg/ 10Oft 0,00 1.68 1,12 2.36 1,21 1062,65 1175,05 1272,30 1369.77 1462,70 92,7 1060,04 ?2,4 1171.48 97,2 1267.66 97,5 1364,14 92,9 1456,16 32,03 8,16 354,82 50,42 -1,52 50,44 3"~,27 O..k8 3'7,72 8,44 253,40 63,68 -2,89 63,75 357.40 0.37 47,73 8.55 352,i4 77.93 -4.70 78.08 356.,55 0.23 55,64 7,80 35'5.38 91,71 -6,23 91,92 356,11 0,90 63,52 8,24 257,06 104.65 -7,08 104,89 356,13 0.53 1557,60 1651.95 1747,07 1842.73 1926,97 94,9 1550,23 94,4 1644,04 95,1 1738,77 95.7 1834,18 94.2 1928,34 70,96 6,86. 253,73 117,07 76,65 5,43 352.38 127,10 81,18 4,6? 349,10 135,55 84.74 3.34 251,58 142,30 66,78 1,41 248,14 146,15 -8,05 117,35 355.¢7 1,53 -9,25 127,44 355,84 1,52 -10,62 135,96 355.52 0,65 -ll,BO 142,79 355.26 1.63 -12,44 146,68 355.14 2,05 2033,30 2127,61 2223,83 2319,22 2415,67 96,3 2O24,65 94.3 2118,96 96,2 2215,18 ~.4 2310,56 96,5 2406,95 87,19 0,24 198,82 147,12 &6,69 0,72 173,27 146,34 &6,OS 0,75 166,05 145,12 &6,72 1,36 81,78 144,68 89.82 2,59 59,92 145,93 -12,74 147,67 355.05 1,67 -12,74 146.89 ~5.¢3 0.55 -12,51 145.~ 355.07 0,10 -11.24 145.11 355.56_ 1.56 -8,22 146,16 3~6,78 1,47 2424,16 2507,99 2599.84 26~.85 27'/~,43 8,5 2415,43 83.8 24~',13 91.9 2590.69 100,0 2690,24 id'.6 2789,23 ~,20 2,67 ~,34 146,13 -7,88 146,34 356.91 0,93 94,82 3,78 49,74 148,88 -4,08 148.93 358.43 1,50 102,10 5,30 41,19 154,02 1,03 1.54.03 0.28 1,81 111,61 5,72 40,52 161,29 7,30 161.45 2,59 0.43 122,10 6,58 36,98 169.61 13,96 170.19 4,70 0.94 2892,45 2988,01 3081,48 3177.96 3272,56 93,0 2881,54 95.6 2?76.08 93,5 3068,47 96.5 3163.91 94,6 3257,40 133,48 7.7I 39,~ 178,65 21,17 179,90 6.76 1,28 147,17 8,94 41,05 189,17 30,17 191,56 9.06 1,30 161,29 8,59 41,40 I99,89 3%56 203.76 11.19 0.38 175,23 8.18 ~?,97 210,56 48,73 216,12 ]3.C3 0.48 189,38 9,39 35,19 222,02 57.51 229.35 14.52 1.49 3354.I5 3462.53 35.50.14 3655,84 3751,14 91.6 3347,64 98,4 3444.62 97.6 2541,10 95,7 3635.79 95,3 3730.05 204,60 10,27 36.2! 234,72 220,78 9,07 38,24 247,89 235,44 8,42 41,62 259,27 249.14 8,29 36,94 270,03 262.82 8.67 34.45 281.44 66,63 243,99 15.a5 0.98 76.62 259.46 17.16 1,26 86.13 273,20 18.38 0.85 94.93 286.23 19,37 0.72 103,12 299.74 20,12 0.55 3846.50 ~41.48 4033.65 4132,15 4228,32 95,4 3824.38 95.0 3918.49 92.2 4009,87 98.5 4107.42 96,2 4202,57 276,45 8,12 41,34 292,42 289,27 7,46 48,17 301,57 301.25 7,61 45,93 309.81 314,91 8.28 43,07 319,52 328,82 8,45 42,17 329,81 111,63 313.00 20.89 1.20 120,66 224,81 21,81 1,19 129,50 335.78 22.69 0.~ 139,02 348,46 23.51 0,79 148,49 361.70 24,24 0,22 PA~E NO, 3 3-43/P-36 ~EA.SL~ED IN.,%'RVAL VB;,~ICAL DP'TH D~FTH ft ft ft 4318,98 90,7 4292,17 4417.5~ 98.6 4~9~ 4~6,~ ~9 4~5,82 4702,4~ 96, ~ 4670,84 ~ CALCULATIONS T~ET STATION AZIMU~ LATITUDE SECTION INCLN, N/-S $t d~. deg ft 342,52 9,11 39,90 340,25 3.56,02 9,30 37,15 352,59 372,~ 9.18 37,01 364.73 387,32 8,82 37,78 376,40 401,60 8,58 38,58 387,83 DEPARTURE DISF'LACEF~NT at AZIMUTH E/-W ft ft deq 157.57 374,97 24.85 167,38 390,~ 25,40 176,56 405.22 25,83 185.48 419,62 26,23 194.46 433.85 26.63 DL$ deo/ lOOft 0.82 0,48 0.12 0,41 0,28 4797,77 48F3.22 4989,~ 50~3.10 5177,49 ?5,4 476%16 95,5 4859,65 96.1 4954,77 93,8 5047,60 94,4 5141.00 415,35 8,25 39,17 398,69 428.71 8,11 37,64 409,34 441,97 8.08 37.05 420,10 455,12 8,40 36,50 430,87 468,43 8,20 36,52 441,82 203,22 447,50 27,01. 211,66. 460,83 27,34 219,87 474,16 27,63 227,92 487,44 27,86 236,03 500,91 28,11 0.36 0,27 0,09 0,34 0,20 5273,73 5370.48 5464.86 5560.85 5655.73 96,2 52~.,20 96,7 5331,85 94,4 5425,21 96,0 5520.20 94,9 5614.11 482,27 8,69 37,47 453,1I 496.46 8,52 37,62 464,59 510,09 8,40 37,87 475,57 523,70 8,20 38.13 486,49 537,02 8,21 39,10 497,07 244,54 514,89 28,36 253,36 529,18 28.61 261,~ 542,90 28,84 270.39 556.58 29,¢7 278,84 569,94 29,25' 0,53 0,18 0.13 0,22 0,15 5752.74 5848.44 5944,05 6036,19 6133,89 97,0 57.10,13 95,7 5804,88 ?5,6 ~,49 94,1 5992,63 ?5,7 6O87,36 550,58 8,11 38,.~ 507,80 563,82 8,06 38,25 518,35 577.41 8,52 39,97 529.04 590,97 8,19 42,70 539.31 604,36 8,00 42.~5 549,22 287,48 583,53 29.52 0.14 295.84 596.83 29~72 0.07 304,55 610.44 29.~3 0.54 313.57 623.85 30,17 0.55 322,70 637,01 3D,44 0,19 6229,t9 6324,71 6419,25 6513.90 6610,44 95,3 6181,77 ?5,5 6276,44 94,5 6370,04 94.7 6463,63 96,5 6559,08 617,43 7,82 46,51 558,56 630,20 7,55 49,71 567,09 643,48 8,61 51,49 575,51 657,59 8.56 52.3~ 584,23 671,96 8,60 53,07 592,96 331,90 649.72 30.72 0.59 341,40 661.92 31,C5 0,53 351,68 674.46. 31.43 1,15 362.80 .587.72 31,84 0,14 374,25 701.19 32,26 0.13 6706,18 6800,79 6896,80 6994,27 7088,60 95,7 66.53,71 94,6 6747,13 %,0 6841,88 97,5 6938,00 94,3 7031,04 686,56 8,98 51,75: 601,89 701,44 9,13 49,76 611,31 716,97 9,49 49,93 621.32 733,(79 9,55 49,7I 631,72 748,71 9.51 50,~ 641,74 385,84 714,94 32,66 397.37 729,11 33.03 409,24 743,9? 33.37 421,56 759,47 33.72 433,55 774,46 34,04 0.45 0,37 0.38 0,07 0,15 7184,44 7280.15 7374.90 7469,72 7504.83 95,8 7125,54 ?5,7 7219,95 94.7 7313,48 94,8 7407,16 35,1 7441.86 764,61 9.61 50,89 651,81 780,36 9.34 47,66 66.2,08 795.48 9,03 47,88 672.25 810,11 8,72 49.74 681.86 815.49 8,92 49,50 ,685.37 445,87 789.72 ~,37 457,81 804.95 34.66 469.00 819,68 Cq,90 480,01 833.89 35,14 4~4,11 839.10 35,24 0.12 0.63 0,33 0,44 0,58 7~3.94 7660,46 7756,06 7851,79 7947,20 59,1 7500,28 96,5 7595,67 ?5,6 7690,15 95,7 7784,67 ?5,4 7878,77 824,56 8,73 50,44 691,20 &q9,22 8.75 50,85 700,50 853,85 8,88 51,54 709,68 868,96 9,30 51,52 719.09 884,73 9,74 51..B0 728,88 491,06 847,88 35.39 0.40 502.40 862,04 35,65 0,06 513,81 876.16 35,90 0,17 525.65 890.73 36,17 0,45 538.03 905.95 36.43 0,46 F'A~E NO, 4 3-43/F'-~. ANAl)RILL ~.~.t~Y CALDJLATIO~ CIRCULAR ARC MBA.SURED INTEE~JAL V~H?ICAL TARGET STATION AZIMUTH LATITUI)£ DEPAR?LKd-'. DISPLACEMENT at AZIMUTH BLS I)EPTH ])EP?H S~-~'ION INCLN. N/-S £/-W deg/ ~t ft ft ft deg deo ft ft ft de~ lOOft 8042,78 95,6 7972,96 900,96 9,83 49,78 73~.15 550,62 921.70 36,68 0,37 8137,27 94,5 8065.98 917,53 10,43 43.09 750.60 562,62 938.05 36.85 1.39 8232,68 95,4 8159,79 934,79 10,54 42,B0 76.3,31 574,44 955,31 36.96 0.13 8326.22 93.5 8251,74 951,93 10,69 43,28 775,90 586,20 972,44 37.07 0.19 8422,59 96,4 8346,55 969,11 9,93 44,D3 768.,38 598,10 989.58 37.19 0.79 8519,43 96,8 8442,05 985,06 9,09 45.21 799.77 60"~'. 33 1005.45 37.30 0.90 6613,42 94.0 8534.88 999,82 9,03 44,34 810.26 619,75 1020,12 37,41 0,16 8706,87 95,4 8629,14 1014,76 9,02 45,25 820.90 630,30 1034,97 37,52 0,15 8801.43 9'2,6 8720,61 1026,86 8,55_ 45,23 630,85 640,34 1048,98 37,62 0,51 8896,46 97,0 8816,73 1042,17 7,25 45,05 840,26 649,7? 1062,20 37,72 1,33 8993,05 94,6 8910.56 I054,03 7,21 43.19 848,81 658,08 1074,03 37.79 0,25 9069,36 96,3 90~.,11 1066,03 7,18 42,56 857,65 666,29 108.6..05 37,84 0,09 9182,82 93,5 9098,83 1077,70 7,28 40,90 866,43 674,12 1097,78 37.88 0.25 9252,88 70,1 9166.34 I0&~.37 7,06 40.33 873,07 679,82 1106.53 37,91 0,31 9280,89 28,0 9196,14 1089,77 7,03 40,90 875,68 682,06 1109.97 37,~1 0,32 9375,07 94.2 9289,67 1100,67 6,43 36,92 &84,).4 689,14 1120,9~' 37.,93 0,68 9469,81 94,7 9'383,~ 1110.45 5+65 36+79 892,00 695.26 1130,95 37,93 0.86 9565,93 96,1 9479,58 1119,08 5.07 29,44 899,48 700,18 11~.88 37.90 0,93 9660,12 94,2 9573,49 1125,76 3.81 20.52 906,04 703,33 1146,99 37.82 1,52 9755,30 95,3 9668,59 1130,67 3,02 16,68 911o41 705,16 1152,35 37,73 0,~ 9850,17 94,8 9763,25 1134,36 2,59 6,26 915,93 706,11 1156,51 37.'.,K3 0.70 9946,58 96.4 9859,58 1137,36 2,34 3,98 920,06 706,48 1160,01 37,52 0.27 10040.41 93,8 9.753,33 1140,05 2,55 358.56 924,06 706,56 1163.23 37.40 0.33 10136,36 95,9 10049,18 1142,65 2.53 354,56 928,30 706,31 11.66.,45 37,27 0.19 10230,~ 94,3 10143,35 1145,25 2,74 356,69 932,62 705,98 1169,70 37.13 0.24 10279,54 48,9 10192,20 1146,67 2,67 356,99 934.92 705,85 1171,46 37,05 0,14 THI~ FINAL SUR'UI~Y IS A ~J~ZII~D SURVE~ DNLY, 10358,00 78,5 10270,58 1148,92 2.67 356.99 938,57 705../'6. 1174,25 36.94 0.00 BP EXPLORATION 3-43/P-36 500292241600 ENDICOTT COMPUTATION DATE: SPERRY-SUNANCHORAGE DRILLING ALASKA SERVICES ~ '~ / ~ / ~/~'~L PAGE 4/25/94 DATE OF SURVEY: 041994 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-40036 KELLY BUSHING ELEV. = 55.85 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST 2691 2682.00 2626.15 5 18 N 39.90 E .00 165.00N 7.00E 2764 2754.67 2698.82 5 31 N 41.49 E .37 170.22N 11.49E 2859 2849.13 2793.28 6 42 N 40.64 E 1.25 177.85N 18.13E 2954 2943.33 2887.48 8 8 N 41.29 E 1.51 187.12N 26.18E 3049 3037.29 2981.44 8 48 N 46.17 E 1.03 197.21N 35.87E VERT. SECT. 113.83 120.64 130.66 142.82 156.76 3144 3131.25 3075.40 8 6 N 42.49 E .93 207.18N 45.64E 3239 3225.28 3169.43 8 19 N 37.87 E .73 217.55N 54.39E 3334 3319.01 3263.16 10 19 N 35.33 E 2.15 229.92N 63.53E 3429 3412.53 3356.68 9 52 N 37.81 E .65 243.30N 73.45E 3524 3506.34 3450.49 8 16 N 40.36 E 1.74 254.95N 82.87E 170.68 184.09 199.11 215.38 230.14 3619 3600.37 3544.52 8 2 N 40.39 E .24 265.22N 91.60E 3714 3694.37 3638.52 8 38 N 34.53 E 1.09 276.16N 99.95E 3809 3788.31 3732.46 8 26 N 35.90 E .30 287.68N 108.09E 3904 3882.38 3826.52 7 40 N 48.97 E 2.09 297.50N 116.96E 3999 3976.57 3920.72 7 15 N 49.78 E .45 305.53N 126.32E 243.47 256.96 270.67 283.80 296.14 4094 4070.77 4014.92 7 39 N 44.59 E .82 313.91N 135.34E 4189 4164.85 4109.00 8 14 N 44.88 E .61 323.23N 144.58E 4284 4258.84 4202.99 8 29 N 43.50 E .34 333.14N 154.21E 4319 4293.46 4237.61 8 29 N 43.50 E .00 336.88N 157.76E 308.45 321.54 335.31 340.45 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 372.00 FEET AT NORTH 25 DEG. 5 MIN. EAST AT MD = 4319 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 48.86 DEG. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 BP EXPLORATION 3-43/P-36 500292241600 ENDICOTT COMPUTATION DATE: 4/25/94 DATE OF SURVEY: 041994 JOB NUMBER: AK-EI-40036 KELLY BUSHING ELEV. = 55.85 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 2691 2682.00 2626.15 3691 3671.63 3615.78 4319 4293.46 4237.61 TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 165.00 N 7.00 E 9.00 273.31 N 97.99 E 19.37 10.37 336.88 N 157.76 E 25.54 6.17 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION 3-43/P-36 500292241600 ENDICOTT COMPUTATION DATE: 4/25/94 DATE OF SURVEY: 041994 JOB NUMBER: AK-EI-40036 KELLY BUSHING ELEV. = 55.85 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 2691 2682.00 2626.15 165.00 N 7.00 E 9.00 2765 2755.85 2700.00 170.30 N 11.57 E 9.33 .33 2865 2855.85 2800.00 178.45 N 18.65 E 9.92 .59 2966 2955.85 2900.00 188.46 N 27.37 E 10.80 .89 3067 3055.85 3000.00 199.20 N 37.95 E 11.94 1.13 3168 3155.85 3100.00 209.77 N 48.01 E 13.00 1.06 3269 3255.85 3200.00 221.08 N 57.13 E 14.05 1.05 3371 3355.85 3300.00 235.39 N 67.41 E 15.60 1.55 3472 3455.85 3400.00 249.22 N 78.05 E 17.11 1.51 3574 3555.85 3500.00 260.42 N 87.52 E 18.18 1.07 3675 3655.85 3600.00 271.33 N 96.63 E 19.19 1.01 3776 3755.85 3700.00 283.78 N 105.26 E 20.33 1.14 3877 3855.85 3800.00 295.15 N 114.26 E 21.39 1.06 3978 3955.85 3900.00 303.83 N 124.31 E 22.26 .88 4078 4055.85 4000.00 312.48 N 133.94 E 23.10 .84 4179 4155.85 4100.00 322.31 N 143.66 E 24.05 .95 4280 4255.85 4200.00 332.81 N 153.90 E 25.12 1.07 4311 4285.55 4229.70 336.03 N 156.95 E 25.45 .33 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 1 June 1994 Transmittal of Data Sent by: ANCHORAGE XPRES Dear Sir/Madam, Enclosed, please find the data as described below: WELL 3-43/P-36 (SDI) DESCRIPTION 2-04/M-19 j 1 PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Received by: ECC No. Run # 1 6192.03 Run # 1 Run ~ 1 5985.08 Run # 1 Date: Please sign and return to: Petrotechnical Data Center BP Exploration (Alaska) Inc 900 East Benson Boulevard Anchorage, Alaska 99508 Received by Date ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 16 May 1994 RE: Transmittal of Data ECC #: 6192.00 Sent by: ANCHORAGE XPRES Data: LDWG Dear Sir/Madam, Reference: BP . 3-43/P-36 (SDI) ENDICOTT NORTH SLOPE, AK Enclosed, please find the data as described below: Tapes/Diskettes: 1 DIFL LDWG TAPE+LISTR Run # 1 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: Petrotechnical Data Center BP Exploration (Alaska) Inc 900 East Benson Boulevard Anchorage, Alaska 99908 Received by Date ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 11 May 1994 RE: Transmittal of Data Sent by: ANCHORAGE XPRES Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION 3-43/P-36 (SDI) 3-43/P-36 (SDI) /SBT/ R/CC . FINAL 1 SBT/GR/CCL RF SEPIA · PFC/GR/CCL FINAL BL J 1 PFC/GR/CCL RF SEPIA ECC No. Run # 1 6192.01 Run # 1 S-31 i.-/PL INJPROF. FINAL BL PL INJPROF. RF SEPIA Run ~ 1 6192.02 Run ~ 1 D-11 Run # 1 5188.01 Run # 1 A-9 B-12 1 PL GASENTRY FINAL BL' Run ~ 1 PL GASENTRY RF SEPIA Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 X-29 (21-12-10-13) /PFC/GR/CCL FINAL BL PFC/GR/CCL RF SEPIA ~ CN/GR FINAL BL 1 CN/GR FINAL RF SEPIA Run # 1 Run # 1 C-29 ~ PL STATIC FINAL BL //1 PL STATIC RF SEPIA B-21 (12-31-11-14) ~ CN/GR FINAL BL Run # 1 1 CN/GR FINAL RF SEPIA Run # 1 Run # 1 Run # 1 Cont/ ,1.~ CN/GR FINAL BL ~/1 CN/GR FINAL RF SEPIA 5617.06 5694.03 5791.02 6139.04 2352.02 5718.04 JJaska Oil & Gas Cons. Commission Anchorage ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 3 May 1994 RE: Transmittal of Data ECC #: 6192.00 Sent by: U.S. MAIL Data: LDWG Dear Sir/Madam, Reference: BP 3-43/P-36 (SDI) ENDICOTT NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: Prints/Films: 1 DIFL/GR/SP FINAL BL 1 ZDL/CN/GR FINAL BL 1 FMT/GR FINAL BL 1 SSVD/SSDS FINAL BL 1 BHPF FINAL BL 1 ~D~IFL/GR/SP RF SEPIA 1 -'~DL/CN/GR RF SEPIA 1 ~MT/GR RF SEPIA 1 fSSVD/SSDS RF SEPIA 1 ~PF RF SEPIA Please ~£gn and return to: Atla~ Wirel£ne Service~ 5600 B Street Su£te 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Run # 1 Run # 1 Run # 1 Run # 1 Run ~ 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 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: ALASKA OIL AND GAS CONSERVATION COMMISSION November 9, 1993 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Michael Zanghi Drilling Engineer Supervisor BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Duck Island Unit/Endicott 3-43/P-36 BP Exploration (Alaska), Inc. Permit No: 93-170 Sur. Loc. 2777'NSL, 640'WEL, Sec. 8, TllN, R17E, UM Btmhole Loc. 3679'NSL, 5180'WEL, Sec. 9, TllN, R17E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David W. '~°hnst°n~~ Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 Re-Entry [] Deepen131 Service [] Development Gas [] Single Zone [] Multiple Zone[] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration BKB=56 feet Endicott Field/Endicott Pool 3. Address 6. Property Designation P. 0. Box 196612, Anchorage, Alaska 99519-6612 ADL 47503 4. Location of well at surface 7. Unit or property Name 11. Type Bond(me 2o ^^c 25.02,5) 2777'NSL, 640' WEL, SEC. 8, T11N, R17E Duck Island Unit/Endicott At top of productive interval 8. Well number Number 3679'NSL, 5180' WEL, SEC. 9, T11N, R17E 3-43/P-36 2S100302630-277 At total depth 9. Approximate spud date Amount 3679' NSL, 5180' WEL, SEC. 9, T11N, R17E 11/12/93 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth(UDandTVD) property line ADL 47502-99' feet 3-45/M-39-10'@ 190'MD feet 2560 10469'MD/10289' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 KicKott depth 5000 feet Maximum hole angle 26.43) Maximum surface 3900 psig At total depth (TVD) 10000Y4890 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length M D TVD MD TVD (include stage data) 30" Struct. Drive Pipe 94' 37' 37' 131' Drive 13-1/2" 10-3/4" 45.5~ NT80 BTC 2713' 37' 37' 2750' 2750' 460SX"E"/375SX"C"/250SX"C" 9-7/8" 7-5/8" 29.7# NT-95 NSCC 10065' 36' 36' 10101' 9921' 600 sx Class "G" 6-3/4" 5-1/2" 17# 13CR NSCC 554 9915' 9735' 10469' 10289' 120 sx Class "G" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor RECEIVED Surface Intermediate 007'2 9 199,:3 Production Liner Alaska 0ii & Gas Cons. Perforation depth: measured Anchorage true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis[] Seabed reportl-I 20 AAC 25.050 requirements[] 21. I hereby certify that tl3e fo. regoin, g is true and correct to the best of my knowledge Signed \. Title Drilling Engineer Supervisor ~ · , Commission Use Only -" Permit Number IAPI number IAp/p.;oval~at,_e~ ..~ See cover letter ~- /.~ J50- C, ~_. ~- ..Z. ~/---TZ/E~~ // / ___..." for other requirements Conditions of approval Samples required [] Yes .1~ No Mud Icg required []Yes [] No Hydrogen sulfide measures [] Yes ,IZ] No Directional survey required ~ Yes [] No Required working pressure for BOPE []2M; 1-13M; ~5M; I-IIOM; I-i15M; Other: Original Signed By by order of Approved by David W. Johnston Commissioner me commission Date/'//f/,~.,~ Form 10-401 Rev. 12-1-85 Submit SDI 3-43/P-36 WELL PLAN SUMMARY SURFACE LOCATION: 2777' FSL 640' FEL SEC 8 T1 1N R17E UM TARGET LOCATION: 3679' FSL 51 80' FEL SEC 9 T11N R17E UM BOTTOM HOLE LOCATION: 3679' FSL 5180' FEL SEC 9 T1 1N R17E UM TOTAL DEPTH: 10469' MD/10289' TVD ESTIMATED SPUD DATE: 1 1/12/93 CONTRACTOR: ELEVATIONS: PAD: 1 O' Pad TO RKB: 46' RKB: 56' DOYON Rig 1 5 DIRECTIONAL INFORMATION: KOP: 5000 DIRECTION: BUILD RATE: 2°/100' EOB: AVG ANGLE 26.43° DROP DEPTH: 7395'TVD/7537' MD EOD: DROP RATE: 1.5°/1 00' AVG ANGLE VERTICAL (0°) DEP at TD: 41.76° 6090'TVD/8121' MD 8856'TVD/9036'MD 1165' FORMATIONS MD TVD BKB Permafrost 1471 1471 SURFACE CSG PT 2750 2750 TOP TUFFS 91 96 9016 TOP HRZ 9776 9596 TOP PUT RIVER 1001 9 9839 TOP ITKILYARIAK 1 0061 9881 7-5/8" CSG PT 10101 9921 EST GOC 10106 9926 TOP KEKIKTUK (ZONE 3C) 10111 9931 TARGET 10284 10104 TOP ZONE 3B 10346 10166 EST OWC 10431 10251 TD 10469 10289 Alaska 0ii & Gas fio~]s. ~;ommissiot; Anchorage CASING PROGRAM 1. The exact 7-5/8" casing point will be determined on location by the onsite geologist and the dg team. Bit Size Casing Size Weight Grade Connection Top Bottom Length Driven 30" Struct. WELD Preset Preset 13-1/2" 10 3/4" 45.5# NT-80 BTC 37 2750 2713 9-7/8" 7 5/8" 29.7# NT-95 NSCC 36 10101 10065 6-3/4" 5-1/2" 17# 13-CR NSCC 991 5 10469 554 MWD/OPEN HOLE LOGGING PROGRAM 1. 13-1/2" hole & 9-7/8" hole: MWD Directional 2. 6-3/4" hole: Run #1 DLL/MSFL/GR Run #2 LDT/CNL/GR Run #3 RFT (10-1 5 points) CASED HOLE LOGGING PROGRAM 1. SST from TD to TOC in 7 5/8" casing. 2. GYRO: PSTD to surface. COMPLETION PROGRAM 1. 3-1/2" coiled tubing completion to be run after rig is released. 2. Six Gas Lift Mandrels. (Gaslift design will be determined after OH logs). SPUD MUD PROPERTIES Weight Marsh Vis Yield Pt. 10 sec gel 10 rain gel p__I_H APl F.L. Hardness Spud 8.7 300 40-60 30-60 60-80 9-10 15-25 <200 Csg Pt. 9.5 1 O0 20-40 15-20 20-30 9-10 15-25 <200 INTERMEDIATE HOLE MUD PROPERTIE~; Depth Weioht Y._~P 1 0 sec Gel 10 rain Gel APl F.L. laJ:[ Hardness to TUFFS 9.5 - 9.8 15 - 25 12- 15 25- 30 <12 9.5 - 10.0 < 200 to TD 9.8 - 10.5 20 - 30 12 - 15 25 - 30 6.0 - 8.0 9.5 - 10.0 < 200 At the top of the Tuffs, the fluid loss should be controled by the addition of Drispac SL, Resinex, and/or lignite. Polymer sweeps utilizing Biozan should be incorporated into the mud system to improve Iow shear rate rheology. PRODUCTION HOLE MUD PROPERTIES Depth Weight Y__~P 10 sec Gel 10 min Gel APl F.L. p_~ Hardness to TD 9.2-9.4 15 - 25 12 - 15 25 - 30 <8 9.5 - 10.0 < 200 The intermediate hole mud should be watered back to build the production hole mud. The fluid loss should be controlled with Drispac. Polymer sweeps utilizing Biozan should be incorporated into the mud system to improve Iow shear rate rheology. aCT o!~ "~ ,,~iaska Oil a Gas Cons. Anchorage CEMENT PROGRAM -HALLIBURTON 1 0-3/4" SURFACE CASING CASING SIZE: 10-3/4", 45.5# CIRC. TEMP: 40°F LEAD CEMENT TYPE; Type 'E' Permafrost ADDITIVES: retarder WEIGHT: 12.0 ppg YIELD: 2.17 ft/sx gps APPROX. SACKS: 460 THICKENING TIME: 5+ hrs MIX WATER: 11.63 TAIL CEMENT TYPE: Premium ADDITIVES: 2% Calcium Chloride WEIGHT: 15.8 ppg YIELD: 1.15 ft3/sx 5.00 gps APPROX. SACKS: 375 THICKENING TIME: 4 hrs MIX WATER: TOP JOB CEMENT TYPE: Type 'C' Permafrost ADDITIVES: retarder WEIGHT: 15.6 ppg YIELD: 0.94 ft3/sx MIX WATER: 3.5 gps APPROX. SACKS: 250 ~ 100 bbls fresh water ahead of lead slurry. The mixing temperature should be as cold as possible to prevent acceleration-approximately 40 - 45 F. CEMENT VOLUME 1. Lead slurry + 375 sx Tail slurry w/40% excess over gauge hole. 2. Top job volume 250 sx. 7 5/8" INTERMEDIATE CASING_ CASING SIZE: 7 5/8", 29.7# CIRC. TEMP 135°F LEAD CEMENT TYPE: Premium ADDITIVES: 0.5% CFR-3 (Dispersant) + 3% Econolite (Extender) + 0.4% Halad-344 (Fluid Loss) WEIGHT: 11.0 ppg YIELD: 3.24 ft3/sx 20.4 gps APPROX. SACKS: 400 PUMP TIME: 5+hrs TAIL CEMENT TYPE: Premium ADDITIVES: 0.2% CFR-3 (Dispersant) + 0.2% Halad-344 (Fluid Loss) + HR-5 (Retarder) WEIGHT: 15.8 ppg YIELD: 1.15 ft3/sx 5.0 gps SACKS: 200 PUMP TIME: 4 hrs Retarder (HR-5) concentration will be based on actual lab tests. SPACERS: Pump 20 bbls Sea Water; 50 bbls ARCO spacer @ 11 ppg. OTHER CONSIDERATIONS: Continuously mix lead and tail slurries. Displace at 12-15 bpm with rig pumps. CEMENT VOLUME 1. Lead Slurry based 90% of hole volume to surface casing shoe. 2. Tail Slurry to 750' above shoe w/30% excess + 80 ft. shoe. MIX WATER: MIX WATER: 5-1/2" LINER CASING SIZE: 5-1/2", 17# CR-13 CIR(;. TEMP: 140° F CEMENT TYPE: Premium ADDITIVES: 0.2% CFR-3 (Dispersant) + 0.5% Halad-344 (Fluid Loss) + HR-5 (Retarder) Retarder (HR-5) concentration to be based on actual lab tests. WEIGHT: 15.8 ppg YIELD: 1.15 ft3/sx MIX WATER: 5.00 gps APPROX. SACKS: 120 THICKENING TIME: 3 hfs + 1 hour @ surface SPACERS: 20 bbls Sea Water 50 bbls ARCO spacer, weighted 1 ppg above MW. 20 bbls Fresh Water 20 bbls Super Flush 20 bbls Fresh Water OTHER CONSIDERATIONS; Batch mix the cement slurry. Perform fluid loss test on the batch mixed slurry. Fluid loss should be 40cc to 60cc/30 mins. Displace @ 8-10 bpm. LINER CEMENT VOLUME 1. Open hole (6-3/4" X 5-1/2") annulus + 50% excess. 2. 5-1/2" 17# casing capacity below landing collar (80 feet). 3. 150' liner lap (7 5/8" x 5-1/2" liner) 4. 200' of cement on top of the liner in the 7-5/8" casing (without DP in hole). 0 CT 9 199; Aiaska Oil & Gas Cons, (;0rnrnissiu'; Anchorage WELL 3-43/P-36(SDI) PROPOSED DRILLING AND COMPLETION PROGRAM Objective Well 4-38/P-36 will be drilled from the Endicott SDI to produce reserves in the Kekiktuk formation. The well will be completed with a 3-1/2" coiled tubing completion. The cost estimate includes the associated coiled tubing running costs and accessories. Operation Execute a rig move and rig-up. Directionally drill surface hole with a 8.5 - 9.5 ppg mud system to proposed depth. Run and cement lo-3/4" 45.5#/ft NT- 80 buttress casing to surface. Pressure test casing. Install BOPE. Drill out casing and 5 ft. of new hole and conduct a formation leak-off test. Directionally drill 9-7/8" hole with a 9.0 - 10.2 ppg mud system to casing point above the Kekiktuk formation. Run and cement 7-5/8" 29.7#/ft., NT95HS, NSCC casing. No abnormal pressures are expected in the 9-7/8" hole section. Drill 6-3/4" hole to TD. Run open hole logs. Run and cement 5-1/2" liner. Clean ont liner and displace to brine. Pressure test casing. Nipple up dry hole tree and release Rig. Run SBT/GR/CCL/gyro in the 5-1/2" liner and 7-5/8" casing. Complete well with coiled tubing assembly. A subsurface safety valve will be installed below base of permafrost. Fluids incidental to the drilling of the well will be pumped down the 10-3/4" by 7-5/8" annulus of the well. The 10-3/4" x 7-5/8" annulus will be freeze protected with a non-freezing fluid down to 3000 feet once the rig is released. JLH 8/18/93 Atask~ Oil & Gas Cons. Anchorage PRUDHOE BAY DRILLING A,~4arkerlden[ificati°nKB ~4Do"'~o ~'~o,, 3-43/P-36 (P2) ~1 C) ENO ~.5/]00 BUILD 940 24 8 PLAN VlEN B) BROP ~/~00 J490 84 27 E) END ~/~00 DROP 2~50 ~20 39 CLOSURE · ~65 fee[ a( Az~mu[h 39.25 F) BUZLD 2.0/~00 5000 ~20 39 G) END OF 2/]00 BUILD 6~25 283 ~84 DECLINATION.' 30.000 E H) DROP ~.5/]00 7537 686 544 SCALE · ~ inch = 200 fee~ I) END OF ~.5/~00 DROP 9036 903 738 J) CASING POINT ~O~OJ 903 738 DRAWN · ~0/20/93 K) TARGET ~0284 903 738 L) TB ~0469 903 738 Schlumberger AnadrJ ]] 1100-- ~oo- _ I ] ( 800- - i - 700- - [ , 6oo-- I I 500-- 400 300-- / ~'~L ~'~- ~"' ~ . o Alaska gl & Gas]ohs. Uo~mmss~u' Z . · - o a , ~ , Anch}ra~e ~ I 6 ~oo I 100 0 100 200 300 ~00 ~00 [00 700 800 ~00 ~000 ~ ~00 ~200 1~00 <- ~[SI ' [~SI -> . . (Anadrill (c)93 343P36P2 B1.5~ 3:40 PI41 PRUBHOE BAY BRILLING VERTICAL SECTION VIEW I i Section al: 41.76 c-- TVD Scale.' I inch = ~200 fee( o-- , Rep Scs]e.' ~ inch = ~200 feet I Brawn · ~0/20/93 0 -- 0-- ! Schlumberger Anadri ]] E-- I ! Marker Identification MD BKB SECTN INCLN D-- A) KB 0 0 0 0.00 B) NUDGE KOP ~.5/100 500 500 0 0.00 , C) END I.§/100 BUILD 940 g39 23 6.60 3-- ~ D) DROP 1/100 1490 ~485 81 6 60 i · E) END 1/lO0 DROP 2150 2144 1~6 0.00 ~) BUI~D2.0/~oo ~000 4s94 ~6 0.00 i ~ ~) E,D O~ ~/~00 BUILD 6~2~ 6090 334 22.49 ~-- I I ,) 0~0~ 1.5/~00 ~3~ ~3S~ S~4 22.49 I I ~) E,oo~ 1.~/looo,o~ so~6 ss~6 ~16~ 0.00 ~) CASI~a ~OIm lOlO1 S921 1165 0.00 )__ ~ I K) T~aGE~ 102S4 lOl04 1165 0.00 I, L) TD 10469 10289 1165 0.00 ) , >-- I I i -TOP TUFFS 9016 -~ ..... ~ ~ m ~ ~ ~ I -- TOP HRZ S596 m ~ ~ , + .; .... Alaska Oil ~ Gas Go,is. Gorm~issm'* ~5~ ~-~ ............. r~ ~ .... ~ ................ -~200 -600 0 600 1200 i800 2400 3000 3600 4200 4800 5400 6000 6600 Section Beparture (Anadri]] (c}93 343P36P2 8~.5~ 3:38 ** CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE ( 1 ) Fee /~ ~p~..2_.~ [2 thru 8] [10 & 13] (4) Casg [14 thru 22 (5) BOPE [23 thru YES 1. 2. 3. S' A 6. Is well to be deviated & is wellbore plat included ................... ~ 7. Is operator the only affected party .................................. ~/~ 8. Can permit be approved before 15-day wait ............................ ~. Lease & Wel 1 ~~ ~zZ~c::)~ * NO · 10. 11. 12. 13. 14. 15. Is permit fee attached ............................................... Is well to be located in a defined pool .............................. Is well located proper distance from property line ................... Is well located proper distance from other wells ..................... Is sufficient undo. dicated acreage available in this pool ............. REMARKS 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. [29 thru' 31] 30. 31. (7) ContactL _I'-A~'~F32~'~~' ~ 32. (8) Addl 33. Does operator have a bond in force ................................... Is a conservation order needed ........................ . ............... I s admi n i st rat i ve approval needed .................................... Is lease nL~nber appropriate .......................................... Does well have a unique name & n~nber ................................ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface $ intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter $ BOPE attached .... Does BOPE have sufficient pressure rating -- test to i~C:) psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... FOR EXPLORATORY $ STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone nLrnber of contact to supply weekly progress data ...... Additional requirements ............................................. geology' eng i neet i nq' ' TAB rev 6/93 jo/6.011 INITIAL GEOL UNIT ON/OFF ... POOL CLASS STATUS AREA ~ SHORE Additional remarks' MERIDIAN' UM;~ WELL TYPE' Exp~. ~ Inj. SM Redrill Rev Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simPlify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : BP EXPLORATION (ALASKA), INC. WELL NAME : 03-43/P-36 FIELD NAME : ENDICOTT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292241600 REFERENCE NO : 98577 lO-NOV-1998 10:55 PAGE: 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/11/10 ORIGIN : FLIC REEL NAFiE : 98577 CONTINUATION # : PREVIOUS REEL : CO~fENT : BP EXPLORATION, 3-43/P-36, ENDICOTT, API# 50-029-22416-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/11/10 ORIGIN : FLIC TAPE NAME : 98577 CONTINUATION # : 1 PREVIOUS TAPE : COf~4~NT · BP EXPLORATION, 3-43/P-36, E1VDICOTT, API# 50-029-22416-00 TAPE HEADER Endicott CASED HOLE WIRELINE LOGS WELL NAME: 03-43/P-36 API NUMBER: 500292241600 OPERATOR: BP Exploration (Alaska), Inc. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 9-NOV-98 JOB NUMBER: 98577 LOGGING ENGINEER: Carl o A. Yon OPERATOR WITNESS: Don Barba SURFACE LOCATION SECTION '. 8 TOWNSHIP '. I iN RANGE: 17E FNL : FSL: 2777 FEL: 640 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 58.85 DERRICK FLOOR: 58.85 GROUND LEVEL: 14.50 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) lST STRING 9. 875 7. 625 10558.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (M~ASURED DEPTH) LI.S Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:55 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: DIL LDWG CURVE CODE: GR RUN NUPIBER : PASS NUMBER: DATE LOGGED: 28-APR-94 LOGGING COMPANY: ATLAS BASELINE DEPTH .............. 88888.0 10334.5 10330.5 10323.0 10321.5 10320.5 10312.0 10310.5 10310.0 10306.0 10304.5 10301.5 10297.0 10291.0 10289.0 10287.5 10273.5 10263.5 10246.0 10241.5 10239.0 10238.0 10234.0 10233.0 10229.0 10224.0 10223.0 10221.0 10208.0 10204.5 10203.5 10194.5 10192.5 10186.5 10180.5 10179.5 10178.5 10168.0 10167.0 10165.5 10162.5 10161.5 10159.0 10152.5 10136.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST 88889.0 88890.0 10335.5 10331.5 10325.0 10322.0 10322.0 10313.0 10312.5 10310.0 10307.5 10307.0 10302.5 10299.0 10292.5 10290.0 10290.0 10276.0 10265.5 10247.0 10242.0 10240.0 10240.0 10234.5 10234.5 10230.0 10230.5 10225.0 10225.0 10221.5 10209.5 10205.5 10205.5 10195.5 10195.5 10194.0 10188.5 10182.5 10180.5 10180.5 10170.0 10168.0 10168.0 10164.5 10164.5 10161.0 10155.0 10139.0 PAGE: LI~S Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:55 10133.0 10134.0 10131.5 10133.5 10129.0 10131.0 10114.0 10115.0 10113.0 10115.0 10108.0 10110.0 10110.5 10104.5 10105.5 10087.0 10089.0 10081.0 10082.5 10076.0 10077.5 10070.5 10072.0 10069.0 10072.0 10061.0 10062.0 10059.0 10059.5 10057.0 10059.5 10055.0 10057.5 10039.5 10042.5 10038.5 10040.5 10035.5 10038.0 10029.5 10031.0 10028.5 10031.0 10012.5 10014.0 10011.5 10013.5 10008.0 10010.5 10010.5 10005.0 10006.0 10004.5 10006.5 10001.5 10003.0 9998.5 10000.0 9996.5 9998.5 9987.0 9988.5 9986.5 9988.5 9979.5 9981.0 9979.0 9981.0 9971.0 9971.5 9970.5 9971.5 9968.0 9969.0 9966.5 9969.0 9958.0 9960.0 9956.5 9956.5 9953.5 9953.5 9925.5 9927.0 9922.0 9922.5 9913.0 9915.5 9912.0 9913.5 9911.0 9913.5 9910.5 9911.5 9909.0 9910.0 9898.5 9900.0 9894.5 9895.5 9891.0 9890.5 9882.5 9884.0 9881.0 9883.5 100.0 101.5 102.5 $ PAGE: REMARKS: CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE RST LI.S Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:55 DATA AQUIRED ON BP EXPLORATION'S 3-43/P-36 WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #1 AND THE DIL GAI~A RAY, ALSO BASE PASS #1 SIGMA AND THE DIL GAi~FZA RAY, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ $ PA GE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION ' O01CO1 DATE : 98/11/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INC~: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10341 . 0 9875.5 RST 10353 . 0 9876.5 $ CURVE SHIFT DATA - PASS TO PASS (14EASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH .............. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST REMARKS: THIS FILE CONTAINS CASED HOLE RST BASE PASS #1. THERE ARE NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:55 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1239886 O0 000 O0 0 1 1 1 4 68 0000000000 NBAC RST CPS 1239886 O0 000 O0 0 1 1 1 4 68 0000000000 FBAC RST CPS 1239886 O0 000 O0 0 1 1 1 4 68 0000000000 SBNA FIL CU 1239886 O0 000 O0 0 1 1 1 4 68 0000000000 SFNA FIL CU 1239886 O0 000 O0 0 1 1 1 4 68 0000000000 SBFA FIL CU 1239886 O0 000 O0 0 1 1 1 4 68 0000000000 SFFA FIL CU 1239886 O0 000 O0 0 1 1 1 4 68 0000000000 TRAT FIL 1239886 O0 000 O0 0 1 1 1 4 68 0000000000 IRAT FIL 1239886 O0 000 O0 0 1 1 1 4 68 0000000000 CIRNFIL 1239886 O0 000 O0 0 1 1 1 4 68 0000000000 CIRF FIL 1239886 O0 000 O0 0 1 1 1 4 68 0000000000 BSAL RST PPK 1239886 O0 000 O0 0 1 1 1 4 68 0000000000 SIBF RST CU 1239886 O0 000 O0 0 1 1 1 4 68 0000000000 TPHI RST PU-S 1239886 O0 000 O0 0 1 1 1 4 68 0000000000 SFFC RST CU 1239886 O0 000 O0 0 1 1 1 4 68 0000000000 SFNC RST CU 1239886 O0 000 O0 0 1 1 1 4 68 0000000000 SIGMRST CU 1239886 O0 000 O0 0 1 1 1 4 68 0000000000 DSIG RST CU 1239886 O0 000 O0 0 1 1 1 4 68 0000000000 FBEF RST UA 1239886 O0 000 O0 0 1 1 1 4 68 0000000000 CRRARST 1239886 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH RST GAPI 1239886 O0 000 O0 0 1 1 1 4 68 0000000000 TENS RST LB 1239886 O0 000 O0 0 1 1 1 4 68 0000000000 CCL RST V 1239886 O0 000 O0 0 1 1 1 4 68 0000000000 LI.S Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:55 PAGE: ** DATA ** DEPT. 10353.000 NBAC.RST SFNA.FIL 34.825 SBFA.FIL IRAT. FIL 0.516 CIRN. FIL SIBF. RST 35.804 TPHI.RST SIGM. RST 30.908 DSIG.RST GRCH. RST -999.250 TENS.RST DEPT. 9875.500 NBAC.RST SFNA.FIL -999.250 SBFA.FIL IRAT. FIL -999.250 CIRN. FIL SIBF. RST -999.250 TPHI.RST SIGM. RST -999.250 DSIG.RST GRCH.RST 144.906 TENS.RST 2310.479 FBAC.RST 48.176 SFFA.FIL 0.713 CIRF. FIL 34.112 SFFC.RST 1.723 FBEF. RST 1297.000 CCL.RST -999.250 FBAC.RST -999.250 SFFA.FIL -999.250 CIRF. FIL -999.250 SFFC.RST -999.250 FBEF.RST -999.250 CCL.RST 3283.779 SBNA.FIL 33.402 TRAT. FIL 1.254 BSAL.RST 31.256 SFNC.RST 35.855 CRRA.RST 0.000 -999.250 SBNA.FIL -999.250 TRAT. FIL -999.250 BSAL.RST -999.250 SFNC.RST -999.250 CRRA.RST -999.250 50.340 1.108 39.005 33.016 1.985 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE ·FLIC VERSION ·O01CO1 DATE · 98/11/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE H~ER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SURff~ARY LDWG TOOL CODE START DEPTH ........................ GRCH 10341.5 RST 10353.0 STOP DEPTH .......... 9881.5 9883.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:55 PAGE: $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH .............. 88888.0 10337.5 10331.0 10327.5 10324.5 10323.0 10318.5 10315.5 10314.0 10305.0 10304.5 10297.5 10289.0 10287.5 10273.5 10263.5 10256.0 10246.0 10243.0 10242.5 10239.0 10234.5 10228.5 10224.0 10223.0 10219.5 10212.0 10208.0 10204.5 10203.5 10195.0 10194.5 10192.5 10187.0 10180.5 10179 5 10172 5 10168 0 10167 0 10163 5 10161 5 10159 0 10154 0 10152 5 10146.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST .............. 88889.5 10339.0 10332.0 10325.5 10323.5 10315.0 10307.5 10299.5 10290.0 10274.5 10258.0 10246.5 10243.5 10240.0 10234.5 10225.0 10205.5 10196.0 10188.0 10180.5 10174.5 10168.0 10164.5 10161.0 10156.5 88890.0 10329.5 10325.0 10320.0 10317.5 10307.0 10290.0 10276.0 10265.5 10245.0 10230.0 10225.0 10221.5 10214.0 10209.5 10205.5 10195.5 10194.0 10182.5 10170.0 10164.5 10155.0 10148.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:55 PAGE: 10142.5 10138.0 10136.5 10131.5 10129.5 10128 5 10123 0 10118 0 10114 0 10113 0 10108 0 10107 5 10104 5 10101 5 10098 5 10096 0 10093 5 10087 5 10080 0 10070 0 10063 5 10061 5 10060.5 10059.0 10057.0 10048.5 10040.0 10039.5 10035.5 10028.5 10021.5 10018.5 10015.0 10014.0 10011.5 10009.0 10008.0 10004.0 10001.5 9996.0 9994.5 9987.5 9979.5 9979.0 9974.5 9974.0 9970.5 9968.0 9966.5 9953.0 9952.0 9945.5 9942.5 9939.5 9926.0 10139.0 10131.0 10118.5 10115.0 10109.5 10105.5 10097.0 10093.5 10089.0 10082.0 10065.0 10062.0 10059.5 10051.0 10042.0 10022.5 10019.5 10015.5 10010.5 10003.0 9996.0 9988.5 9981.0 9975.0 9969.0 9953.5 9943.0 9926.5 10144.5 10139.0 10133.5 10130.5 10125.0 10115.0 10110.0 10103.5 10100.5 10071.5 10062.5 10059.5 10042.5 10038.0 10031.0 10017.5 10013.5 10010.5 10006.0 9998.0 9981.0 9975.5 9971.5 9969.0 9953.5 9946.0 9941.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:55 PAGE: 9921.0 9922.5 9917.5 9918.0 9914.5 9916.5 9912.0 9913.5 9911.0 9913.5 9909.0 9910.0 9899.5 9903.0 9898.5 9900.0 9894.5 9896.0 9891.0 9890.5 9886.0 9886.0 9882.5 9884.0 100.0 101.5 103.5 REMARKS: THIS FILE CONTAINS CASED HOLE RST BASE PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #2 AND GRCH BASE PASS #1, ALSO SIGMA BASE PASS #2 AND SIGMA BASE PASS #1, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:55 PAGE: 10 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1239886 O0 000 O0 0 2 1 1 4 68 0000000000 NBAC RST CPS 1239886 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC RST CPS 1239886 O0 000 O0 0 2 1 1 4 68 0000000000 SBNA FIL CU 1239886 O0 000 O0 0 2 1 1 4 68 0000000000 SFNA FIL CU 1239886 O0 000 O0 0 2 1 1 4 68 0000000000 SBFA FIL CU 1239886 O0 000 O0 0 2 1 1 4 68 0000000000 SFFA FIL CU 1239886 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT FIL 1239886 O0 000 O0 0 2 1 1 4 68 0000000000 IRAT FIL 1239886 O0 000 O0 0 2 1 1 4 68 0000000000 CIRNFIL 1239886 O0 000 O0 0 2 1 1 4 68 0000000000 CIRF FIL 1239886 O0 000 O0 0 2 1 1 4 68 0000000000 BSAL RST PPK 1239886 O0 000 O0 0 2 1 1 4 68 0000000000 SIBF RST CU 1239886 O0 000 O0 0 2 1 1 4 68 0000000000 TPHI RST PU-S 1239886 O0 000 O0 0 2 1 1 4 68 0000000000 SFFC RST CU 1239886 O0 000 O0 0 2 1 1 4 68 0000000000 SFNC RST CU 1239886 O0 000 O0 0 2 1 1 4 68 0000000000 SIGM RST CU 1239886 O0 000 O0 0 2 1 1 4 68 0000000000 DSIG RST CU 1239886 O0 000 O0 0 2 1 1 4 68 0000000000 FBEF RST UA 1239886 O0 000 O0 0 2 1 1 4 68 0000000000 CRRARST 1239886 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH RST GAPI 1239886 O0 000 O0 0 2 1 1 4 68 0000000000 TENS RST LB 1239886 O0 000 O0 0 2 1 1 4 68 0000000000 CCL RST V 1239886 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 10353.000 NBAC.RST 2519.178 FBAC. RST 3426.738 SBNA.FIL SFNA.FIL 34.906 SBFA.FIL 45.179 SFFA.FIL 33.330 TRAT. FIL IRAT. FIL 0.511 CIRN. FIL 0.707 CIRF. FIL 1.266 BSAL.RST SIBF.RST 34.671 TPHI.RST 33.942 SFFC.RST 31.483 SFNC.RST SIGM. RST 31.200 DSIG.RST 0.856 FBEF. RST 28.425 CRRA.RST GRCH.RST -999.250 TENS.RST 1328.000 CCL.RST 0.000 DEPT. 9881.500 NBAC.RST -999.250 FBAC.RST -999.250 SBNA.FIL SFNA.FIL -999.250 SBFA.FIL -999.250 SFFA.FIL -999.250 TRAT. FIL IRAT. FIL -999.250 CIRN. FIL -999.250 CIRF. FIL -999.250 BSAL.RST SIBF.RST -999.250 TPHI.RST -999.250 SFFC.RST -999.250 SFNC.RST SIGM. RST -999.250 DSIG.RST -999.250 FBEF. RST -999.250 CRRA.RST GRCH.RST 142.173 TENS.RST -999.250 CCL.RST -999.250 49.166 1.112 35.838 33.555 2.022 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:55 PAGE: 11 **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION · O01CO1 DATE : 98/11/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE 1VO?4BER : 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUFiBER : 3 DEPTH INCREMENT: 0.5000 FILE SU~fiVzARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10341 . 5 9899.5 RST 10353.0 9901.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS AU3MBER : 1 .......... EQUIVALENT UNSHIFTEDDEPTH .......... BASELINE DEPTH GRCH RST 88888.0 88889.5 88890.0 10343.0 10345.0 10337.5 10340.0 10334.0 10335.5 10336.0 10331.0 10333.5 10330.5 10331.5 10328.5 10331.0 10327.5 10329.5 10325.0 10325.5 10323.0 10323.5 10322.5 10325.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:55 PAGE: 12 10320 0 10315 5 10314 0 10305 0 10298 0 10294 0 10288 5 10287 5 10279 0 10267.0 10264.5 10258.0 10246.0 10238.0 10234.0 10233.0 10229.5 10229.0 10224.0 10223.0 10217.5 10209.5 10208.0 10204.0 10203.5 10199.0 10194.5 10194.0 10178.5 10167.0 10165.0 10162.5 1 O161.5 10159.5 10152.0 10149.0 10148.5 10146.0 10136.5 10132.5 10131.5 10129.5 10128.5 10118.5 10114.0 10113.0 10108.0 10107.5 10104.0 10099.5 10098.0 10092.0 10070.0 10067.0 10063.5 10315.0 10307.5 10299.5 10290.0 10279.5 10268.0 10266.0 10258.0 10247.0 10240.0 10234.5 10230.5 10225.0 10218.0 10205.5 10199.0 10195.5 10168.0 10164.5 10161.0 10150.5 10134.0 10131.0 10115.0 10110.0 10105.0 10100.5 10094.0 10065.0 10322.0 10317.5 10307.5 10297.0 10290.0 10235.0 10230.0 10225.0 10211.5 10209.5 10205.5 10195.5 10180.5 10167.5 10164.5 10155.0 10151.0 10148.5 10139.0 10133.5 10131.0 10120.5 10115.0 10110.0 10100.0 10072.0 10069.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:55 PAGE: 13 10063 0 10059 0 10056 5 10056 0 10054 5 10050 0 10040.0 10039.5 10034.0 10028.0 10026.0 10014.0 10011.5 10008.5 10008.0 10004.0 10002.0 10001.5 9998.5 9997.0 9996.0 9991.5 9987.0 9986.5 9984.5 9983.0 9979.0 9975.0 9973 5 9970 5 9968 0 9966 5 9956 5 9953 0 9946 5 9945 0 9942.0 9935.0 9927.0 9921.5 9912.0 9911.0 9909.0 9908.5 9904.5 9900.5 9898.5 100.0 $ REMARKS: 10059.5 10057.5 10051.0 10042.0 10028.0 10015.5 10010.0 10003.0 10000.0 9991.5 9988.5 9986.5 9985.0 9974.5 9969.0 9956.5 9953.5 9948.0 9943.0 9934.0 9927.5 9922.5 9913.5 991 O. 0 9905.5 9902.5 9900.0 101.5 10065.0 10059.0 10057.5 10042.5 10036.5 10030.5 10013.5 10010.5 10006.0 10004.0 9999.0 9998.5 9988.5 9985.5 9981.0 9975.0 9971.5 9969.0 9946.5 9913.5 9911.5 103.0 THIS FILE CONTAINS CASED HOLE RST BASE PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #3 AND GRCH BASE PASS #1, ALSO SIGMA BASE PASS #3 AND SIGMA BASE PASS #1, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:55 PAGE: 14 $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN * * NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1239886 O0 000 O0 0 3 1 1 4 68 0000000000 NBAC RST CPS 1239886 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC RST CPS 1239886 O0 000 O0 0 3 1 1 4 68 0000000000 SBNA FIL CU 1239886 O0 000 O0 0 3 1 1 4 68 0000000000 SFNA FIL CU 1239886 O0 000 O0 0 3 1 1 4 68 0000000000 SBFA FIL CU 1239886 O0 000 O0 0 3 1 1 4 68 0000000000 SFFA FIL CU 1239886 O0 000 O0 0 3 1 1 4 68 0000000000 TRAT FIL 1239886 O0 000 O0 0 3 1 1 4 68 0000000000 IRAT FIL 1239886 O0 000 O0 0 3 1 1 4 68 0000000000 CIRNFIL 1239886 O0 000 O0 0 3 1 I 4 68 0000000000 CIRF FIL 1239886 O0 000 O0 0 3 1 1 4 68 0000000000 BSALRST PPK 1239886 O0 000 O0 0 3 1 1 4 68 0000000000 SIBF RST CU 1239886 O0 000 O0 0 3 1 1 4 68 0000000000 TPHI RST PU-S 1239886 O0 000 O0 0 3 1 1 4 68 0000000000 SFFC RST CU 1239886 O0 000 O0 0 3 1 1 4 68 0000000000 SFNC RST CU 1239886 O0 000 O0 0 3 1 1 4 68 0000000000 SIGM RST CU 1239886 O0 000 O0 0 3 1 1 4 68 0000000000 DSIG RST CU 1239886 O0 000 O0 0 3 1 1 4 68 0000000000 FBEF RST UA 1239886 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:55 PAGE: 15 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) CRRARST 1239886 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH RST GAPI 1239886 O0 000 O0 0 3 1 1 4 68 0000000000 TENS RST LB 1239886 O0 000 O0 0 3 1 1 4 68 0000000000 CCL RST V 1239886 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 10353.000 NBAC.RST 2742.176 FBAC. RST SFNA.FIL 35.292 SBFA.FIL 43.376 SFFA.FIL IRAT. FIL 0.511 CIRN. FIL 0.710 CIRF. FIL SIBF.RST 35.188 TPHI.RST 33.294 SFFC. RST SIGM. RST 31.888 DSIG.RST 1.508 FBEF. RST GRCH. RST -999.250 TENS.RST 1337.000 CCL.RST DEPT. 9899.500 NBAC.RST -999.250 FBAC. RST SFNA.FIL -999.250 SBFA.FIL -999.250 SFFA.FIL IRAT. FIL -999.250 CIRN. FIL -999.250 CIRF. FIL SIBF. RST -999.250 TPHI.RST -999.250 SFFC. RST SIGM. RST -999.250 DSIG.RST -999.250 FBEF. RST GRCH. RST 207.902 TENS.RST -999.250 CCL.RST 3405 169 34 201 1 248 32 450 29 835 -0 008 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 SBNA.FIL TRAT. FIL BSAL.RST SFNC.RST CRRA.RST SBNA.FIL TRAT. FIL BSAL.RST SFNC.RST CRRA.RST 50. 407 1.107 37. 285 33. 849 1. 952 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAM~ : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:55 PAGE: 16 FILE NUMBER: 4 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS 1, 2, 3, RST $ REMARKS: THIS FILE CONTAINS THE ARITHMETIC AVERAGE OF BASE PASSES 1,2, & 3. THE DATA WAS CLIPPED AND DEPTH SHIFTED BEFORE THE AVERAGE WAS CALCULATED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 84 4 66 1 $ 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1239886 O0 000 O0 0 4 1 1 4 68 0000000000 NBAC RST CPS 1239886 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC RST CPS 1239886 O0 000 O0 0 4 1 1 4 68 0000000000 SBNA RSAV CU 1239886 O0 000 O0 0 4 1 1 4 68 0000000000 SFNA RSAV CU 1239886 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:55 PAGE: 17 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) SBFA RSAV CU 1239886 O0 000 O0 0 4 1 1 4 68 0000000000 SFFA RSAV CU 1239886 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT RSAV 1239886 O0 000 O0 0 4 1 1 4 68 0000000000 IRAT RSAV 1239886 O0 000 O0 0 4 1 1 4 68 0000000000 CIRNRSAV 1239886 O0 000 O0 0 4 1 1 4 68 0000000000 CIRF RSAV 1239886 O0 000 O0 0 4 1 1 4 68 0000000000 BSALRSAV PPK 1239886 O0 000 O0 0 4 1 1 4 68 0000000000 SIBF RSAV CU 1239886 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI RSAV PU-S 1239886 O0 000 O0 0 4 1 1 4 68 0000000000 SFFC RSAV CU 1239886 O0 000 O0 0 4 1 I 4 68 0000000000 SFNC RSAV CU 1239886 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM RSAV CU 1239886 O0 000 O0 0 4 1 1 4 68 0000000000 DSIG RSAV CU 1239886 O0 000 O0 0 4 1 1 4 68 0000000000 FBEF RSAV UA 1239886 O0 000 O0 0 4 1 1 4 68 0000000000 CRRARSAV 1239886 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH RST GAPI 1239886 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 10353.000 NBAC.RST 2310.479 FBAC.RST 3283.779 SBNA.RSAV SFNA.RSAV 35. 004 SBFA.RSAV 45.573 SFFA.RSAV 33. 641 TRAT.RSAV IRAT.RSAV 0.513 CIRN. RSAV 0.710 CIRF.RSAV 1.256 BSAL.RSAV SIBF. RSAV 35.217 TPHI.RSAV 33. 779 SFFC.RSAV 31. 726 SFNC.RSAV SIGM. RSAV 31.329 DSIG.RSAV 1.362 FBEF. RSAV 31.368 CRRA.RSAV GRCH. RST -999. 250 DEPT. 9875.500 NBAC.RST -999.250 FBAC.RST -999.250 SBNA.RSAV SFNA.RSAV -999.250 SBFA.RSAV -999.250 SFFA.RSAV -999.250 TRAT.RSAV IRAT.RSAV -999.250 CIRN. RSAV -999.250 CIRF.RSAV -999.250 BSAL.RSAV SIBF.RSAV -999.250 TPHI.RSAV -999.250 SFFC.RSAV -999.250 SFNC.RSAV SIGM. RSAV -999. 250 DSIG. RSAV -999. 250 FBEF. RSAV - 999. 250 CRRA. RSAV GRCH. RST 144. 906 49.966 1.109 37.372 33.470 1.986 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:55 PAGE: 18 **** FILE HEADER **** FILE NAM~ : EDIT .005 SERVICE · FLIC VERSION : O01CO1 DATE : 98/11/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SD?4MARY VENDOR TOOL CODE START DEPTH RST 10375.0 $ LOG HEADER DATA STOP DEPTH 9844.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~A RAY RST RESERVOIR SATURATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : 06-AUG-98 8Cl -205 1125 06-AUG-98 10373.0 10375.0 9874.0 10351.0 1800.0 TOOL NUMBER CGRS-A RST-A 9. 875 10558.0 Produced Fluids LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:55 PAGE: 19 FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN): REMARKS: Thank you for using Schlumberger This log was depth referenced to a Atlas SBL dated 02-May-1994. Ail depth correlations and tie-ins witnessed by co. rep. Logging Procedure: SANDSTONE MATRIX Logging interval of 9900 - 10375'PBTD THIS FILE CONTAINS THE RAW DATA FOR PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 1I 66 2 12 68 13 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:55 PAGE: 20 TYPE REPR CODE VALtrE 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 CS PS1 F/HR 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 TENS PS1 LB 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 NPHVPS1 V 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 NPDE PS1 V 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 NSCE PS1 V 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 CRRA PS1 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 NSCR PS1 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 AQTMPS1 S 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 CHV PS1 V 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 CPSV PS1 V 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 CP2V PS1 V 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 CM2V PS1 V 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 RCFR PS1 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 RCLC PS1 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 RCRC PS1 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 RCAKPS1 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 RTDF PS1 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 FPHVPS1 V 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 FPDE PS1 V 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 FSCE PS1 V 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 FSCR PS1 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 AQTF PS1 S 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 SF6P PS1 PSIG 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 HVPV PS1 V 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 BMCU PS1 UA 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 GDCU PS1 MA 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 EXCU PS1 UA 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 NBEF PS1 UA 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 FBEF PS1 UA 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 NPGF PS1 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 FPGF PS1 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 BSTR PSi 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 BSPR PS1 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 MARC PS1 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 ~ PS1 V 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 XPSV PSi V 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 XP2V PS1 V 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 X~2V PSi V 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 RXFR PS1 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 RXLC PS1 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:55 PAGE: 21 NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NU~B SAMP ELE~I CODE (HEX) RX_RC PS1 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 RXAKPS1 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 SHCU PS1 MA 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 BSAL PS1 PPK 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 BSAL SIG PPK 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 CIRNPS1 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 CIRF PS1 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 CIRNFIL 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 CIRF FIL 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 DSIG PS1 CU 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC PS1 CPS 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 IRAT PS1 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 IRAT FIL 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 NBAC PS1 CPS 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 SFNA PS1 CU 1239886 O0 000 O0 0 5 1 SFFA PS1 CU 1239886 O0 000 O0 0 5 1 SBNA PSi CU 1239886 O0 000 O0 0 5 1 SBFA PS1 CU 1239886 O0 000 O0 0 5 1 1 SFNA SIG CU 1239886 O0 000 O0 0 5 1 1 SFFA SIG CU 1239886 O0 000 O0 0 $ 1 1 SBNA SIG CU 1239886 O0 000 O0 0 $ 1 1 SBFA SIG CU 1239886 O0 000 O0 0 $ 1 1 SFNA FIL CU 1239886 O0 000 O0 0 5 1 1 SFFA FIL CU 1239886 O0 000 O0 0 5 1 1 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 SBNA FIL CU 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 SBFA FIL CU 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 SIBF PS1 CU 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 SFNC PS1 CU 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 SFFC PS1 CU 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM PS1 CU 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 SIBF SIG CU 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM SIG CU 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT PS1 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT SIG 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT FIL 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 GR PS1 GAPI 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 RDIX PS1 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 CRNI PS1 2(HZ 1239886 O0 000 O0 0 $ 1 1 4 68 0000000000 CRFI PS1 Kt~Z 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 CTM PS1 DEGC 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 XTM PS1 DEGC 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 TAV PSi 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 FICU PS1 AMP 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 CACU PS1 AMP 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 BUST PS1 1239886 O0 000 O0 0 5 1 1 BUSP PS1 1239886 O0 000 O0 0 5 1 1 RSXS PSl 1239886 O0 000 O0 0 5 1 1 TPHI PS1 PU 1239886 O0 000 O0 0 5 1 1 TPHI SIG PU 1239886 O0 000 O0 0 5 1 1 CCLC PS1 V 1239886 O0 000 O0 0 5 1 1 RSCS PS1 1239886 O0 000 O0 0 5 1 1 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 LIS-Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:55 PAGE: 22 ** DATA ** DEPT. 10375.000 CS.PS1 NPDE. PS1 1453.820 NSCE. PS1 AQTM. PS1 0.661 CHV. PS1 CM2V. PS1 -12.211 RCFR.PS1 RCAK. PS1 2.000 RTDF.PS1 FSCE. PS1 1.769 FSCR.PS1 HVPV. PS! 160.889 BMCU. PS1 NBEF. PS1 18.100 FBEF. PS1 BSTR.PS1 65.702 BSPR.PS1 XPSV. PS1 5.079 XP2V. PS1 RXLC.PS1 0.000 RXRC. PS1 BSAL.PS1 -999.250 BSAL.SIG CIRN. FIL -999.250 CIRF. FIL IRAT. PS1 -999.250 IRAT. FIL SFFA.PS1 -999.250 SBNA.PSl SFFA.SIG -999.250 SBNA.SIG SFFA.FIL -999.250 SBNA.FIL SFNC.PS1 -999.250 SFFC. PS1 SIGM. SIG -999.250 TRAT. PS1 GR.PS1 60.564 RDIX. PS1 CTM. PS1 99.121 XTM. PS1 CACU. PS1 2.476 BUST. PSI TPHI.PS1 -999.250 TPHI.SIG DEPT. NPDE. PS1 AQTM. PS1 CM2V. PS1 RCAK. PS1 FSCE.PS1 HVPV. PS1 NBEF.PS1 BSTR.PS1 XPSV. PS1 RXLC.PS1 BSAL.PS1 CIRN. FIL IRAT.PSI SFFA.PS1 SFFA.SIG SFFA.FIL SFNC.PS1 SIGM. SIG GR.PS1 CTM. PS1 CACU. PS1 TPHI.PS1 9844 000 1464 387 1 322 -12 270 0 000 1 659 161. 290 16. 052 71.622 5.074 0.000 35.706 0.735 0.550 35.276 1. 037 34. 757 31. 397 O. 637 144.036 98.877 2.467 48.392 CS.PS1 NSCE. PS1 CHV. PS1 RCFR.PS1 RTDF. PS1 FSCR.PS1 BMCU. PS1 FBEF. PS1 BSPR.PS1 XP2V. PS1 RXRC. PS1 BSAL.SIG CIRF. FIL IRAT. FIL SBNA.PS1 SBNA.SIG SBNA.FIL SFFC. PS1 TRAT. PS1 RDIX. PS1 XTM. PS1 BUST. PSi TPHI.SIG 1832 061 2 451 201 339 0 000 0 000 -0 434 44 824 34 971 1 120 12.114 0.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 54326.000 98.145 3.000 -999.250 1840. 414 2. 621 201. 339 0.000 0 000 0 121 42 731 27 958 1 112 12 078 0.000 2.719 1.009 0.550 48.462 3.100 49.844 32.955 1.316 69693.000 98.145 3.000 1.493 TENS. PS1 CRRA. PS1 CPSV. PS1 RCLC. PS1 FPHV. PS1 AQTF. PS1 GDCU. PS1 NPGF. PS1 MARC. PS1 XM2 V. PSi RXAK. PS1 CIRN. PS1 DSIG. PSi NBAC. PS1 SBFA. PS1 SBFA. SIG SBFA. FIL SIGM. PS1 TRAT. SIG CRNI. PS1 TAV. PSi B USP. PS1 CCLC. PSi TENS. PS1 CRR~. PS1 CPS V. PS1 RCLC. PS1 FPHV. PS1 AQTF. PS1 GDCU. PSI NPGF. PSi MARC. PSI XM2 V. PS1 RXAK. PS1 CIRN. PS1 DSIG. PSi NBAC. PS1 SBFA. PSI SBFA. SIG SBFA. FIL SIGM. PS1 TRAT. SIG CRNI. PS1 TAV. PS1 BUSP. PSl CCLC. PSl 972.000 1.932 5.021 0.000 1408.692 0.661 60.012 0 993 0 000 -12 426 0 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999.250 -999.250 447.050 94.888 3.000 0.029 1264.000 1.742 5.040 0.000 1412.354 1.322 60.340 0.997 0.000 -12 358 1 000 0 722 -0 970 2532 662 47 171 4 785 46 841 32 927 0.028 440.504 95.001 3.000 -999.250 NPHV. PS1 NSCR.PS1 CP2V. PS1 RCRC.PS1 FPDE.PS1 SF6P.PS1 EXCU. PS1 FPGF. PS1 XHV. PS1 RXFR.PS1 SHCU. PS1 CIRF. PS1 FBAC.PS1 SFNA.PSl SFNA.SIG SFNA.FIL SIBF. PS1 SIBF. SIG TRAT. FIL CRFI.PS1 FICU. PS1 RSXS.PS1 RSCS.PS1 NPHV. PS1 NSCR.PS1 CP2V. PS1 RCRC. PS1 FPDE. PS1 SF6P. PS1 EXCU. PS1 FPGF. PS1 XHV. PS1 RXFR.PS1 SHCU. PS1 CIRF. PS1 FBAC. PS1 SFNA.PS1 SFNA.SIG SFNA.FIL SIBF. PS1 SIBF. SIG TRAT. FIL CRFI.PS1 FICU. PS1 RSXS. PS1 RSCS. PS1 1491.700 0.341 12.173 0 000 1380 502 155 958 29 195 0 992 200 854 0 000 33 495 -999 250 -999 250 -999 250 -999 250 -999.250 -999.250 -999.250 -999.250 231.378 2.275 8878.O0O 8459.000 1499.024 -0.398 12.114 0.000 1387.979 165.644 29.533 1.000 200 854 0 000 36 863 0 994 3352 801 32 715 0.645 31.582 34.624 0.970 1.315 252.926 2.205 8878.000 8463.000 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:55 PAGE: 23 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .005 SERVICE . FLIC VERSION : O01CO1 DATE : 98/11/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE ' FLIC VERSION · O01CO1 DATE : 98/11/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~ER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS--ER: 2 DEPTH INCREMENT: O. 5000 FILE SURff4ARY VENDOR TOOL CODE START DEPTH STOP DEPTH 10398.0 9848.0 RST $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 06-AUG-98 8Cl -205 1125 06-AUG-98 10373.0 10375.0 9874.0 10351.0 1800.0 TOOL NUMBER LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:55 PAGE: 24 GR RST $ GAMMA RAY RESERVOIR SATURATION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE T~MPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : CGRS-A RST-A 9. 875 10558.0 Produced Fi uids NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN): REMARKS: Thank you for using Schlumberger This log was depth referenced to a Atlas SBL dated 02-May-1994. Ail depth correlations and tie-ins witnessed by co. rep. Logging Procedure: SANDSTONE MATRIX Logging interval of 9900 - 10375'PBTD THIS FILE CONTAINS THE RAW DATA FOR PASS #2. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:55 PAGE: 25 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 CS PS2 F/HR 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS2 LB 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 NPHVPS2 V 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 NPDE PS2 V 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 NSCE PS2 V 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 CRRA PS2 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 NSCR PS2 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 AQTMPS2 S 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 CHV PS2 V 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 CPSV PS2 V 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 CP2V PS2 V 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 CM2V PS2 V 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 RCFR PS2 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 RCLC PS2 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 RCRC PS2 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 RCAKPS2 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 RTDF PS2 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 FPHVPS2 V 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 FPDE PS2 V 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 FSCE PS2 V 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 FSCR PS2 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 AQTF PS2 S 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 SF6P PS2 PSIG 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 HVPV PS2 V 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 BMCU PS2 UA 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:55 PAGE: 26 NAFIE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) GDCUPS2 MA 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 EXCU PS2 UA 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 NBEF PS2 UA 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 FBEF PS2 UA 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 NPGF PS2 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 FPGF PS2 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 BSTR PS2 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 BSPR PS2 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 MARC PS2 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 XHV PS2 V 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 XPSV PS2 V 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 XP2V PS2 V 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 ~2~2V PS2 V 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 RXFR PS2 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 RXLC PS2 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 RXRC PS2 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 RXAKPS2 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 SHCU PS2 MA 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 BSAL PS2 PPK 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 BSAL SIG PPK 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 CIRNPS2 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 CIRF PS2 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 CIRNFIL 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 CIRF FIL 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 DSIG PS2 CU 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 FBAC PS2 CPS 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 IRAT PS2 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 IRAT FIL 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 NBAC PS2 CPS 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 SFNA PS2 CU 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 SFFA PS2 CU 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 SBNA PS2 CU 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 SBFA PS2 CU 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 SFNA SIG CU 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 SFFA SIG CU 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 SBNA SIG CU 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 SBFA SIG CU 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 SFNA Fib CU 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 SFFA FIL CU 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 SBNA FIL CU 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 SBFA FIL CU 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 SIBF PS2 CU 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 SFNC PS2 CU 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 SFFC PS2 CU 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM PS2 CU 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 SIBF SIG CU 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM SIG CU 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT PS2 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT SIG 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT FIL 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS2 GAPI 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 LIB Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:55 PAGE: 27 NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) RDIX PS2 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 CRNI PS2 KHZ 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 CRFI PS2 KHZ 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 CTM PS2 DEGC 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 XTM PS2 DEGC 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 TAV PS2 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 FICU PS2 AMP 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 CACU PS2 AMP 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 BUST PS2 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 BUSP PS2 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 RSXS PS2 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI PS2 PU 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI SIG PU 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 CCLC PS2 V 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 RSCS PS2 1239886 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. NPDE. PS2 AQTM. PS2 CM2V. PS2 RCAK. PS2 FSCE. PS2 HVPV. PS2 NBEF. PS2 BSTR.PS2 XPSV. PS2 RXLC. PS2 BSAL.PS2 CIRN. FIL IRAT. PS2 SFFA.PS2 SFFA.SIG SFFA.FIL SFNC. PS2 SIGM. SIG GR.PS2 CTM. PS2 CACU. PS2 TPHI.PS2 10398 000 1465 074 0 661 -12 211 0 000 1 684 160 645 14936 60.526 5.069 0.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 87.481 99.121 2.471 -999.250 DEPT. NPDE.PS2 AQTM. PS2 CM2V. PS2 RCAK. PS2 FSCE.PS2 HVPV. PS2 9848.000 1466.027 1.322 -12.250 0.000 1.723 160.661 CS.PS2 NSCE. PS2 CHV. PS2 RCFR.PS2 RTDF. PS2 FSCR.PS2 BMCU. PS2 FBEF. PS2 BSPR.PS2 XP2V. PS2 RXRC.PS2 BSAL.SIG CIRF. FIL IRAT.FIL SBNA.PS2 SBNA.SIG SBNA.FIL SFFC. PS2 TRAT. PS2 RDIX. PS2 XTM. PS2 BUST. PS2 TPHI.SIG CS.PS2 NSCE. PS2 CHV. PS2 RCFR.PS2 RTDF. PS2 FSCR.PS2 BMCU. PS2 1863.354 2.621 201.339 0 000 0 000 0 138 37 500 29 046 1 047 12 085 0 000 -999 250 -999 250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 72732.000 97.656 3.000 -999.250 1827.768 2.600 201.218 0.000 0.000 0.052 36.230 TENS.PS2 CRRA.PS2 CPSV. PS2 RCLC. PS2 FPHV. PS2 AQTF. PS2 GDCU. PS2 NPGF. PS2 MARC. PS2 XM2V. PS2 RXAK. PS2 CIRN. PS2 DSIG. PS2 NBAC. PS2 SBFA.PS2 SBFA.SIG SBFA.FIL SICM. PS2 TRAT. SIG CRNI. PS2 TAV. PS2 B USP. PS2 CCLC. PS2 TENS. PS2 CRRA.PS2 CPSV. PS2 RCLC. PS2 FPHV. PS2 AQTF. PS2 GDCU. PS2 1081.000 NPHV. PS2 1.945 5.069 0.000 1413.575 0.661 60.340 0.999 0 000 -12 387 0 000 -999 250 -999 250 -999 250 -999 250 -999.250 -999.250 -999.250 -999.250 457.965 94.888 3.000 0.105 NSCR.PS2 CP2V. PS2 RCRC. PS2 FPDE.PS2 SF6P.PS2 EXCU. PS2 FPGF. PS2 XHV. PS2 RXFR.PS2 SHCU. PS2 CIRF. PS2 FBAC. PS2 SFNA.PS2 SFNA.SIG SFNA.FIL SIBF. PS2 SIBF. SIG TRAT. FIL CRFI.PS2 FICU. PS2 RSXS.PS2 RSCS.PS2 1263.000 1.764 5.045 0.000 1417.237 1.322 59.749 NPHV. PS2 NSCR.PS2 CP2V. PS2 RCRC.PS2 FPDE. PS2 SF6P.PS2 EXCU. PS2 1508.790 0.064 12.129 0.000 1389.199 166.960 25.644 0.992 200.612 0.000 36.097 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 235.494 2.207 8878.00O 8463.000 1496.583 -0.252 12.158 0.000 1390.649 171.020 24.907 LI~ Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:55 PAGE: 28 NBEF. PS2 14.033 FBEF. PS2 BSTR.PS2 79.014 BSPR.PS2 XPSV. PS2 5.073 XP2V. PS2 RXLC. PS2 0.000 RXRC. PS2 BSAL.PS2 36.993 BSAL.SIG CIRN. FIL 0.733 CIRF. FIL IRAT. PS2 0.541 IRAT. FIL SFFA.PS2 33.640 SBNA.PS2 SFFA.SIG 0.971 SBNA.SIG SFFA.FIL 33.694 SBNA.FIL SFNC. PS2 30.784 SFFC.PS2 SIGM. SIG 0.619 TRAT. PS2 GR. PS2 106.181 RDIX. PS2 CTM. PS2 99.854 XTM. PS2 CACU. PS2 2.470 BUST. PS2 TPHI.PS2 47.811 TPHI.SIG 52 2 54 31 1 88496 98 3 1 24. 754 1 147 12 123 0 000 2 726 1 057 0 542 779 803 511 567 282 000 438 000 472 NPGF. PS2 MARC. PS2 2ff42V. PS2 RXAK. PS2 CIRN. PS2 DSIG. PS2 NBAC. PS2 SBFA.PS2 SBFA.SIG SBFA.FIL SIGM. PS2 TRAT. SIG CRNI. PS2 TA V. PS2 BUSP. PS2 CCLC. PS2 0.995 FPGF. PS2 0.000 XHV. PS2 -12.349 RXFR.PS2 0.000 SHCU. PS2 0 738 CIRF. PS2 -1 2600 43 4 43 31 0 441 94 3 -999 228 FBAC. PS2 739 SFNA.PS2 790 SFNA.SIG 895 SFNA.FIL 066 SIBF. PS2 593 SIBF. SIG 026 TRAT. FIL 137 CRFI.PS2 993 FICU. PS2 000 RSXS.PS2 250 RSCS.PS2 0.999 200.886 0.000 39.912 1.040 3489.236 32.082 0 577 31 234 35 O84 0 975 1 291 250 075 2 241 8878 000 8463.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE ·FLIC VERSION .O01CO1 DATE : 98/11/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NTJM~ER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREM~J~f: 0.5000 FILE S07~4ARY VENDOR TOOL CODE START DEPTH STOP DEPTH RST 10395.5 9863.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:55 PAGE: 29 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 06-AUG-98 8Cl -205 1125 06-AUG-98 10373.0 10375.0 9874.0 10351.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAFk~A RAY RST RESERVOIR SATURATION $ TOOL NUMBER ........... CGRS-A RST-A BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 9. 875 10558.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : Produced Fluids NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN): REMARKS: Thank you for using Schlumberger LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:55 PAGE: 30 This log was depth referenced to a Atlas SBL dated 02-May-1994. Ail depth correlations and tie-ins witnessed by co. rep. Logging Procedure: SANDSTONE MATRIX Logging interval of 9900 - 10375'PBTD THIS FILE CONTAINS THE RAW DATA FOR PASS #3. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 65 8 68 O. $ 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~ZE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 CS PS3 F/HR 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS3 LB 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 NPHVPS3 V 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 NPDE PS3 V 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 NSCE PS3 V 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 CRRA PS3 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 NSCR PS3 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 AQTMPS3 S 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 CHV PS3 V 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 CPSV PS3 V 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 CP2V PS3 V 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 LI.S Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:55 PAGE: 31 NAME SERV UNIT SERVICE API API API API FILE ~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) CM2V PS3 V 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 RCFR PS3 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 RCLC PS3 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 RCRC PS3 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 RCAKPS3 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 RTDF PS3 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 FPHVPS3 V 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 FPDE PS3 V 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 FSCE PS3 V 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 FSCR PS3 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 AQTF PS3 S 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 SF6P PS3 PSIG 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 HVPV PS3 V 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 BMCU PS3 UA 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 GDCU PS3 MA 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 EXCU PS3 UA 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 NBEF PS3 UA 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 FBEF PS3 UA 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 NPGF PS3 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 FPGF PS3 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 BSTR PS3 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 BSPR PS3 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 MARC PS3 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 XHV PS3 V 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 XPSV PS3 V 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 XP2V PS3 V 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 X~2V PS3 V 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 RXFR PS3 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 RXLC PS3 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 RXRC PS3 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 ~PS3 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 SHCU PS3 MA 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 BSAL PS3 PPK 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 BSAL SIG PPK 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 CIRNPS3 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 CIRF PS3 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 CIRNFIL 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 CIRF FIL 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 DSIG PS3 CU 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 FBAC PS3 CPS 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 IRAT PS3 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 IRAT FIL 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 NBAC PS3 CPS 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 SFNA PS3 CU 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 SFFA PS3 CU 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 SBNA PS3 CU 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 SBFA PS3 CU 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 SFNA SIG CU 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 SFFA SIG CU 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 SBNA SIG CU 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 SBFA SIG CU 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 LI.S Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:55 PAGE: 32 NAM~ SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) SFNA FIL CU 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 SFFA FIL CU 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 SBNA FIL CU 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 SBFA FIL CU 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 SIBF PS3 CU 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 SFNC PS3 CU 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 SFFC PS3 CU 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM PS3 CU 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 SIBF SIG CU 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM SIG CU 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT PS3 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT SIG 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT FIL 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS3 GAPI 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 RDIX PS3 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 CRNI PS3 KHZ 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 CRFI PS3 KHZ 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 CTM PS3 DEGC 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 XTM PS3 DEGC 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 TAV PS3 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 FICU PS3 AMP 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 CACU PS3 AMP 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 BUST PS3 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 BUSP PS3 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 RSXS PS3 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI PS3 PU 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI SIG PU 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 CCLC PS3 V 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 RSCS PS3 1239886 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. NPDE.PS3 AQTM. PS3 CM2V. PS3 RCAK. PS3 FSCE.PS3 HVPV. PS3 NBEF.PS3 BSTR.PS3 XPSV. PS3 RXLC. PS3 BSAL.PS3 CIRN. FIL IRAT. PS3 SF?A.PS3 SFFA.SIG SFFA.FIL 10395 500 1465 684 0 661 -12 211 0 000 1 729 160.889 15.274 57.172 5.089 0.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 CS.PS3 1895.735 TENS.PS3 NSCE. PS3 2.623 CRRA.PS3 CHV. PS3 201.581 CP5V. PS3 RCFR.PS3 0.000 RCLC. PS3 RTDF. PS3 0.000 FPHV. PS3 FSCR.PS3 -0.321 AQTF. PS3 BMCU. PS3 36.914 GDCU. PS3 FBEF. PS3 29.601 NPGF. PS3 BSPR.PS3 1.033 MARC. PS3 XP2V. PS3 12.129 X~I2V. PS3 RXRC. PS3 0.000 RXAK. PS3 BSAL.SIG -999.250 CIRN. PS3 CIRF. FIL -999.250 DSIG.PS3 IRAT. FIL -999.250 NBAC. PS3 SBNA.PS3 -999.250 SBFA.PS3 SBNA.SIG -999.250 SBFA.SIG SBNA.FIL -999.250 SBFA.FIL 874.000 NPHV. PS3 1.938 NSCR.PS3 5.060 0.000 1420 899 0 661 59 028 1 005 0 000 -12 289 0 000 -999 250 -999.250 -999.250 CP2V. PS3 RCRC. PS3 FPDE. PS3 SF6P.PS3 EXCU. PS3 FPGF. PS3 XHV. PS3 RXFR.PS3 SHCU. PS3 CIRF. PS3 FBAC. PS3 SFNA.PS3 -999.250 SFNA.SIG -999.250 SFNA.FIL -999.250 SIBF. PS3 1484.376 0.076 12 100 0 000 1390 153 171 821 24 066 1 002 201 096 0 000 38.048 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ~ lO-NOV-1998 10:55 PAGE: 33 LI~S Tape Verification Listing Schlumberger Alaska Computing Center SFNC. PS3 -999.250 SFFC. PS3 -999.250 SIGM. PS3 SIGM. SIG -999.250 TRAT. PS3 -999.250 TRAT. SIG GR. PS3 127.857 RDIX. PS3 91444.000 CRNI.PS3 CTM. PS3 98.633 XTM. PS3 98.145 TAV. PS3 CACU. PS3 2.480 BUST. PS3 3.000 BUSP. PS3 TPHI. PS3 -999.250 TPHI.SIG -999.250 CCLC. PS3 DEPT. 9863.500 CS.PS3 NPDE. PS3 1465.493 NSCE.PS3 AQTM. PS3 1.102 CHV. PS3 CM2V. PS3 -12.260 RCFR.PS3 RCAK. PS3 0.000 RTDF. PS3 FSCE. PS3 1.722 FSCR.PS3 HVPV. PS3 161.035 BMCU. PS3 NBEF. PS3 14.766 FBEF. PS3 BSTR.PS3 78.096 BSPR.PS3 XP5V. PS3 5.073 XP2V. PS3 RXLC. PS3 0.000 RXRC. PS3 BSAL.PS3 37.205 BSAL.SIG CIRN. FIL 0.726 CIRF.FIL IRAT. PS3 0.568 IRAT.FIL SFFA.PS3 34.396 SBNA.PS3 SFFA.SIG 0.798 SBNA.SIG SFFA.FIL 34.897 SBNA.FIL SFNC.PS3 30.965 SFFC. PS3 SIGM. SIG 0.661 TRAT.PS3 GR.PS3 147.362 RDIX. PS3 CTM. PS3 100.342 XTM. PS3 CACU. PS3 2.469 BUST. PS3 TPHI.PS3 49.397 TPHI.SIG 1838.256 TENS. PS3 2.606 CRRA.PS3 201.339 CP5V. PS3 0.000 RCLC. PS3 0.000 FPHV. PS3 0.014 AQTF. PS3 36.992 GDCU. PS3 26.273 NPGF. PS3 1.085 MARC. PS3 12.118 X~2V. PS3 0.000 RXAK. PS3 2.715 CIRN. PS3 0.956 DSIG.PS3 0.562 NBAC. PS3 53.712 SBFA.PS3 2.874 SBFA.SIG 55.993 SBFA.FIL 32.995 SIGM. PS3 1.347 TRAT. SIG 107045.000 CRNI.PS3 98.145 TAV. PS3 3.000 BUSP. PS3 1.581 CCLC. PS3 -999.250 -999.250 452.378 94.888 3.000 0.010 1263.000 1.779 5.050 0.000 1420.899 0.661 60.143 0.996 0.000 -12.365 0 000 0 745 -1 795 2695 251 48 363 3 826 46.976 33.020 0.029 444.140 94.984 3.000 -999.250 SIBF. SIG TRAT. FIL CRFI.PS3 FICU. PS3 RSXS.PS3 RSCS.PS3 NPHV. PS3 NSCR.PS3 CP2V. PS3 RCRC.PS3 FPDE. PS3 SF6P.PS3 EXCU. PS3 FPGF. PS3 XHV. PS3 RXFR.PS3 SHCU. PS3 CIRF. PS3 FBAC. PS3 SFNA.PS3 SFNA.SIG SFNA.FIL SIBF. PS3 SIBF. SIG TRAT.FIL CRFI.PS3 FICU. PS3 RSXS.PS3 RSCS.PS3 -999.250 -999.250 233.417 2.246 8878.000 8459.000 1497.804 0.156 12.151 0.000 1391 412 174 090 24 566 1 001 200 822 0 000 39 912 0 949 3605.965 30.936 0.570 31.234 35.159 0.971 1.345 249.609 2.212 8878.O0O 8463.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE . FLIC VERSION · O01CO1 DATE : 98/11/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/11/10 ORIGIN : FLIC TAPE NAME · 98577 CONTIArUATION # : 1 PREVIOUS TAPE : COFk~ENT · BP EXPLORATION, 3-43/P-36, ENDICOTT, API # 50-029-22416-00 LAS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:55 PAGE: 34 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/11/10 ORIGIN : FLIC REEL NAME : 98577 CONTINUATION # : PREVIOUS REEL : CO~4ENT : BP EXPLORATION, 3-43/P-36, ENDICOTT, API# 50-029-22416-00 Tape Subfile 2 is type: LIS TAPE HEADER ENDICOTT UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: OWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING RUN 1 6192.00 J. DAHL ZARNDT/WALLS REMARKS: 3 - 43/P - 36 500292241600 BP EXPLORATION (ALASKA) INC. ATLAS WIRELINE SERVICES 03-MAY-94 OPEN HOLE RUN 2 RUN 3 8 liN 17E 2777 640 58.85 58.85 14.50 CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 10.750 2740.0 9.875 10565.0 DIFL/ZDL/CN/GR. CIRCULATION STOPPED AT 14:30, 28-APR-94. DIFL/GR WAS LOGGED UP TO 9600' ON REPEAT PASS. MAIN PASS WAS LOGGED UP TO 9900'. THE ZCOR RESPONSE ON MAIN PASS WAS READING HIGH DUE TO PROBABLE MUD BUILDUP ON PAD. REPEAT PASS CONFIRMED TOOLS RESPONSE. BARITE PRESENT IN MUD SYSTEM (4.1%) CAN EFFECT PE RESPONSE. NEUTRON LOG PARAMETERS: SANDSTONE MATRIX, CALIPER CORRECTED, CHISM FILTERING ACTIVE, NO CASING OR SALINITY CORRECTIONS APPLIED. AS PER CLIENTS REQUEST, BOREHOLE & TORNADO CHART CORRECTIONS WERE APPLIED TO THE DIL DATA. THE DIL DATA WAS CORRECTED FOR BOREHOLE SIZE. THE CORRECTED DATA WAS THEN USED IN THE ATLAS TORNADO CHART TO GET "RT" & "DI" CURVES. RT = TRUE FORMATION RESISTIVITY. DI = DEPTH OF INVASION. FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; cased hole data. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR DIL SDN 2435 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA depth shifted and clipped curves; .5000 START DEPTH STOP DEPTH 9600.0 10502.0 9600.0 10560.0 9903.0 10527.5 9903.0 10509.0 GR (MEASURED DEPTH) BASELINE DEPTH LL8 9608.5 9608.5 9618.5 9618.5 9627.5 9665.5 9666.0 9668.0 9668.5 9675.5 9680.0 9680.0 9693.5 9755.5 9756.0 9756.0 9798.0 9797.5 9810.0 9809.5 9811.5 9827.0 9843.5 9843.5 9858.0 9873.5 9897.5 9902.0 9913.0 9922.5 9926.5 9934.0 9942.5 9956.0 9956.5 9957.0 9968.0 9968.5 9969.0 9971.5 9975.0 9980.5 9981.0 9985.0 9985.5 9988.5 9989.0 9998.0 9999.5 9957.5 9972.0 9976.0 9981.5 9988.5 all runs merged; no EQUIVALENT UNSHIFTED DEPTH ILM 9608.0 9618.0 9626.5 9665.0 9668.0 9675.0 9679.5 9693.0 9754.5 RHOB NPHI 9797.0 9810.5 9826.5 9857.0 9873.5 9897.0 9902.0 9934.0 9957.5 9968.0 9922.0 9942.5 9956.0 9969.0 9913.5 9926.5 9955.5 9968.5 9980.0 9984.5 9998.0 9986.0 9989.0 9989.0 9998.0 9997.5 10000.0 9999.5 10003.5 10003.5 10006.5 10006.0 10011.0 10010.0 10010.0 10014.0 10013.5 10031.0 10030.5 10038.0 10039.5 10039.0 10041.5 10041.0 10057.5 10057.5 10056.5 10059.5 10060.0 10062.0 10063.0 10062.0 10062.5 10062.5 10071.5 10071.5 10072.0 10072.5 10073.0 10073.0 10082.0 10082.5 10088.5 10089.0 10088.5 10089.0 10089.0 10100.5 10110.0 10109.5 10110.5 10110.5 10110.0 10114.5 10115.5 10115.5 10115.0 10131.5 10131.0 10134.0 10134.0 10134.5 10134.5 10135.0 10146.5 10151.0 10150.5 10151.0 10155.0 10155.0 10159.5 10159.0 10161.0 10164.5 10164.5 10164.0 10168.5 10167.5 10180.0 10179.5 10180.0 10180.5 10180.0 10191.5 10191.0 10194.0 10195.5 10195.5 10196.0 10196.5 10196.0 10199.0 10206.5 10213.0 10219.5 10225.0 10225.0 10225.5 10224.0 10233.0 10234.5 10235.0 10239.0 10240.0 10240.0 10244.0 10243.5 10247.0 10246.5 10251.5 10252.0 10251.5 10256.5 10256.5 10266.0 10268.5 10269.0 10272.5 10275.5 10275.0 10276.0 10276.0 10276.0 10281.0 9999.5 10006.5 10038.0 10062.5 10089.0 10100.5 10111.0 10115.5 10146.0 10161.0 10168.5 10194.5 10196.0 10199.5 10207.0 10214.0 10221.0 10225.5 10234.0 10239.0 10244.0 10248.0 10252.5 10257.5 10266.0 10272.0 10275.5 10281.5 10281.5 10289.5 10290.0 10292.5 10293.0 10296.0 10299.0 10312.0 10312.5 10321.5 10325.0 10331.5 10332.0 10335.0 10335.5 10338.0 10339.5 10346.5 10350.0 10353.0 10356.0 10356.5 10365.5 10366.5 10369.0 10372.5 10373.0 10380.5 10393.5 10402.0 10406.0 10406.5 10411.5 10412.0 10416.0 10416.5 10418.5 10419.0 10422.5 10423.0 10432.0 10434.0 10434.5 10435.0 10435.5 10436.0 10444.0 10453.5 10456.0 10457.5 10458.5 10459.0 10460.5 10461.5 10464.0 10466.5 10470.5 10471.0 10474.0 10474.5 10289.0 10312.0 10325.0 10332.5 10336.0 10339.5 10350.5 10353.0 10356.5 10366.5 10373.0 10406.0 10417.0 10419.5 10422.5 10433.5 10452.5 10455.0 10457.5 10470.5 10474.0 10281.0 10288.5 10311.0 10324.5 10332.0 10335.5 10346.0 10365.0 10416.5 10422.5 10434.0 10452.5 10458.0 10460.5 10470.0 10474.0 10289.0 10292.5 10298.5 10312.0 10321.5 10325.0 10335.0 10349.5 10355.0 10365.0 10368.5 10371.5 10380.0 10393.0 10403.5 10410.5 10415.0 10420.5 10435.5 10452.5 10456.0 10458.5 10461.5 10466.5 10471.0 10475.0 10290.0 10293.0 10296.5 10313.5 10336.0 10339.0 10346.5 10356.0 10373.0 10402.5 10407.0 10412.5 10417.0 10419.5 10423.5 10432.0 10434.5 10437.0 10444.0 10453.5 10456.5 10460.5 10464.5 10478.0 10484.5 10492.0 10500.5 10501.5 10504.0 10531.0 10540.5 10549.0 $ MERGED DATA SOURCE PBU TOOL CODE GR GR DIL DIL SDN 2435 $ REMARKS: 10530.5 10539.5 10547.5 10478.0 10492.0 10501.0 10484.5 10491.5 10501.5 10505.5 RUN NO. PASS NO. MERGE TOP MERGE BASE 1 4 9600.0 9910.0 1 3 9910.0 10502.0 1 4 9600.0 9910.0 1 3 9910.0 10560.0 1 3 9903.0 10527.5 1 3 9903.0 10509.0 MERGED MAIN PASS. DIFL/GR WAS LOGGED UP TO 9600' ON REPEAT PASS. THE MAIN PASS WAS LOGGED UP TO 9900'. REPEAT PASS DATA FROM 9600 - 9910' WAS SPLICED ONTO THE MAIN PASS FOR COMPLETE DATA COVERAGE. SP FROM REPEAT PASS (9600-9910') WAS SHIFTED LEFT (MINUS) 15 MV TO AGREE WITH SP FROM MAIN PASS. SP, MTEM, TEND, & TENS WERE SHIFTED WITH LL8. ILD, RT, & DI WERE SHIFTED WITH ILM. DRHO, PEF, & CALl WERE SHIFTED WITH RHOB. FUCT & NUCT WERE SHIFTED WITH NPHI. CN WN FN COUN STAT / ? ?MATCH1. OUT / ? ?MATCH2. OUT /??MATCH3 .OUT / ??MATCH4. OUT $ : BP EXPLORATION : 3 - 43/P - 36 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 17 Curves: Name Tool Code Samples Units Size API API API API Log Crv Crv Length Typ Typ Cls Mod 1 GR DIL 68 1 GAPI 2 LL8 DIL 68 1 OHMM 3 ILM DIL 68 1 OHMM 4 ILD DIL 68 i OHMM 5 RT DIL 68 1 OHMM 6 DI DIL 68 1 IN 7 SP DIL 68 1 MV 8 MTEM DIL 68 1 DEGF 9 TEND DIL 68 1 LB 10 TENS DIL 68 1 LB 11 RHOB SDN 68 1 G/C3 12 DRHO SDN 68 1 G/C3 13 PEF SDN 68 1 BN/E 14 CALl SDN 68 1 IN 15 NPHI 2435 68 1 PU-S 16 FUCT 2435 68 1 CPS 17 NUCT 2435 68 1 CPS 4 4 55 965 57 4 4 50 746 76 4 4 50 746 76 4 4 50 746 76 4 4 50 746 76 4 4 50 746 76 4 4 50 746 76 4 4 50 746 76 4 4 50 746 76 4 4 50 746 76 4 4 22 779 91 4 4 22 779 91 4 4 22 779 91 4 4 22 779 91 4 4 98 211 23 4 4 98 211 23 4 4 98 211 23 68 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 141 0 1 1 1 1 1 1 1 1 1 0 0 0 0 1 1 1 Tape File Start Depth = 10578.000000 Tape File End Depth = 9594.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 35443 datums Tape Subfile: 2 432 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 3 is type: LIS TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY FILE HEADER FILE NUMBER: 2 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 1 3 .2500 VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9903.0 10510.0 DIFL 9903.0 10568.0 ZDL 9898.0 10534.0 2435 9898.0 10512.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): 28-APR-94 FSYS REV. J001 VER. 1.1 1430 28-APR-94 1855 28-APR-94 10565.0 10563.0 9600.0 10560.0 1500.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MODL MIS GR CN ZDL KNJT TEMP PCM DIFL $ CABLEHEAD TENSION MODAL SUB MASS ISOLATION SUB GAMMA RAY COMPENSATED NEUTRON Z-DENSITY KNUCKLE JOINT TEMPERATURE PULSE CODE MODULATOR DUAL INDUCTION TOOL NUMBER 3974XA 3517XA 3967XA 1309XA 2435XA 2222EA/2222MA 3921NA 2806XA 3506XA 1503XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 9.875 2740.0 .0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): LSND 10.30 56.0 9.6 4.9 161.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: MAIN PASS. $ CN WN FN COUN STAT : BP EXPLORATION : 3 - 43/P - 36 : ENDICOTT : NORTH SLOPE : ALASKA 1.640 .750 2.550 .000 1.240 .000 THERMAL SANDSTONE 2.65 .000 1.5 70.0 161.0 69.0 .0 70.0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 21 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 2O 21 GR DIFL 68 1 GAPI RFOC DIFL 68 1 OHMM RILM DIFL 68 1 OHMM RILD DIFL 68 1 OHMM RT DIFL 68 1 OHMM DI DIFL 68 1 IN VILD DIFL 68 1 MV SP DIFL 68 1 MV TEMP DIFL 68 1 DEGF CHT DIFL 68 1 LB TTEN DIFL 68 1 LB SPD DIFL 68 1 F/MN ZDEN ZDL 68 1 G/C3 ZCOR ZDL 68 1 G/C3 PE ZDL 68 1 BN/E CAL ZDL 68 1 IN CNC 2435 68 1 PU-S CNCF 2435 68 1 PU-S CN 2435 68 1 PU-L LSN 2435 68 1 CPS SSN 2435 68 1 CPS 4 4 67 456 14 5 4 4 27 515 24 6 4 4 06 213 78 0 4 4 04 903 06 0 4 4 04 903 06 0 4 4 04 903 06 0 4 4 04 522 10 6 4 4 53 419 67 0 4 4 40 467 34 0 4 4 78 867 34 0 4 4 78 867 34 0 4 4 13 331 34 0 4 4 52 443 33 1 4 4 09 884 61 1 4 4 76 731 33 1 4 4 24 115 90 6 4 4 98 211 23 1 4 4 98 211 23 1 4 4 52 326 75 5 4 4 84 023 70 1 4 4 83 368 34 1 84 * DATA RECORD (TYPE# 0) Total Data Records: 248 974 BYTES * Tape File Start Depth = 10578.000000 Tape File End Depth = 9898.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 59863 datums Tape Subfile: 3 329 records... Minimum record length: 62 bytes Maximum record length: 974 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 4 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9600.0 DIFL 9600.0 ZDL 9900.0 2435 9900.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (PT): TD LOGGER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): STOP DEPTH 10124.0 10182.0 10149.0 10128.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MODL MIS GR CN ZDL KNJT TEMP PCM DIFL $ CABLEHEAD TENSION MODAL SUB MASS ISOLATION SUB GAMMA RAY COMPENSATED NEUTRON Z-DENSITY KNUCKLE JOINT TEMPERATURE PULSE CODE MODULATOR DUAL INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 28-APR-94 FSYS REV. J001 VER. 1.1 1430 28-APR-94 1929 28-APR-94 10565.0 10563.0 9600.0 10560.0 1500.0 TOOL NUMBER 3974XA 3517XA 3967XA 1309XA 2435XA 2222EA/2222MA 3921NA 2806XA 3506XA 1503XA 9.875 2740.0 .0 LSND 10.30 56.0 9.6 4.9 161.0 1.640 70.0 MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: REPEAT PASS. $ CN WN FN COUN STAT : BP EXPLORATION : 3 - 43/P - 36 : ENDICOTT : NORTH SLOPE : ALASKA .750 2.550 .000 1.240 .000 THERMAL SANDSTONE 2.65 .000 1.5 161.0 69.0 .0 70.0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 21 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR DIFL 68 1 GAPI 2 RFOC DIFL 68 1 OHMM 3 RILM DIFL 68 1 OHMM 4 RILD DIFL 68 1 OHMM 5 RT DIFL 68 1 OHMM 6 DI DIFL 68 1 IN 7 VILD DIFL 68 1 MV 8 SP DIFL 68 1 MV 9 TEMP DIFL 68 1 DEGF 10 CHT DIFL 68 1 LB 11 TTEN DIFL 68 1 LB 12 SPD DIFL 68 1 F/MN 13 ZDEN ZDL 68 1 G/C3 14 ZCOR ZDL 68 1 G/C3 15 PE ZDL 68 1 BN/E 16 CAL ZDL 68 1 IN 17 CNC 2435 68 1 PU-S 18 CNCF 2435 68 1 PU-S 19 CN 2435 68 1 PU-L 20 LSN 2435 68 1 CPS 21 SSN 2435 68 1 CPS 4 4 67 456 14 5 4 4 27 515 24 6 4 4 06 213 78 0 4 4 04 903 06 0 4 4 04 903 06 0 4 4 04 903 06 0 4 4 04 522 10 6 4 4 53 419 67 0 4 4 40 467 34 0 4 4 78 867 34 0 4 4 78 867 34 0 4 4 13 331 34 0 4 4 52 443 33 1 4 4 09 884 61 1 4 4 76 731 33 1 4 4 24 115 90 6 4 4 98 211 23 1 4 4 98 211 23 1 4 4 52 326 75 5 4 4 84 023 70 1 4 4 83 368 34 1 84 * DATA RECORD (TYPE# 0) 974 BYTES * Total Data Records: 219 Tape File Start Depth = 10194.000000 Tape File End Depth = 9594.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 88266 datums Tape Subfile: 4 298 records... Minimum record length: 62 bytes Maximum record length: 974 bytes Tape Subfile 5 is type: LIS 94/ 5/ 3 01 **** REEL TRAILER **** 94/ 5/ 4 01 Tape Subfile: 5 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 4 MAY 94 9:37a Elapsed execution time = 14.01 seconds. SYSTEM RETURN CODE = 0
